FORM 10-K
United States
Securities and Exchange Commission
Washington, D.C. 20549
(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, 2006
/ / Transition Report Pursuant to Section 13 or 15(d) of the Securities
Exchange Act of 1934
For the transition period from ______________ to ______________
Commission File No. 1-3548
ALLETE, 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)
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(218) 279-5000
(Registrant's telephone number, including area code)
SECURITIES REGISTERED PURSUANT TO SECTION 12(B) OF THE ACT:
Name of Each Stock Exchange
Title of Each Class on Which Registered
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Common Stock, without par value New York Stock Exchange
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SECURITIES REGISTERED PURSUANT TO SECTION 12(G) OF THE ACT:
None
Indicate by check mark if the registrant is a well-known seasoned issuer, as
defined in Rule 405 of the Securities Act.
Yes /X/ No / /
Indicate by check mark if the registrant is not required to file reports
pursuant to Section 13 or Section 15(d) of the Act.
Yes / / No /X/
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/
Indicate by check mark whether the registrant is a large accelerated filer, an
accelerated filer or a non-accelerated filer (as defined in Rule 12b-2 of the
Act).
Large Accelerated Filer /X/ Accelerated Filer / / Non-Accelerated Filer / /
Indicate by check mark whether the registrant is a shell company (as defined in
Rule 12b-2 of the Act).
Yes / / No /X/
The aggregate market value of voting stock held by nonaffiliates on June 30, 2006, was $1,427,346,731.
As of February 1, 2007, there were 30,446,854 shares of ALLETE Common Stock, without par value, outstanding.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the Proxy Statement for the 2007 Annual Meeting of Shareholders are incorporated by reference in Part III.
INDEX
DEFINITIONS................................................................. 2
SAFE HARBOR STATEMENT UNDER THE PRIVATE SECURITIES LITIGATION REFORM ACT
OF 1995..................................................................... 4
PART I
Item 1. Business...................................................... 5
Energy - Regulated Utility................................ 6
Electric Sales........................................ 7
Purchased Power....................................... 9
Fuel.................................................. 10
Regulatory Issues..................................... 10
Competition........................................... 14
Franchises............................................ 14
Energy - Nonregulated Energy Operations................... 14
Energy - Investment in ATC................................ 15
Real Estate............................................... 15
Regulation............................................ 19
Competition........................................... 19
Other..................................................... 19
Environmental Matters..................................... 20
Employees................................................. 22
Executive Officers of the Registrant...................... 23
Item 1A. Risk Factors.................................................. 24
Item 1B. Unresolved Staff Comments..................................... 27
Item 2. Properties.................................................... 27
Item 3. Legal Proceedings............................................. 27
Item 4. Submission of Matters to a Vote of Security Holders........... 27
PART II
Item 5. Market for Registrant's Common Equity, Related Stockholder
Matters and Issuer Purchases of Equity Securities......... 28
Item 6. Selected Financial Data....................................... 29
Item 7. Management's Discussion and Analysis of Financial Condition
and Results of Operations................ ................ 31
Executive Summary............................................. 31
Net Income.................................................... 34
2006 Compared to 2005......................................... 36
2005 Compared to 2004......................................... 38
Non-GAAP Financial Measures................................... 40
Critical Accounting Estimates................................. 40
Outlook....................................................... 42
Liquidity and Capital Resources............................... 46
Capital Requirements.......................................... 50
Environmental and Other Matters............................... 50
Market Risk................................................... 50
New Accounting Standards...................................... 51
Item 7A. Quantitative and Qualitative Disclosures about Market Risk.... 52
Item 8. Financial Statements and Supplementary Data................... 52
Item 9. Changes in and Disagreements with Accountants on Accounting
and Financial Disclosure.................................. 52
Item 9A. Controls and Procedures....................................... 52
Item 9B. Other Information............................................. 52
PART III
Item 10. Directors, Executive Officers and Corporate Governance........ 53
Item 11. Executive Compensation........................................ 53
Item 12. Security Ownership of Certain Beneficial Owners and
Management and Related Stockholder Matters................ 53
Item 13. Certain Relationships and Related Transactions, and
Director Independence..................................... 53
Item 14. Principal Accountant Fees and Services........................ 53
PART IV
Item 15. Exhibits and Financial Statement Schedules.................... 54
SIGNATURES.................................................................. 58
CONSOLIDATED FINANCIAL STATEMENTS........................................... 59
1 ALLETE 2006 Form 10-K
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DEFINITIONS
The following abbreviations or acronyms are used in the text. References in this report to "we," "us" and "our" are to ALLETE, Inc. and its subsidiaries, collectively.
ABBREVIATION OR ACRONYM TERM
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ADESA ADESA, Inc.
AICPA American Institute of Certified Public
Accountants
ALLETE ALLETE, Inc.
ALLETE Properties ALLETE Properties, LLC
AREA Arrowhead Regional Emission Abatement
ATC American Transmission Company LLC
BNI Coal BNI Coal, Ltd.
Boswell Boswell Energy Center
Company ALLETE, Inc. and its subsidiaries
Constellation Energy Commodities Constellation Energy Commodities Group,
Inc.
DOC Minnesota Department of Commerce
DRI Development of Regional Impact
EITF Emerging Issues Task Force
Enventis Telecom Enventis Telecom, Inc.
EPA Environmental Protection Agency
ESOP Employee Stock Ownership Plan
FASB Financial Accounting Standards Board
FERC Federal Energy Regulatory Commission
Florida Landmark Florida Landmark Communities, Inc.
Florida Water Florida Water Services Corporation
Form 8-K ALLETE Current Report on Form 8-K
Form 10-K ALLETE Annual Report on Form 10-K
Form 10-Q ALLETE Quarterly Report on Form 10-Q
FPL Energy FPL Energy, LLC
FPSC Florida Public Service Commission
FSP Financial Accounting Standards Board Staff
Position
GAAP Accounting Principles Generally Accepted
in the United States
Invest Direct ALLETE's Direct Stock Purchase and
Dividend Reinvestment Plan
IPO Initial Public Offering
kV Kilovolt(s)
Laskin Laskin Energy Center
MBtu Million British thermal units
Minnesota Power An operating division of ALLETE, Inc.
Minnkota Power Minnkota Power Cooperative, Inc.
MISO Midwest Independent Transmission System
Operator, Inc.
Moody's Moody's Investors Service, Inc.
MPCA Minnesota Pollution Control Agency
MPUC Minnesota Public Utilities Commission
MW / MWh Megawatt(s) / Megawatthour(s)
ALLETE 2006 Form 10-K 2
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DEFINITIONS (CONTINUED)
ABBREVIATION OR ACRONYM TERM
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NOx Nitrogen Oxide
Northwest Airlines Northwest Airlines, Inc.
Note ___ Note ___ to the consolidated financial
statements in this Form 10-K
NPDES National Pollutant Discharge Elimination
System
NYSE New York Stock Exchange
OAG Office of the Attorney General
Oliver Wind I Oliver Wind I Energy Center
Oliver Wind II Oliver Wind II Energy Center
Palm Coast Park Palm Coast Park development project in
Florida
Palm Coast Park District Palm Coast Park Community Development
District
PolyMet Mining PolyMet Mining, Inc.
PSCW Public Service Commission of Wisconsin
PUHCA 1935 Public Utility Holding Company Act of 1935
PUHCA 2005 Public Utility Holding Company Act of 2005
Rainy River Energy Rainy River Energy Corporation
SEC Securities and Exchange Commission
SFAS Statement of Financial Accounting
Standards No.
SO2 Sulfur Dioxide
Split Rock Energy Split Rock Energy LLC
Square Butte Square Butte Electric Cooperative
Standard & Poor's Standard & Poor's Ratings Services, a
division of The McGraw-Hill Companies,
Inc.
SWL&P Superior Water, Light and Power Company
Taconite Harbor Taconite Harbor Energy Center
Town Center Town Center at Palm Coast development
project in Florida
Town Center District Town Center at Palm Coast Community
Development District
WDNR Wisconsin Department of Natural Resources
3 ALLETE 2006 Form 10-K
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SAFE HARBOR STATEMENT
UNDER THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995
In connection with the safe harbor provisions of the Private Securities Litigation Reform Act of 1995, we are hereby filing cautionary statements identifying important factors that could cause our actual results to differ materially from those projected in forward-looking statements (as such term is defined in the Private Securities Litigation Reform Act of 1995) made by or on behalf of ALLETE in the 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," "projects," "will likely result," "will continue," "could," "may," "potential," "target," "outlook" or similar expressions) are not statements of historical facts and may be forward-looking.
Forward-looking statements involve estimates, assumptions, risks and uncertainties, which are beyond our control and may cause actual results or outcomes to differ materially from those that may be projected. These statements are qualified in their entirety by reference to, and are accompanied by, the following important factors, in addition to any assumptions and other factors referred to specifically:
- our ability to successfully implement our strategic objectives;
- our ability to manage expansion and integrate acquisitions;
- prevailing governmental policies and regulatory actions, including
those of the United States Congress, state legislatures, the FERC, the
MPUC, the PSCW, and various local and county regulators, and city
administrators, about allowed rates of return, financings, industry and
rate structure, acquisition and disposal of assets and facilities, real
estate development, operation and construction of plant facilities,
recovery of purchased power and capital investments, present or
prospective wholesale and retail competition (including but not limited
to transmission costs), and zoning and permitting of land held for
resale;
- effects of restructuring initiatives in the electric industry;
- economic and geographic factors, including political and economic
risks;
- changes in and compliance with laws and policies;
- weather conditions;
- natural disasters and pandemic diseases;
- war and acts of terrorism;
- wholesale power market conditions;
- population growth rates and demographic patterns;
- effects of competition, including competition for retail and wholesale
customers;
- changes in the real estate market;
- pricing and transportation of commodities;
- changes in tax rates or policies or in rates of inflation;
- unanticipated project delays or changes in project costs;
- availability of construction materials and skilled construction labor
for capital projects;
- unanticipated changes in operating expenses and capital expenditures;
- global and domestic economic conditions;
- our ability to access capital markets and bank financing;
- changes in interest rates and the performance of the financial markets;
- our ability to replace a mature workforce, and retain qualified,
skilled and experienced personnel; and
- the outcome of legal and administrative proceedings (whether civil or
criminal) and settlements that affect the business and profitability of
ALLETE.
Additional disclosures regarding factors that could cause our results and performance to differ from results or performance anticipated by this report are discussed in Item 1A under the heading "Risk Factors" beginning on page 24 of this Form 10-K. Any forward-looking statement speaks only as of the date on which such statement is made, and we undertake no obligation to update any forward-looking statement to reflect events or circumstances after the date on which that 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 these factors, nor can it assess the impact of each of these factors on the businesses of ALLETE or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statement. Readers are urged to carefully review and consider the various disclosures made by us in this Form 10-K and in our other reports filed with the SEC that attempt to advise interested parties of the factors that may affect our business.
ALLETE 2006 Form 10-K 4
PART I
ITEM 1. BUSINESS
ALLETE has been incorporated under the laws of Minnesota since 1906. ALLETE's corporate headquarters are in Duluth, Minnesota. As of December 31, 2006, we had approximately 1,500 employees, 100 of which were part-time. Statistical information is presented as of December 31, 2006, unless otherwise indicated. All subsidiaries are wholly owned unless otherwise specifically indicated. References in this report to "we," "us" and "our" are to ALLETE and its subsidiaries, collectively.
ALLETE makes its SEC filings, including its annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and any amendments to those reports, available free of charge on ALLETE's Website www.allete.com, as soon as reasonably practicable after they are electronically filed with or furnished to the SEC.
ALLETE is a diversified company providing fundamental products and services. This includes our two core businesses--ENERGY and REAL ESTATE, as well as former operations in the water, paper, telecommunication and automotive industries.
ENERGY is comprised of Regulated Utility, Nonregulated Energy Operations and Investment in ATC.
- REGULATED UTILITY includes retail and wholesale rate regulated electric, natural gas and water services in northeastern Minnesota and northwestern Wisconsin under the jurisdiction of state and federal regulatory authorities.
- NONREGULATED ENERGY OPERATIONS includes our coal mining activities in North Dakota, approximately 50 MW of nonregulated generation and Minnesota land sales.
In 2004 and 2005, Nonregulated Energy Operations also included nonregulated generation from our Taconite Harbor facility in northern Minnesota, and generation secured through the Kendall County power purchase agreement. Effective January 1, 2006, Taconite Harbor was integrated into our Regulated Utility business to help meet forecasted base load energy requirements. In April 2005, the Kendall County power purchase agreement was assigned to Constellation Energy Commodities.
- INVESTMENT IN ATC includes our equity ownership interest in ATC.
REAL ESTATE includes our Florida real estate operations.
OTHER includes our investments in emerging technologies, and earnings on cash and short-term investments.
YEAR ENDED DECEMBER 31 2006 2005 2004
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Consolidated Operating Revenue - Millions $767.1 $737.4 $704.1
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Percentage of Consolidated Operating Revenue
Regulated Utility
Industrial
Taconite Producers 24% 23% 25%
Paper and Wood Products 9 9 9
Pipelines and Other Industries 6 6 7
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Total Industrial 39 38 41
Residential 10 10 11
Commercial 11 11 11
Municipals 5 5 4
Other Power Suppliers 12 7 5
Other Revenue 6 7 7
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Total Regulated Utility 83 78 79
Nonregulated Energy Operations 9 16 15
Real Estate 8 6 6
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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.
5 ALLETE 2006 Form 10-K
DISCONTINUED OPERATIONS. In the past five years, we also had business operations in the automotive, water and telecommunications industries.
SPIN-OFF OF AUTOMOTIVE SERVICES. Through a June 2004 IPO, our Automotive Services business, doing business as ADESA, Inc. (NYSE: KAR), issued 6.3 million shares of common stock, representing 6.6% of ADESA's common stock outstanding. In September 2004, we spun off the business by distributing to ALLETE shareholders all of ALLETE's remaining 93.4% of ADESA common stock.
SALE OF WATER SERVICES BUSINESSES. In early 2005, we completed the exit from our Water Services businesses with the sale of our wastewater assets in Georgia. In mid-2004, we sold our North Carolina water and wastewater assets, and our remaining 72 water and wastewater systems in Florida. Substantially all of our water assets in Florida were sold in 2003, under condemnation or imminent threat of condemnation. The net cash proceeds from the sale of all water and wastewater assets, after transaction costs, retirement of most Florida Water debt and payment of income taxes, were approximately $300 million.
SALE OF ENVENTIS TELECOM. On December 30, 2005, we sold all the stock of our telecommunications subsidiary, Enventis Telecom for $35.5 million. The transaction resulted in an after-tax loss of $3.6 million, which was included in our 2005 loss from discontinued operations. Net cash proceeds realized from the sale were approximately $29 million after transaction costs, repayment of debt and payment of income taxes.
ENERGY - REGULATED UTILITY
MINNESOTA POWER, an operating division of ALLETE, provides regulated utility electric service in a 26,000 square-mile service territory in northeastern Minnesota to 140,000 retail customers and wholesale electric service to 16 municipalities. SWL&P provides regulated utility electric, natural gas and water service in northwestern Wisconsin to 14,000 electric customers, 12,000 natural gas customers and 10,000 water customers.
Minnesota Power had an annual net peak load of 1,586 MW on July 28, 2006. Our regulated power supply sources are listed below.
FOR THE YEAR ENDED
REGULATED UTILITY UNIT YEAR NET WINTER DECEMBER 31, 2006
POWER SUPPLY NO. INSTALLED CAPABILITY ELECTRIC REQUIREMENTS
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MW MWh %
Steam
Coal-Fired
Boswell Energy Center 1 1958 69
in Cohasset, MN 2 1960 69
3 1973 351
4 1980 428
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917 6,380,647 48.9%
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Laskin Energy Center 1 1953 55
in Hoyt Lakes, MN 2 1953 55
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110 623,975 4.8
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Taconite Harbor Energy Center 1, 2 & 3 1957, 1957
in Taconite Harbor, MN 1967 220 1,466,803 11.2
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Purchased Steam
Hibbard Energy Center in Duluth, MN 3 & 4 1949, 1951 50 79,731 0.6
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Total Steam 1,297 8,551,156 65.5
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Hydro
Group consisting of ten stations in MN Various 115 343,729 2.6
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Total Company Generation 1,412 8,894,885 68.1
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Purchased Power
Square Butte burns lignite coal near Center, ND 299 2,069,700 15.9
Oliver Wind I Energy Center near Center, ND 50 12,696 -
All Other - Net - 2,071,481 16.0
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Total Purchased Power 349 4,153,877 31.9
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Total 1,761 13,048,762 100.0%
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ALLETE 2006 Form 10-K 6
ENERGY - REGULATED UTILITY (CONTINUED)
We have electric transmission and distribution lines of 500 kV (8 miles), 230 kV (605 miles), 161 kV (43 miles), 138 kV (126 miles), 115 kV (1,209 miles) and less than 115 kV (6,875 miles). We own and operate 169 substations with a total capacity of 9,525 megavoltamperes. Some of our transmission and distribution lines interconnect with other utilities.
We own offices and service buildings, an energy control center and repair shops, and lease offices and storerooms in various localities. Substantially all of our electric plant is subject to mortgages, which collateralize the outstanding first mortgage bonds of Minnesota Power and of SWL&P. Generally, we hold fee interest in our real properties subject only to the lien of the mortgages. Most of our electric lines are located on land not owned in fee, but are covered by appropriate easement rights or by necessary permits from governmental authorities. Wisconsin Public Power, Inc. (WPPI) owns 20% of Boswell Unit 4. WPPI has the right to use our transmission line facilities to transport its share of Boswell generation. (See Note 4.)
SPLIT ROCK ENERGY was a joint venture between Minnesota Power and Great River Energy. In March 2004, we terminated our ownership interest upon receipt of FERC approval.
ELECTRIC SALES
Our regulated utility operations include retail and wholesale activities under the jurisdiction of state and federal regulatory authorities. (See Regulatory Issues.)
REGULATED UTILITY ELECTRIC SALES
YEAR ENDED DECEMBER 31 2006 2005 2004
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MILLIONS OF KILOWATTHOURS
Retail and Municipals
Residential 1,100 1,102 1,053
Commercial 1,335 1,327 1,282
Industrial 7,206 7,130 7,071
Municipals and Other 990 956 902
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10,631 10,515 10,308
Other Power Suppliers <F1> 2,153 1,142 918
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12,784 11,657 11,226
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<F1> Effective January 1, 2006, Taconite Harbor was redirected from Nonregulated Energy Operations to Regulated Utility.
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Approximately 60% of the ore consumed by integrated steel facilities in the United States originates from six 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. Strong worldwide steel demand, driven largely by extensive infrastructure development in China, has resulted in very robust world iron ore demand and steel pricing. This globalization of demand has positively impacted Minnesota taconite producers, which all produced near their rated capacities in both 2006 and 2005. Annual taconite production in Minnesota was 40 million tons in 2006 (41 million tons in both 2005 and 2004) and is estimated to be 40 million tons in 2007. Recent consolidation activities, combined with the strong steel market, have placed the Minnesota taconite producers in a strong competitive position.
In addition to serving the taconite industry, Minnesota Power also serves a number of customers in the paper and pulp, and wood products industry. In total, we serve four major paper and pulp mills directly and one paper mill indirectly by providing wholesale service to the retail provider of the mill. Minnesota Power also serves four wood products manufacturers. In 2006, approximately 90% of our revenue from this industry sector came from the paper and pulp producers, and 10% came from the wood products customers.
Minnesota Power's paper and pulp customers ran at or very near full capacity in 2006 despite the fact that the industry continued to face high fiber, chemical and energy costs as well as competition from exports in certain grades. Minnesota Power's customers benefited from the temporary or permanent idling of capacity in North America at mills other than those served by Minnesota Power and from the strength of the Euro. Wood products customers ran at reduced capacity levels or were temporarily idled in the last third of 2006 because of high wood prices and a decreasing number of new housing starts.
The pipeline and refining industry is the third key industrial segment served by Minnesota Power with services provided to two crude oil pipelines and one refinery. These customers have a common reliance on the importation of Canadian crude oil. After years of near capacity operation in 2005 and 2006, both pipeline operators are executing expansion plans to transport newly developed Western Canadian crude oil reserves (Alberta Oil Sands) to United States markets. Access to traditional Midwest markets is being expanded to Southern markets as the Canadian supply is displacing domestic production and deliveries imported from the Gulf Coast.
7 ALLETE 2006 Form 10-K
ENERGY - REGULATED UTILITY (CONTINUED)
LARGE POWER CUSTOMER CONTRACTS. Minnesota Power has large power customer contracts with 12 customers (Large Power Customers), 11 of which require 10 MW or more of generating capacity and one that requires at least 8 MW of generating capacity. In 2006, a contract for approximately 70 MW was successfully negotiated with PolyMet Mining, a new customer planning to start a copper, nickel and precious metals (non-ferrous) mining operation by late 2008. If PolyMet's environmental permits are received and start-up is achieved, the contract with PolyMet Mining will run through at least 2018. The PolyMet Mining contract requires MPUC approval.
Large Power Customer contracts require Minnesota Power to have a certain amount of generating capacity available. (See Minimum Revenue and Demand Under Contract table below.) In turn, each Large Power Customer is required to pay a minimum monthly demand charge that covers the fixed costs associated with having this 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 biannual (power pool season) or four-month basis and require that a portion of their megawatt needs be committed on a take-or-pay basis for at least a portion 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 provides a discounted demand rate and energy priced at Minnesota Power's incremental cost after serving all firm power obligations. Minnesota Power 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 Minnesota Power's cost. Incremental production service is interruptible.
All contracts continue past the contract termination date, unless the required advance notice of cancellation has been given. The advance notice of cancellation varies from one to four years. 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 take all of their purchased electric service requirements from Minnesota Power 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. (See Regulatory Issues - Electric Rates.)
Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates. The customers receive estimated bills based on Minnesota Power's prediction of the customer's energy usage, forecasted energy prices and fuel clause adjustment estimates. Minnesota Power's five taconite-producing Large Power Customers have generally predictable energy usage on a week-to-week basis, which makes the variance between the estimated usage and actual usage small. Taconite-producing Large Power Customers subject to weekly billings receive interest on the money paid to Minnesota Power within the billing cycle.
MINIMUM REVENUE AND DEMAND UNDER CONTRACT MINIMUM ANNUAL MONTHLY
AS OF FEBRUARY 1, 2007 DEMAND REVENUE <F1><F2> MEGAWATTS
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2007 $62.5 million 390
2008 $29.3 million 167
2009 $25.9 million 148
2010 $25.8 million 148
2011 $16.1 million 88
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<F1> Based on past experience, we believe revenue from our Large Power Customers will be substantially in excess of the minimum
contract amounts. For example, in our 2005 Form 10-K we stated 2006 minimum annual revenue from these Large Power Customers
would be $61.3 million. Actual 2006 demand revenue from these Large Power Customers was $116.9 million.
<F2> Although several contracts have a feature that allows demand to go to zero after a two-year advance notice of a permanent
closure, this minimum revenue summary does not reflect this occurrence happening in the forecasted period because we believe
it is unlikely.
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ALLETE 2006 Form 10-K 8
ENERGY - REGULATED UTILITY (CONTINUED)
CONTRACT STATUS FOR MINNESOTA POWER LARGE POWER CUSTOMERS
AS OF FEBRUARY 1, 2007
EARLIEST
CUSTOMER INDUSTRY LOCATION OWNERSHIP TERMINATION DATE
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Hibbing Taconite Co. <F1> Taconite Hibbing, MN 62.3% Mittal Steel USA Inc. February 28, 2011
23% Cleveland-Cliffs Inc
14.7% Stelco Inc.
Mittal Steel USA - Minorca Mine Taconite Virginia, MN Mittal Steel USA Inc. December 31, 2012
United States Steel Corporation Taconite Mt. Iron, MN USS October 31, 2013
(USS) Minntac
USS Keewatin Taconite Taconite Keewatin, MN USS October 31, 2013
United Taconite LLC <F1> Taconite Eveleth, MN 70% Cleveland-Cliffs Inc February 28, 2011
30% Laiwu Steel Group
UPM, Blandin Paper Mill <F1> Paper Grand Rapids, MN UPM-Kymmene Corporation February 28, 2011
Boise White Paper, LLC Paper International Falls, MN Madison Dearborn December 31, 2008
Partnership
Sappi Cloquet LLC <F1> Paper Cloquet, MN Sappi Limited February 28, 2011
Stora Enso North America, Paper and Pulp Duluth, MN Stora Enso Oyj August 31, 2013
Duluth Paper Mill and
Duluth Recycled Pulp Mill
USG Interiors, Inc. <F2> Manufacturer Cloquet, MN USG Corporation February 28, 2008
Enbridge Energy Company, Pipeline Deer River, MN Enbridge Energy Company, February 28, 2008
Limited Partnership <F2> Floodwood, MN Limited Partnership
Minnesota Pipeline Company <F2> Pipeline Staples, MN 60% Koch Pipeline Co. L.P. February 28, 2008
Little Falls, MN 40% Marathon Ashland
Park Rapids, MN Petroleum LLC
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<F1> The contract will terminate four years from the date of written notice from either Minnesota Power or the customer. No notice
of contract cancellation has been given by either party. Thus, the earliest date of cancellation is February 28, 2011.
<F2> The contract will terminate one year from the date of written notice from either Minnesota Power or the customer. No notice of
contract cancellation has been given by either party. Thus, the earliest date of cancellation is February 28, 2008.
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PURCHASED POWER
Minnesota Power has contracts to purchase capacity and energy from various
entities, the largest is with Square Butte. Under an agreement with Square Butte
expiring at the end of 2026, Minnesota Power is currently entitled to
approximately 60% (55% beginning in 2008; 50% in 2009 and thereafter) of the
output of a 455-MW coal-fired generating unit located near Center, North Dakota.
(See Note 8.)
In May 2005, Minnesota Power entered into a 25-year agreement with an affiliate of FPL Energy to purchase all of the renewable energy from Oliver Wind I, an approximately 50-MW (nameplate) wind facility in North Dakota. Oliver Wind I commenced commercial operation in late December 2006 and is comprised of 22 new 2.3-MW wind turbines. In addition, in December 2006, Minnesota Power and an affiliate of FPL Energy reached an agreement for Minnesota Power to purchase an additional 48 MW of wind energy from an expansion of Oliver Wind I. If regulatory approvals and permits are received, FPL Energy expects the expansion, Oliver Wind II, to be operational by late 2007. Minnesota Power is also continuing to pursue additional agreements for wind energy from new facilities being planned within Minnesota Power's service territory. The projects, expected to be operational in late 2007 or 2008, would be smaller in size than the North Dakota projects and would be subject to negotiation and execution of power purchase agreements, as well as regulatory approvals.
9 ALLETE 2006 Form 10-K
ENERGY - REGULATED UTILITY (CONTINUED)
FUEL
Minnesota Power purchases low-sulfur, sub-bituminous coal from the Powder River Basin coal region located in Montana and Wyoming. Coal consumption in 2006 for electric generation at Minnesota Power's coal-fired generating stations was about 5 million tons. As of December 31, 2006, Minnesota Power had a coal inventory of about 800,000 tons. Minnesota Power has two coal supply agreements with expiration dates extending through 2009 and one contract with an initial term expiring in 2008. Under these agreements, Minnesota Power has the tonnage flexibility to procure 70% to 100% of its total coal requirements. In 2007, Minnesota Power will obtain coal under these coal supply agreements and in the spot market. This diversity in coal supply options allows Minnesota Power to manage market price and supply risk and to take advantage of favorable spot market prices. Minnesota Power is exploring future coal supply options. We believe that adequate supplies of low-sulfur, sub-bituminous coal will continue to be available.
In 2001, Minnesota Power and Burlington Northern and Santa Fe Railway Company (Burlington Northern) entered into a long-term agreement under which Burlington Northern transports all of Minnesota Power's coal by unit train from the Powder River Basin directly to Minnesota Power's generating facilities or to a designated interconnection point. Minnesota Power also has agreements with the Canadian National Railway and Midwest Energy Resources Company to transport coal from the Burlington Northern interconnection point to certain Minnesota Power facilities.
COAL DELIVERED TO MINNESOTA POWER YEAR ENDED DECEMBER 31 2006 2005 2004 --------------------------------------------------------------------------------------------------------------------------- Average Price per Ton $20.19 $19.76 $19.01 Average Price per MBtu $1.10 $1.08 $1.04 --------------------------------------------------------------------------------------------------------------------------- |
The Square Butte generating unit operated by Minnkota Power burns North Dakota lignite coal supplied by BNI Coal, in accordance with the terms of a contract expiring in 2027. Square Butte's cost of lignite burned in 2006 was approximately 85 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 fuel for the anticipated useful life of the generating unit.
REGULATORY ISSUES
We are subject to the jurisdiction of various regulatory authorities. The MPUC has regulatory authority over Minnesota Power's 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, natural gas and water by SWL&P. The MPUC, FERC and PSCW had regulatory authority over 56%, 8% and 8%, respectively, of our 2006 consolidated operating revenue.
ELECTRIC RATES. Minnesota Power 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, recovery of current and deferred conservation improvement program expenditures, and recovery of certain environmental expenditures.
In addition to Large Power Customer contracts, Minnesota Power also has contracts with large industrial and commercial customers with monthly demands of more than 2 MW but less than 10 MW of capacity. The terms of these contracts vary depending upon the customer's demand for power and the cost of extending Minnesota Power's facilities to provide electric service.
Minnesota Power requires that all large industrial and commercial customers under contract specify the date when power is first required. Thereafter, the customer is generally billed monthly 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 rates and other contract terms are subject to approval by appropriate regulatory authorities.
ALLETE 2006 Form 10-K 10
ENERGY - REGULATED UTILITY (CONTINUED)
FEDERAL ENERGY REGULATORY COMMISSION. The FERC has jurisdiction over our wholesale electric service and operations. Minnesota Power's hydroelectric facilities, which are located in Minnesota, are licensed by the FERC.
In August 2005, President Bush signed into law the Energy Policy Act of 2005 (EPAct 2005), which repealed PUHCA 1935 and enacted PUHCA 2005. PUHCA 2005 gives FERC certain authority over books and records of public utility holding companies and their affiliates. It also addresses FERC review and authorization of the allocation of costs for non-power goods, or administrative or management services when requested by a holding company system or state commission. In addition, EPAct 2005 directs the FERC to issue certain rules addressing electricity reliability, investment in energy infrastructure, fuel diversity for electric generation, and promotion of energy efficiency and wise energy use. The FERC is currently in the process of implementing EPAct 2005. These include (among others):
- rulemaking for implementing long-term transmission rights;
- dockets pertaining to the development and certification of electric
reliability organizations, including delegated authority to regional
entities for proposing and enforcing reliability standards;
- rules specifying the form of applications for federal construction
permits to be issued in the exercise of federal backstop siting
authority for transmission projects;
- rulemaking requiring unregulated transmitting utilities to provide open
access to their transmission systems;
- various rulemakings regarding the consideration of merger applications
under the revised Federal Power Act Section 203;
- a U.S. Department of Energy study/report on the benefits of economic
dispatch and a report on recommendations of regional joint boards that
considered economic dispatch;
- rulemaking to facilitate transmission market transparency; and
- the energy market manipulation rulemaking.
We continue to monitor FERC activity in these and other proceedings.
MUNICIPAL AND WHOLESALE CUSTOMERS. Minnesota Power has contracts with 16 Minnesota municipalities receiving wholesale electric service. One contract expires April 2008 (31,000 MWh purchased in 2006), while the other 15 are for service through at least January 2011. In 2006, these municipal customers purchased 813,000 MWh from Minnesota Power. Minnesota Power also has a contract for wholesale service with Dahlberg Light & Power Company (Dahlberg) in Wisconsin. Dahlberg purchased 111,000 MWh in 2006.
MIDWEST INDEPENDENT TRANSMISSION SYSTEM OPERATOR, INC. (MISO). Minnesota Power and SWL&P are members of MISO. MISO was the first regional transmission organization (RTO) approved by the FERC as meeting its Order No. 2000 criteria. Minnesota Power and SWL&P retain ownership of their respective transmission assets and control area functions, but their transmission network is under the regional operational control of MISO, and they take and provide transmission service under MISO open access transmission tariff. MISO continues its efforts to standardize rates, terms and conditions of transmission service over its broad region, which encompasses all or parts of 15 states and one Canadian province, and over 100,000 MW of generating capacity.
MID-CONTINENT AREA POWER POOL (MAPP). Minnesota Power also participates in MAPP, a power pool operating in parts of eight states in the Upper Midwest and in two provinces in Canada. MAPP functions include a regional transmission committee and a generation reserve-sharing pool. Minnesota Power is also a member of the Midwest Reliability Organization that was established as a regional reliability council within the North American Electric Reliability Council on January 1, 2005.
MINNESOTA PUBLIC UTILITIES COMMISSION. Minnesota Power's retail rates are based on a 1994 MPUC retail rate order that allows for an 11.6% return on common equity dedicated to utility plant. Minnesota Power does not expect to file a request to increase rates for its retail utility operations during 2007. We will, however, continue to monitor the costs of serving our retail customers and evaluate the need for a rate filing in the future. Retail rates will be adjusted without a rate proceeding to reflect recovery of costs related to the Arrowhead Regional Emission Abatement plan (see AREA Plan).
LARGE POWER CONTRACTS. In 2006, the MPUC approved Minnesota Power's new electric service agreement through August 2013 with Stora Enso's Duluth mills and a new electric service agreement through February 2011 with Blandin Paper's Grand Rapids facilities. Also in 2006, Minnesota Power reached an agreement with PolyMet Mining to provide all of its electric service needs through at least 2018. PolyMet Mining plans to begin commercial operations by late 2008, pending completion of financing arrangements and receipt of regulatory approvals. Once fully operational, it is anticipated that PolyMet will require approximately 70 MW. The PolyMet Mining electric service agreement requires MPUC approval.
11 ALLETE 2006 Form 10-K
ENERGY - REGULATED UTILITY (CONTINUED)
RESOURCE PLAN. In September 2004, Minnesota Power filed its Integrated Resource Plan (Resource Plan) with the MPUC. A November 2006 update to our Advance Forecast contained a revised projection showing our winter peak demand by customers in our service territory is expected to increase at an average annual growth rate of 1.5% through 2011. We project an additional capacity need of approximately 150 MW by 2010, with another 200 MW of capacity need anticipated by 2015. These forecasted capacity needs are a combination of increased customer demand and decreases in our existing capacity supply. Increased demand is anticipated from residential and smaller commercial growth as well as from a positive outlook for our Large Power Customers in northeastern Minnesota. Minnesota Power will also realize a reduction in generating resource supply over the next two years under the terms of a long-term energy supply contract with Square Butte. The combination of increased demand and reduced supply means Minnesota Power will need to secure additional capacity and energy to serve our customers in future years. In the Resource Plan, we provided several options designed to replace the Square Butte reductions and meet the predicted growing demand in the region.
In 2006, the MPUC approved our Resource Plan. One of the key components of the Resource Plan was the redirection of our Taconite Harbor generating facility from Nonregulated Energy Operations to Regulated Utility operations effective January 1, 2006. We have also entered into a 50-MW long-term power purchase agreement with Manitoba Hydro, which will be effective from May 2009 to April 2015. This agreement was executed in June 2006 and filed for approval with the MPUC in January 2007. The MPUC also approved expansion of our renewable generating assets to meet Minnesota's Renewable Energy Objective which seeks a 10% supply of qualified renewable energy resources for each Minnesota utility by 2015. In 2006, Oliver Wind I, a 50-MW wind facility in North Dakota, was constructed and placed in service. We began purchasing Oliver Wind I output under a 25-year power purchase agreement with an affiliate of FPL Energy in late December 2006.
Minnesota Power has executed a power purchase agreement for an additional 48 MW of wind energy from an expansion of Oliver Wind I. The expansion, Oliver Wind II, is expected to be completed and operational by late 2007. Minnesota Power is also pursuing additional agreements for wind energy from new facilities being planned within Minnesota Power's service territory and is considering 10 MW of additional hydro generation through an expansion of the Fond du Lac hydroelectric station.
The Company is required to file its next Resource Plan with the MPUC by November 1, 2007.
We are exploring various construction and purchase options for our anticipated resource needs in 2015. These options include:
- NORTH DAKOTA GENERATION STUDY. In December 2005, Minnesota Power, Basin Electric Power Cooperative, Minnkota Power and Montana-Dakota Utilities Company announced a project development agreement to evaluate the feasibility of a joint lignite-fueled generating resource in the vicinity of the existing Milton R. Young generating station (which includes Square Butte) near Center, North Dakota. The feasibility study is currently underway and any final resource decision by Minnesota Power is subject to MPUC and other approvals.
- MESABA ENERGY PROJECT. Excelsior Energy Inc. (Excelsior) is a Minnesota-based independent energy development company. Excelsior has proposed to construct two 600-MW (net) coal-gasification generation units in northern Minnesota. This project is in the early development stages but may be an option for our long-term forecasted energy and capacity needs. Excelsior says the facility could be operational in 2011, but it needs to obtain necessary permits and financing. In 2003, the Minnesota legislature enacted several provisions that provide Excelsior with special considerations, including requiring utilities within the state to "consider" Excelsior before pursuing new fossil-fuel-fired resource additions. This was done as part of Xcel Energy Inc.'s (Xcel) Prairie Island nuclear waste storage reauthorization. Excelsior is "entitled" to enter into a 450-MW power sales agreement with Xcel, subject to MPUC approval. In December 2005, Excelsior filed with the MPUC a petition for approval of terms and conditions for the sale of power to Xcel under these statutory provisions. Other utilities in the state, including Minnesota Power, "must consider" Excelsior before pursuing new fossil-fuel-fired resource additions. In January 2006, Minnesota Power filed comments with the MPUC in Excelsior's proposed power purchase agreement proceeding. Our comments focused on the importance to the state of maintaining a range of base load energy options including multiple fuel types and generating technologies. In April 2006, the MPUC referred Excelsior's petition to an administrative law proceeding to further develop the record in the case for subsequent MPUC deliberations. Minnesota Power continues to be a participant in these proceedings, focusing its comments on energy policy and infrastructure impacts.
- NATURAL GAS COMBINED CYCLE GENERATION. Minnesota Power is also continuing to study the feasibility of the construction of a natural gas-fired electric generating facility which could be located in northwestern Wisconsin or northeastern Minnesota.
ALLETE 2006 Form 10-K 12
ENERGY - REGULATED UTILITY (CONTINUED)
ARROWHEAD REGIONAL EMISSION ABATEMENT PLAN (AREA PLAN). In May 2006, the MPUC approved Minnesota Power's $60 million environmental initiative. The AREA Plan approval allows Minnesota Power to recover Minnesota jurisdictional costs for SO2, NOX and mercury emission reductions made at its Taconite Harbor and Laskin facilities without a rate proceeding. The Minnesota cost recovery includes return on investment, depreciation, and incremental operations and maintenance expenses. The AREA Plan is expected to significantly reduce emissions from Taconite Harbor and Laskin, while maintaining a reliable and reasonably-priced energy supply to meet the needs of our customers. We believe that control and abatement technologies applicable to these plants have matured to the point where further significant air emission reductions can be attained in a relatively cost-effective manner.
Taconite Harbor will employ an innovative multi-emission reduction technology, while Laskin will receive a retrofit focused on lowering NOX emissions. The Company estimates an emission reduction of over 60% for NOX at both facilities and a 65% reduction in SO2 emissions at Taconite Harbor. Laskin already has relatively low emission levels of SO2 due to existing emission reduction technology. Additionally, with the emerging technology being applied at Taconite Harbor, there is the potential for a 90% reduction in mercury emissions.
Minnesota Power completed installation of new equipment at the first of two Laskin units in November 2006, with the first of three Taconite Harbor unit installations anticipated to be completed by mid-2007. Work on all units at Taconite Harbor and Laskin is anticipated to be completed by the end of 2008. Cost recovery filings are required to be made 90 days prior to the anticipated in-service date for the equipment at each unit, with rate recovery beginning the month following the in-service date. We began cost recovery of AREA plan costs in December 2006 with the placement in service of Laskin Unit 2. We filed with the MPUC for cost recovery on Laskin Unit 1 in January 2007 and expect to begin cost recovery in May 2007. We anticipate beginning cost recovery on Taconite Harbor Unit 2 in mid-2007 and Taconite Harbor Units 1 and 3 in 2008. AREA plan expenditures as of December 31, 2006, were $11.4 million.
BOSWELL UNIT 3 EMISSION REDUCTION PLAN. In May 2006, we announced plans to make emission reduction investments at our Boswell Unit 3 generating unit. Plans include reductions of particulate, SO2, NOX and mercury emissions to meet pending federal and state requirements. The estimated capital cost for these reductions is approximately $200 million, of which $14 million was spent in 2006 for design engineering and related costs. The balance is expected to be spent from 2007 through 2009. In October 2006, we submitted a filing to the MPCA for approval of the Boswell Unit 3 emission reduction plan. A filing with the MPUC for approval of Minnesota jurisdictional related expenditures on Boswell Unit 3 was made in January 2007 to allow cost recovery on these investments without a rate proceeding. MPUC approval would authorize a cash return on construction work in progress during the construction phase and allow recovery for a return on investment, depreciation, and incremental operations and maintenance expenses once the unit is placed into service in late 2009. We expect to begin cost recovery on construction work in progress in 2008. In 2007, we will be filing with the MPUC a request to extend the asset life for depreciation purposes on Boswell Unit 3 from 8 years to 29 years. We anticipate approval of this filing in 2007.
CONSERVATION IMPROVEMENT PROGRAMS (CIP). Minnesota requires investor-owned electric utilities to spend a minimum of 1.5% of gross annual retail electric revenue on CIP each year. These investments are recovered from retail customers through a billing adjustment and amounts included in retail base rates. 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. Minnesota Power's CIP investment goal was $3.2 million for 2006 ($3.2 million for 2005; $3.1 million for 2004), with actual spending of $3.8 million in 2006 ($3.6 million in 2005; $3.1 million in 2004).
PUBLIC SERVICE COMMISSION OF WISCONSIN. SWL&P's current retail rates are based on a December 2006 PSCW retail rate order that became effective January 1, 2007, and allows for an 11.1% return on common equity. New rates reflect a 2.8% average increase in retail utility rates for SWL&P customers (a 2.8% increase in electric rates, a 1.4% increase in natural gas rates and an 8.6% increase in water rates). SWL&P originally requested an average increase in retail utility rates of 5.2% in its 2006 application. The approved rates were lower than originally requested due to the subsequent removal of costs for a new water tower and electric substation from the original request. Both of these projects are now estimated to be in service in late 2008 because of delays in obtaining all the necessary construction approvals. SWL&P plans to file for another rate increase request in 2008. Previously, SWL&P's retail rates were based on a 2005 PSCW retail order that allowed for an 11.7% return on common equity.
13 ALLETE 2006 Form 10-K
ENERGY - REGULATED UTILITY (CONTINUED)
COMPETITION
We believe the overall impact of the EPAct 2005 on the electric utility industry has been positive and are continuing to evaluate the effects on our business as this legislation is being implemented. This federal legislation is designed to bring more certainty to energy markets in which ALLETE participates, as well as to provide investment incentives for energy efficiency, energy infrastructure (such as electric transmission lines) and energy production. The FERC has the responsibility of implementing numerous new standards as a result of the promulgation of EPAct 2005. So far the FERC's regulatory efforts appear to be generally positive for the utility industry.
EPAct 2005's repeal of the PUHCA 1935 should result in more capital flowing into the industry, while providing additional operational flexibility. The PUHCA 1935 repeal may also allow an acceleration of merger activity, as well as spawn moves by state regulators to adopt PUHCA-like regulations, although both events are speculative and difficult to predict.
We cannot predict the timing or substance of any future legislation or regulation.
FRANCHISES
Minnesota Power holds franchises to construct and maintain an electric distribution and transmission system in 90 cities and towns located within its electric service territory. SWL&P holds similar franchises for electric, natural gas and/or water systems 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. Our exclusive service territories are established by state regulatory agencies.
ENERGY - NONREGULATED ENERGY OPERATIONS
BNI COAL owns and operates a lignite mine in North Dakota. BNI Coal is a low-cost supplier of lignite in North Dakota, producing about 4 million tons annually. Two electric generating cooperatives, Minnkota Power and Square Butte, presently consume virtually all of BNI Coal's production of lignite under cost plus a fixed fee coal supply agreements expiring in 2027. (See Fuel and Note 8.) The mining process disturbs and reclaims approximately 210 acres per year. Laws require that the reclaimed land be at least as productive as it was prior to mining. The average cost to reclaim one acre of land is about $15,000, however, could be as high as $30,000. Reclamation costs are included in the cost of coal passed through to customers. In September 2004, BNI Coal entered into a master lease agreement with Farm Credit Leasing Services Corporation (Farm Credit). Under this agreement, BNI Coal leases a dragline that went into operation September 30, 2004. BNI Coal is obligated to make lease payments totaling $2.8 million annually for the 23-year lease term, which expires in 2027. BNI Coal will have the option at the end of the lease term to renew the lease at a fair market rental, to purchase the dragline at fair market value, or to surrender the dragline to Farm Credit and pay a $3.0 million termination fee. With lignite reserves of an estimated 600 million tons and new dragline equipment, BNI Coal has ample capacity to expand production.
NONREGULATED GENERATION consists of approximately 50 MW of generation, the majority of which is dedicated to the needs of one customer. In 2006, we sold 0.2 million MWh of nonregulated generation (1.5 million in 2005; 1.5 million in 2004). Effective January 1, 2006, Taconite Harbor was redirected from our Nonregulated Energy Operations segment to our Regulated Utility segment in accordance with the Company's Resource Plan, as approved by the MPUC.
UNIT YEAR YEAR NET
NONREGULATED POWER SUPPLY NO. INSTALLED ACQUIRED CAPABILITY
------------------------------------------------------------------------------------------------------------------------------------
MW
Steam
Wood-Fired <F1>
Cloquet Energy Center 5 2001 2001 22
in Cloquet, MN
Rapids Energy Center <F2> 6 & 7 1969, 1980 2000 30
in Grand Rapids, MN
------------------------------------------------------------------------------------------------------------------------------------
Hydro
Conventional Run-of-River
Rapids Energy Center <F2> 4 & 5 1917 2000 1
in Grand Rapids, MN
------------------------------------------------------------------------------------------------------------------------------------
<F1> Supplemented by coal.
<F2> The net generation is primarily dedicated to the needs of one customer.
|
ALLETE 2006 Form 10-K 14
ENERGY - NONREGULATED ENERGY OPERATIONS (CONTINUED)
TACONITE HARBOR. In 2002, we commenced operation of the Taconite Harbor generating facilities, which we purchased in 2001. The generation output was primarily sold in the wholesale market and was sold in limited circumstances to Minnesota Power's retail utility customers. Under the terms of our Resource Plan, we have operated the Taconite Harbor facility as a rate-based asset within the Minnesota retail jurisdiction since January 1, 2006. Prior to January 1, 2006, we operated our Taconite Harbor facility as nonregulated generation. (See Energy - Regulated Utility - Minnesota Public Utilities Commission.)
RAINY RIVER ENERGY has been engaged in the acquisition and development of nonregulated generation and wholesale power marketing. On April 1, 2005, Rainy River Energy completed the assignment of its power purchase agreement with LSP-Kendall Energy, LLC, the owner of an energy generation facility located in Kendall County, Illinois, to Constellation Energy Commodities. Rainy River Energy paid Constellation Energy Commodities $73 million in cash to assume the power purchase agreement, which is in effect through mid-September 2017. In addition, consent, advisory and closing costs of $4.9 million were incurred to complete the transaction. As a result of this transaction, ALLETE incurred a $77.9 million ($50.4 million after tax, or $1.84 per diluted share) charge in 2005.
RAINY RIVER ENERGY CORPORATION - WISCONSIN continues to study the feasibility of the construction of a natural gas-fired electric generating facility in northwestern Wisconsin. In accordance with the PSCW's final order approving the project, Rainy River Energy Corporation - Wisconsin undertook preliminary site preparation work in late 2003.
MINNESOTA LAND. We have about 15,000 acres of land in northern Minnesota, which is available for sale. We acquired this land in 2001 at the time we purchased Taconite Harbor from LTV Steel Mining Co. The cost basis of this land was $4.3 million at December 31, 2006.
ENERGY - INVESTMENT IN ATC
In December 2005, we entered into an agreement with Wisconsin Public Service Corporation and WPS Investments, LLC that provides for our Wisconsin subsidiary, Rainy River Energy Corporation - Wisconsin, to invest $60 million in ATC. ATC is a Wisconsin-based public utility that owns and maintains electric transmission assets in parts of Wisconsin, Michigan, Minnesota and Illinois. ATC provides transmission service under rates regulated by the FERC that are set in accordance with the FERC's policy of establishing the independent operation and ownership of, and investment in, transmission facilities. In May 2006, the PSCW reviewed and approved the request that allows us to invest in ATC. During 2006, we invested $51.4 million in ATC. We plan to invest an additional $8.6 million in ATC in early 2007 to reach our $60 million investment commitment and estimated 8% ownership interest. As of December 31, 2006, our equity investment balance in ATC was $53.7 million, representing approximately a 7% ownership interest. (See Note 6.) We will have the opportunity to make additional investments in ATC through general capital calls based upon our pro-rata investment level in ATC.
REAL ESTATE
ALLETE Properties is our real estate business that has operated in Florida since 1991. ALLETE Properties acquires real estate portfolios and large land tracts at bulk prices, adds value through entitlements and/or infrastructure improvements, and resells the property over time to developers, end-users and investors. ALLETE Properties is focused on acquiring vacant land in Florida and other parts of the southeast United States. Management at ALLETE Properties uses their business relationships, understanding of real estate markets and expertise in the land development and sales processes to provide revenue and earnings growth opportunities to ALLETE.
ALLETE Properties is headquartered in Fort Myers, Florida, the location of its southwest Florida regional office. We also have a regional office in Palm Coast, Florida, which oversees northeast Florida operations.
Southwest Florida operations consist of land sales and a third-party brokerage business, with limited land development activities. Inventory includes commercial and residential land located in Lehigh Acres and Cape Coral. The inventory represents the remaining properties acquired in 1991 from the Resolution Trust Corporation and in 1999 from Avatar Properties, Inc. The operation also generates rental income from a 186,000 square foot retail shopping center located in Winter Haven, Florida. The center is anchored by Macy's and Belk's department stores, along with Staples.
Northeast Florida operations focus on land sales and development activities. Development activities involve mainly zoning, permitting, platting and master infrastructure construction. Development costs are financed through a combination of community development district bonds, bank loans and internally-generated funds. Our three major development projects include Town Center at Palm Coast, Palm Coast Park and Ormond Crossings.
15 ALLETE 2006 Form 10-K
REAL ESTATE (CONTINUED)
TOWN CENTER. Town Center, which is located in the city of Palm Coast, is a mixed-use development with a neo-traditional downtown core area. Surrounded by major arterial roads, including Interstate 95, Town Center is adjacent to the Florida Hospital-Flagler, the Flagler County Airport and the Flagler Palm Coast High School. Sites have also been set aside for a new city hall, an arts and entertainment center, and other public uses. At build-out, Town Center is expected to include over 2,900 residential units, including lodging facilities, and 3.7 million square feet of various types of commercial space, including a movie theater. Future market conditions will determine how quickly Town Center is built out.
Construction of the major infrastructure improvements commenced in March 2005 and was substantially complete at the end of 2006. Infrastructure improvements include 3.6 miles of roads, a master storm water management system, underground utilities, street lights, sidewalks and bike paths, and extensive landscaping.
In March 2005, the Town Center at Palm Coast Community Development District (Town Center District) issued $26.4 million of tax exempt, 6% Capital Improvement Revenue Bonds, Series 2005, which are payable over 31 years (by May 1, 2036). The bond proceeds (less capitalized interest, a debt service reserve fund and cost of issuance) were used to pay for the construction of a portion of the major infrastructure improvements at Town Center. The bonds are being repaid by special assessments on all buildable land within Town Center. The special assessments were billed to Town Center landowners beginning in November 2006. To the extent that we still own land at the time of the assessment, we recognize the cost of our portion of these assessments based upon our ownership of benefited property. At December 31, 2006, we owned approximately 73% of the assessable land in the Town Center District. As we sell property, the obligation to pay special assessments will pass to the new landowners.
Additional Town Center development costs not funded through the Town Center District bond financing, estimated at $30 million (up to $11 million can be offset through traffic impact fee credits received over the life of the project), are being partially funded through an $8.5 million revolving development loan. The borrower is Florida Landmark. The development loan is guaranteed by Lehigh Acquisition Corporation. Florida Landmark is a wholly-owned subsidiary of Lehigh Acquisition Corporation which is an 80% owned subsidiary of ALLETE.
Pending land sales under contract for properties at Town Center were $40.1 million at December 31, 2006. We have the opportunity to receive participation revenue as part of one of these sales contracts. Among the pending Town Center sales contracts is a contract with Developers Realty Corporation (DRC) to develop projects in the downtown core area and a large retail shopping center on a 50-acre tract. DRC has entered into an agreement to form a joint venture with Weingarten Realty Investors (Weingarten). DRC/Weingarten has a commitment from a major national retail anchor for the retail shopping center.
Throughout 2005 and 2006, we focused on platting phases 1 and 2, which include the major roads and lots for a variety of uses, and developing the major infrastructure at Town Center. During that period, our marketing program targeted a blend of office, retail, commercial, residential and mixed-use project developers. In December 2006, a Publix grocery store anchored retail center opened and construction started on an 84,000 square foot medical center. Twenty other projects are in the permitting stage, 11 of which are expected to break ground in 2007. Future marketing efforts will focus on attracting the following additional land uses to Town Center: residential apartments, assisted living facilities, business park uses, and restaurants.
PALM COAST PARK. Palm Coast Park, which is located in the city of Palm Coast, is a 4,700-acre mixed-use development bisected by a 6-mile segment of U.S. Highway 1 about one mile from an existing Interstate 95 interchange and bounded on the west by a Florida East Coast Railroad rail line. At build-out, the project will include approximately 3.2 million square feet of commercial space and about 3,900 residential units ranging from affordable condominium units and apartments to estate golf course homes. Future market conditions will determine how quickly Palm Coast Park is built out.
In May 2006, the Palm Coast Park Community Development District (Palm Coast Park
District) issued $31.8 million of tax exempt, 5.7% Special Assessment Bonds,
Series 2006, which are payable over 31 years (by May 1, 2037). The bond proceeds
(less capitalized interest, a debt service reserve fund and cost of issuance)
are being used to pay for the construction of the major infrastructure
improvements at Palm Coast Park and to mitigate traffic and environmental
impacts. The bonds will be repaid by special assessments on all buildable land
within Palm Coast Park. The special assessments will be billed to Palm Coast
Park landowners beginning in November 2007. To the extent that we still own land
at the time of the assessment, we will recognize the cost of our portion of
these assessments based upon our ownership of benefited property. At December
31, 2006, we owned approximately 97% of the assessable land in the Palm Coast
Park District. As we sell property, the obligation to pay special assessments
will pass to the new landowners.
We are funding certain platting and permitting costs; however, the majority of ongoing and future development costs will be funded by Palm Coast Park District bond proceeds. We anticipate that the Palm Coast Park District will need to issue additional bonds to pay for the development of retail commercial, office and industrial lots.
Major infrastructure construction began in December 2006 and is expected to be completed in 2007. Commercial and industrial lots will be offered for sale in 2007, with closings anticipated to begin in 2008.
ALLETE 2006 Form 10-K 16
REAL ESTATE (CONTINUED)
Pending land sales under contract for properties at Palm Coast Park were $62.8 million at December 31, 2006. We have the opportunity to receive participation revenue as part of these sales contracts. One of the pending sales contracts is for the sale of five residential tracts and one commercial tract for $52.5 million. That sales contract provides for closings in 2007, 2008 and 2009. The project, which is named Sawmill Creek, will include up to 1,469 residential housing units, a championship golf course and neighborhood retail office space, along with a community park and elementary school. Other contracts include a residential tract for an affordable condominium project and a 600-unit single-family residential project that will be connected to the existing Matanzas Woods golf course neighborhood.
ORMOND CROSSINGS. Ormond Crossings is a 6,000-acre mixed-use development that is located in both the city of Ormond Beach in Volusia County and unincorporated Flagler County. The site is bisected by Interstate 95 and a Florida East Coast Railroad rail line and is adjacent to the city of Ormond Beach airport. Ormond Crossings has three miles of frontage on the east and west sides of Interstate 95 and will have two main entrances each within a mile from an existing U.S. Highway 1 and Interstate 95 interchange.
The Development of Regional Impact (DRI) development order for Ormond Crossings was approved by the city of Ormond Beach in December 2006, and provides for 5 million square feet of various types of commercial land uses and up to 3,700 residential units to be built in four phases. The Flagler County DRI development order is under review by the Flagler County Commission and, if approved, we will receive entitlements for up to 700 additional residential units. Actual build-out, however, will consider market demand as well as infrastructure and mitigation costs. Most of the developable part of Ormond Crossings is located in the city of Ormond Beach, so the project is not dependent upon receiving any further land use approvals from Flagler County. The Flagler County portion of the project will be mainly permitted for a wetland mitigation bank. Applications to permit the wetland mitigation bank were submitted in 2006 to St. Johns River Water Management District and the U.S. Army Corps of Engineers. Wetland mitigation credits will be used in connection with the permitting of development at Ormond Crossings and can also be sold to other developers.
After an agreement is finalized with the Florida Department of Transportation concerning traffic mitigation costs, we will determine the best economic build-out of the project. The agreement and economic analysis are expected to be completed in 2007.
Engineering design and permitting will be ongoing as the project is developed. We anticipate Ormond Crossings land sales closings starting in 2009.
OTHER LAND. In addition to the major development projects, land inventories in Florida include 3,300 acres of other property. Several smaller development projects are under way to plat these properties, add infrastructure, and modify and enhance existing entitlements.
Property sale prices may vary depending on location; physical characteristics; parcel size; whether parcels are sold as raw land, partially developed land or individually developed lots; degree and status of entitlement; and whether the land is ultimately purchased for residential, commercial or other form of development. In addition to minimum base price contracts, certain contracts allow us to receive participation revenue from land sales to third parties if various formula-based criteria are achieved.
ALLETE Properties occasionally provides seller financing. At December 31, 2006, outstanding finance receivables were $18.3 million, with maturities ranging up to ten years. These finance receivables accrue interest at market-based rates and are collateralized by the financed properties.
17 ALLETE 2006 Form 10-K
REAL ESTATE (CONTINUED)
SUMMARY OF DEVELOPMENT PROJECTS
FOR THE YEAR ENDED TOTAL RESIDENTIAL COMMERCIAL
DECEMBER 31, 2006 OWNERSHIP ACRES <F1> UNITS <F2> SQ. FT. <F2><F3>
-----------------------------------------------------------------------------------------------------------------------------
Town Center 80%
At December 31, 2005 1,480 2,833 2,927,700
Property Sold (124) (773) (401,971)
Change in Estimate <F1> - 162 179,581
-----------------------------------------------------------------------------------------------------------------------------
1,356 2,222 2,705,310
-----------------------------------------------------------------------------------------------------------------------------
Palm Coast Park 100%
At December 31, 2005 4,705 3,600 3,200,000
Property Sold (368) (200) -
Change in Estimate <F1> - 360 (43,200)
-----------------------------------------------------------------------------------------------------------------------------
4,337 3,760 3,156,800
-----------------------------------------------------------------------------------------------------------------------------
Ormond Crossings 100%
At December 31, 2005 5,960 <F4> <F4>
Change in Estimate <F1> -
-----------------------------------------------------------------------------------------------------------------------------
5,960
-----------------------------------------------------------------------------------------------------------------------------
11,653 5,982 5,862,110
-----------------------------------------------------------------------------------------------------------------------------
<F1> Acreage amounts are approximate and shown on a gross basis, including wetlands and minority interest. Acreage amounts may
vary due to platting or surveying activity. Wetland amounts vary by property and are often not formally determined prior
to sale.
<F2> Estimated and includes minority interest. The actual property breakdown at full build-out may be different than these
estimates.
<F3> Includes industrial, office and retail square footage.
<F4> A development order approval from the city of Ormond Crossings was received in December 2006, for up to 3,700 residential
units and 5 million commercial square feet. A development order from Flagler County is currently under review, and if
approved, Ormond Crossings will receive entitlements for up to 700 additional residential units. Actual build-out,
however, will consider market demand as well as infrastructure and mitigation costs.
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SUMMARY OF OTHER LAND INVENTORIES
FOR THE YEAR ENDED
DECEMBER 31, 2006 OWNERSHIP TOTAL MIXED USE RESIDENTIAL COMMERCIAL AGRICULTURAL
------------------------------------------------------------------------------------------------------------------------------
ACRES <F1>
Palm Coast Holdings 80%
At December 31, 2005 2,566 1,692 346 281 247
Property Sold (321) (288) - (30) (3)
Contributed Land (12) - - (4) (8)
Change in Estimate <F1> (97) - - - (97)
------------------------------------------------------------------------------------------------------------------------------
2,136 1,404 346 247 139
------------------------------------------------------------------------------------------------------------------------------
Lehigh 80%
At December 31, 2005 613 390 140 74 9
Property Sold (390) (390) - - -
------------------------------------------------------------------------------------------------------------------------------
223 - 140 74 9
------------------------------------------------------------------------------------------------------------------------------
Cape Coral 100%
At December 31, 2005 41 - 1 40 -
Property Sold (11) - - (11) -
------------------------------------------------------------------------------------------------------------------------------
30 - 1 29 -
------------------------------------------------------------------------------------------------------------------------------
Other <F2> 100%
At December 31, 2005 944 - - - 944
Property Sold (10) - - - (10)
------------------------------------------------------------------------------------------------------------------------------
934 - - - 934
------------------------------------------------------------------------------------------------------------------------------
3,323 1,404 487 350 1,082
------------------------------------------------------------------------------------------------------------------------------
<F1> Acreage amounts are approximate and shown on a gross basis, including wetlands and minority interest. Acreage amounts may
vary due to platting or surveying activity. Wetland amounts vary by property and are often not formally determined prior
to sale. The actual property breakdown at full build-out may be different than these estimates.
<F2> Includes land located in Ormond Beach, Florida, and other land located in Palm Coast, Florida not included in development
projects.
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ALLETE 2006 Form 10-K 18
REAL ESTATE (CONTINUED)
REGULATION
A substantial portion of our development properties in Florida is subject to federal, state and local regulations, and restrictions that may impose significant costs or limitations on our ability to develop the properties. Much of our property is vacant land and some is located in areas where development may affect the natural habitats of various protected wildlife species or in sensitive environmental areas such as wetlands.
Development of real property in Florida entails an extensive approval process involving overlapping regulatory jurisdictions. Real estate projects must generally comply with the provisions of the Local Government Comprehensive Planning and Land Development Regulation Act (Growth Management Act), which requires counties and cities to adopt comprehensive plans guiding and controlling future real property development in their respective jurisdictions. In addition, development projects that exceed certain specified regulatory thresholds require approval of a comprehensive DRI application. The DRI review process includes an evaluation of a project's impact on the environment, infrastructure and government services, and requires the involvement of numerous state and local environmental, zoning and community development agencies. Compliance with the Growth Management Act and the DRI process is usually lengthy and costly.
COMPETITION
The real estate industry is very competitive. Our properties are located in Florida. We are focused on acquiring additional vacant land in Florida and other parts of the southeast United States. This region continues to attract competitive real estate operations at many different levels in the land development pipeline. Competitors include local and out-of-state institutional investors, real estate investment trusts and real estate operators, among others. These competitors, both public and private, compete with us in seeking real estate for acquisition, resources for development and sales to prospective buyers. Consequently, competitive market conditions may influence the timing and profitability of our real estate transactions.
OTHER
Our Other segment consists of investments in emerging technologies related to the electric utility industry, and earnings on cash and short-term investments.
EMERGING TECHNOLOGY PORTFOLIO. As part of our emerging technology portfolio, we have several minority investments in venture capital funds and direct investments in privately-held, start-up companies. Since 1985, we have invested in start-up companies, which are developing technologies that may be utilized by the electric utility industry. We are committed to invest an additional $2.5 million in 2007 and do not have plans to make any additional investments. The investments were first made through emerging technology funds (Funds) initiated by other electric utilities and us. We have also made investments directly in privately-held companies.
Companies in the Funds' portfolios may complete IPOs, and the Funds may, in some instances, distribute publicly tradable shares to us. Some restrictions on sales may apply, including, but not limited to, underwriter lock-up periods that typically extend for 180 days following an IPO.
We account for our investment in venture capital funds under the equity method (see Note 15) and account for our direct investments in privately-held companies under the cost method because of our ownership percentage. The total carrying value of our emerging technology portfolio was $9.2 million at December 31, 2006, and December 31, 2005. Our policy is to review these investments quarterly for impairment by assessing such factors as continued commercial viability of products, cash flow and earnings. Any impairment would reduce the carrying value of the investment. Our basis in direct investments in privately-held companies included in the emerging technology portfolio was zero at December 31, 2006, and December 31, 2005. In 2005, we recorded $5.1 million ($3.3 million after tax) of impairments related to our direct investments in certain privately-held, start-up companies whose future business prospects had significantly diminished. Developments at these companies indicated that future commercial viability was unlikely, as was new financing necessary to continue development. In 2004, we recorded $6.5 million ($4.1 million after tax) of impairments.
19 ALLETE 2006 Form 10-K
ENVIRONMENTAL MATTERS
Our businesses are subject to regulation of environmental matters by various federal, state and local authorities. We consider our businesses to be in substantial compliance with those environmental regulations currently applicable to their operations and believe all necessary permits to conduct such operations have been obtained. Due to future stricter environmental requirements through legislation and/or rulemaking, we anticipate that potential expenditures for environmental matters will be material and will require significant capital investments. (See Item 7 - Capital Requirements.) We are unable to predict if and when any such stricter environmental requirements will be imposed and the impact they will have on the Company. We review environmental matters on a quarterly basis. Accruals for environmental matters are recorded when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated, based on current law and existing technologies. These accruals are adjusted periodically as assessment and remediation efforts progress or as additional technical or legal information becomes available. Accruals for environmental liabilities are included in the balance sheet at undiscounted amounts and exclude claims for recoveries from insurance or other third parties. Costs related to environmental contamination treatment and cleanup are charged to expense unless recoverable in rates from customers.
AIR. CLEAN AIR ACT. Minnesota Power's generating facilities mainly burn low-sulfur western sub-bituminous coal. Square Butte, located in North Dakota, burns lignite coal. All of these facilities are equipped with pollution control equipment such as scrubbers, bag houses or electrostatic precipitators. Permitted emission requirements are currently being met. The federal Clean Air Act Amendments of 1990 (Clean Air Act) created emission allowances for SO2. Each allowance is an authorization to emit one ton of SO2, and each utility must have sufficient allowances to cover its annual emissions. Most Minnesota Power facilities have surplus SO2 emission allowances, which were sufficient to cover the transfer of Taconite Harbor's generating assets to our Regulated Utility effective January 1, 2006, as approved by the MPUC. Square Butte is meeting its SO2 emission allowance requirements through increased use of its existing scrubber.
In accordance with the Clean Air Act, the EPA has established NOX limitations for electric generating units. To meet NOX limitations, Minnesota Power installed advanced low-emission burner technology and associated control equipment to operate the Boswell and Laskin facilities at or below the compliance emission limits. NOX limitations at Taconite Harbor and Square Butte are currently being met by combustion tuning.
CLEAN AIR INTERSTATE RULE AND CLEAN AIR MERCURY RULE. In March 2005, the EPA announced the final Clean Air Interstate Rule (CAIR) that reduces and permanently caps emissions of SO2 and NOX in the eastern United States. The CAIR includes Minnesota as one of the 28 states it considers an "eastern" state. The EPA also announced the final Clean Air Mercury Rule (CAMR) that reduces and permanently caps electric utility mercury emissions nationwide. The CAIR and the CAMR regulations have been challenged in the court system, which may delay implementation or modify provisions. Minnesota Power is participating in a legal challenge to the CAIR, but is not participating in the challenge of the CAMR. However, if the CAMR and the CAIR do go into effect, Minnesota Power expects to be required to (1) make emissions reductions, (2) purchase mercury, SO2 and NOX allowances through the EPA's cap-and-trade system, or (3) use a combination of both.
We believe that CAIR contains flaws in its methodology and application, which will cause Minnesota Power to incur significantly higher compliance costs. Minnesota Power petitioned that the EPA review its CAIR determinations that affected Minnesota. In July 2005, Minnesota Power also filed a Petition for Review with the U.S. Court of Appeals for the District of Columbia Circuit. The Company also filed a Petition for Reconsideration with the EPA. In November 2005, the EPA agreed to reconsider certain aspects of its CAIR, including the Minnesota Power petition addressing modeling used to determine Minnesota's inclusion in the CAIR region and claims about inequities in the SO2 allowance methodology. In March 2006, the EPA announced that it would not make any changes to the CAIR as a result of the Petitions for Reconsideration. Petitions for Review, including Minnesota Power's, remain pending at the Court of Appeals. If the Petition for Review is successful, the Company expects to incur lower compliance costs, consistent with the rules applicable to those states considered "western" states under the CAIR. Resolution of the CAIR Petition for Review with the Court of Appeals is anticipated in 2008.
MERCURY EMISSIONS. The Minnesota mercury emissions budget under the first phase of the CAMR, requiring roughly a 20% reduction in nationwide utility mercury emissions beginning in 2010, is similar to current Minnesota statewide emissions requirements. The second phase allocation, requiring approximately a 70% reduction in nationwide utility mercury emissions effective in 2018, will require that Minnesota generation sources provide for substantial mercury emission reductions or procure mercury emission credits from other sources that have a surplus of allowances. However, mercury emission reductions expected as a result of implementing AREA at Taconite Harbor, and implementation of the 2006 Minnesota Mercury Emission Reduction Law which applies to Boswell Units 3 and 4, are anticipated to meet Minnesota Power's 2018 emission reduction requirements of the second phase of CAMR. (See Minnesota Mercury Emission Law.) Minnesota Power is continuing to review the new mercury rule and considers the outcome of legal challenges as being critical before specific compliance measures can be established or assessed.
ALLETE 2006 Form 10-K 20
ENVIRONMENTAL MATTERS (CONTINUED)
MINNESOTA MERCURY EMISSION LAW. This legislation requires Minnesota Power to file mercury emission reduction plans for its Boswell Units 3 and 4. The Boswell Unit 3 emission reduction plan was filed with the MPCA in October 2006. Minnesota Power is required to install mercury emission reduction technology and equipment by December 31, 2010. The next step will be to file a mercury emissions reduction plan for Boswell Unit 4 by July 1, 2011, with implementation no later than December 31, 2014. One plan must attain the mercury reduction goal of 90%. Alternate mercury plans, with the percentage of reduction elected by the utility, are also required to be filed. Minnesota Power may apply mercury emissions achieved under its Arrowhead Regional Emission Abatement plan at Taconite Harbor toward the reduction goal required under approved plans for Boswell Units 3 and 4. Filed plans must be reviewed and approved by the MPCA and the MPUC under criteria that include, among other things, technical feasibility, environmental benefit, cost effectiveness and rate impact. The new law encourages multi-emission reduction plans and also extends a statutory provision for current cost recovery outside of a rate case for approved emission reduction expenditures, including mercury and other types of emissions, from 2006 through 2013. The legislation generally comports with Minnesota Power's plans for its Boswell Units 3 and 4 mercury and other emission reduction retrofits. Total pollution control capital costs planned for Boswell Unit 3 are estimated at approximately $200 million, of which $14 million was spent in 2006 for design engineering and related costs. The balance is expected to be spent from 2007 through 2009. The Boswell Unit 3 emission reduction plan provides significant cost-effective emission reductions through the use of integrated control technologies appropriate for the size, location and use of Boswell Unit 3. Minnesota Power anticipates that costs for these expenditures will be recovered from retail customers on a current basis, subject to approval by the MPUC. (See Regulatory Issues - Minnesota Public Utilities Commission - Boswell Unit 3 Emission Reduction Plan.)
NEW SOURCE REVIEW RULES. In December 2002, the EPA issued changes to the existing New Source Review rules, which modified the procedures for MPCA review of projects at our electric generating facilities. These changes have been incorporated in Minnesota and have not had a material impact on our operations. In October 2003, the EPA announced additional changes clarifying the application of certain sections of the New Source Review rules. In December 2003, the U.S. Court of Appeals for the District of Columbia Circuit (Court) stayed the implementation of the October 2003 rule pending further review. In March 2006, the Court vacated most of the EPA's 2003 rule. These changes are not expected to have a material impact on Minnesota Power.
WATER. The Federal Water Pollution Control Act requires National Pollutant Discharge Elimination System (NPDES) permits to be obtained from the EPA (or, when delegated, from individual state pollution control agencies) for any wastewater discharged into navigable waters. We have obtained all necessary NPDES permits, including NPDES storm water permits for applicable facilities, to conduct our operations.
FERC LICENSES. Minnesota Power holds FERC licenses authorizing the ownership and operation of seven hydroelectric generating projects with a total generating capacity of about 115 MW.
LASKIN NPDES PERMIT MODIFICATION. In June 2006, Minnesota Power filed an application with the MPCA for a variance from a wastewater discharge standard for mercury included in its NPDES permit for Laskin. The variance requested an extension for Laskin to meet mercury discharge requirements which will become effective March 23, 2007, as set forth in Laskin's NPDES permit issued by the MPCA in May 2005. In view of the EPA's proposed changes relating to the implementation of mercury water policy and recent developments in mercury treatment technologies, the MPCA believes it is more appropriate at this time to forego the processing of mercury variances. Instead, a permit modification will be used which will contain a compliance schedule that specifies interim actions and limits that lead to compliance with the final limits by March 31, 2010. This approach will allow Minnesota Power to further investigate treatment alternatives. In October 2006, Minnesota Power submitted a letter withdrawing its variance request. However, we are continuing discussions on interim limits with the MPCA. The MPCA placed a draft permit modification on 30-day public notice on December 20, 2006. The comment period for the draft permit modification closes March 7, 2007.
SOLID AND HAZARDOUS WASTE. The Resource Conservation and Recovery Act of 1976 regulates the management and disposal of solid wastes and hazardous wastes. As a result of this legislation, the EPA has promulgated various hazardous waste rules. We are required to notify the EPA of hazardous waste activity and, consequently, routinely submit the necessary reports to the EPA. State environmental agencies are responsible for administering solid and hazardous waste rules on the local level with oversight by the EPA. We are in material compliance with these rules.
PCB INVENTORIES. In response to the EPA Region V's request for utilities to participate in the Great Lakes Initiative by voluntarily removing remaining polychlorinated biphenyl (PCB) inventories, Minnesota Power replaced its remaining PCB capacitor banks in 2005. PCB-contaminated oil in substation equipment was largely replaced by the end of 2006.
21 ALLETE 2006 Form 10-K
ENVIRONMENTAL MATTERS (CONTINUED)
SWL&P MANUFACTURED GAS PLANT. In May 2001, SWL&P received notice from the WDNR that the city of Superior had found soil contamination on property adjoining a former Manufactured Gas Plant (MGP) site owned and operated by SWL&P from 1889 to 1904. The WDNR requested SWL&P to initiate an environmental investigation. The WDNR also issued SWL&P a Responsible Party letter in February 2002. In February 2003, SWL&P submitted a Phase II environmental site investigation report to the WDNR. This report identified some MGP-like chemicals that were found in the soil near the former plant site. The investigation continued through the fall of 2006. It is anticipated that the final report for this portion of the investigation will be completed during the first quarter of 2007. Although it is not possible to quantify the total potential clean-up costs until the investigation is completed, a $0.5 million liability was recorded in December 2003 based on initial studies to address the known areas of contamination. The Company has recorded a corresponding amount as a regulatory asset. The PSCW has approved SWL&P's deferral of these MGP environmental investigation and potential clean-up costs for future recovery in rates, subject to a regulatory prudency review. In May 2005, the PSCW approved the collection through rates of $150,000 of site investigation costs that had been incurred at the time SWL&P filed its 2006 rate request. In December 2006, the PSCW approved the recovery of an additional $186,000 of site investigation costs that were incurred through 2005. ALLETE maintains pollution liability insurance coverage that includes coverage for SWL&P. A claim has been filed with respect to this matter. The insurance carrier has issued a reservation of rights letter and the Company continues to work with the insurer to determine the availability of insurance coverage.
EMPLOYEES
At December 31, 2006, ALLETE had approximately 1,500 employees, of which 1,400 were full-time.
Minnesota Power and SWL&P have 612 employees who are members of the International Brotherhood of Electrical Workers (IBEW), Local 31. The labor agreement with Local 31 expires on January 31, 2009.
BNI Coal has 94 employees who are members of the IBEW Local 1593. BNI Coal and Local 1593 have a labor agreement, which expires on March 31, 2008.
ALLETE 2006 Form 10-K 22
EXECUTIVE OFFICERS OF THE REGISTRANT
EXECUTIVE OFFICERS INITIAL EFFECTIVE DATE
------------------------------------------------------------------------------------------------------------------------------------
DONALD J. SHIPPAR, Age 57
Chairman, President and Chief Executive Officer January 1, 2006
President and Chief Executive Officer January 21, 2004
Executive Vice President - ALLETE and President - Minnesota Power May 13, 2003
President and Chief Operating Officer - Minnesota Power January 1, 2002
DEBORAH A. AMBERG, Age 41
Senior Vice President, General Counsel and Secretary January 1, 2006
Vice President, General Counsel and Secretary March 8, 2004
STEVEN Q. DEVINCK, Age 47
Controller July 12, 2006
LAURA A. HOLQUIST, Age 45
President - ALLETE Properties September 6, 2001
MARK A. SCHOBER, Age 51
Senior Vice President and Chief Financial Officer July 1, 2006
Senior Vice President and Controller February 1, 2004
Vice President and Controller April 18, 2001
DONALD W. STELLMAKER, Age 49
Treasurer July 24, 2004
TIMOTHY J. THORP, Age 52
Vice President - Investor Relations July 1, 2004
Vice President - Investor Relations and Corporate Communications November 16, 2001
CLAUDIA SCOTT WELTY, Age 54
Senior Vice President and Chief Administrative Officer February 1, 2004
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All of the executive officers have been employed by us for more than five years in executive or management positions. Prior to election to the positions shown above, the following executives held other positions with the Company during the past five years.
MS. AMBERG was a Senior Attorney.
MR. DEVINCK was Director of Nonutility Business Development, and Assistant
Controller.
MR. STELLMAKER was Director of Financial Planning.
MS. WELTY was Vice President Strategy and Technology Development.
There are no family relationships between any of the executive officers. All officers and directors are elected or appointed annually.
The present term of office of the executive officers listed above extends to the first meeting of our Board of Directors after the next annual meeting of shareholders. Both meetings are scheduled for May 8, 2007.
23 ALLETE 2006 Form 10-K
ITEM 1A. RISK FACTORS
Readers are cautioned that forward-looking statements, including those contained in this Form 10-K, should be read in conjunction with our disclosures under the heading: "Safe Harbor Statement Under the Private Securities Litigation Reform Act of 1995" located on page 4 of this Form 10-K and the factors described below. The risks and uncertainties described in this Form 10-K are not the only ones facing our Company. Additional risks and uncertainties that we are not presently aware of, or that we currently consider immaterial, may also affect our business operations. Our business, financial condition or results of operations could suffer if the concerns set forth below are realized.
OUR REGULATED UTILITY RESULTS OF OPERATIONS COULD BE NEGATIVELY IMPACTED IF OUR LARGE POWER CUSTOMERS EXPERIENCE AN ECONOMIC DOWN CYCLE OR FAIL TO COMPETE EFFECTIVELY IN THE GLOBAL ECONOMY.
Our 12 Large Power Customers account for approximately 33% of our 2006 consolidated operating revenue (one of these customers accounted for 12%). These customers are involved in cyclical industries that by their nature are adversely impacted by economic downturns and are subject to strong competition in the global marketplace. An economic downturn or failure to compete effectively in the global economy could have a material adverse effect on their operations and, consequently, could negatively impact our results of operations and the communities that we serve.
OUR REGULATED UTILITY IS SUBJECT TO EXTENSIVE GOVERNMENTAL REGULATIONS THAT MAY HAVE A NEGATIVE IMPACT ON OUR BUSINESS AND RESULTS OF OPERATIONS.
We are subject to prevailing governmental policies and regulatory actions, including those of the United States Congress, state legislatures, the FERC, the MPUC and the PSCW. These governmental regulations relate to allowed rates of return, financings, industry and rate structure, acquisition and disposal of assets and facilities, operation and construction of plant facilities, recovery of purchased power and capital investments, and present or prospective wholesale and retail competition (including but not limited to transmission costs). These governmental regulations significantly influence our operating environment and may affect our ability to recover costs from our customers. We are required to have numerous permits, approvals and certificates from the agencies that regulate our business. We believe the necessary permits, approvals and certificates have been obtained for existing operations and that our business is conducted in accordance with applicable laws; however, we are unable to predict the impact on our operating results from the future regulatory activities of any of these agencies. Changes in regulations or the imposition of additional regulations could have an adverse impact on our results of operations.
OUR REGULATED UTILITY AND NONREGULATED ENERGY OPERATIONS COULD BE SIGNIFICANTLY IMPACTED BY INITIATIVES DESIGNED TO REDUCE THE IMPACT OF GREENHOUSE GAS EMISSIONS SUCH AS CARBON DIOXIDE FROM OUR GENERATING FACILITIES.
Proposals for voluntary initiatives and mandatory controls are being discussed both in the United States and worldwide to reduce greenhouse gases such as carbon dioxide, a by-product of burning fossil fuels. We currently use coal as the primary fuel in 96% of the energy produced by our generating facilities.
We have implemented greenhouse gas emission reduction or offset measures at our Regulated Utility and Nonregulated Energy Operations generating facilities. These efforts currently result in over one million tons of carbon dioxide reductions or offsets annually. We are participating in research and study initiatives to mitigate the potential impact to our business. There is no assurance that our current reduction efforts will mitigate the impact of any new regulations.
We cannot be certain whether new laws or regulations will be adopted to reduce greenhouse gases and what effect any such laws or regulations would have on us. If any new laws or regulations are implemented, they could have a material effect on our results of operations, particularly if those costs are not fully recoverable from customers.
OUR REGULATED UTILITY AND NONREGULATED ENERGY OPERATIONS POSE CERTAIN ENVIRONMENTAL RISKS WHICH COULD ADVERSELY AFFECT OUR RESULTS OF OPERATIONS AND FINANCIAL CONDITION.
We are subject to extensive environmental laws and regulations affecting many aspects of our present and future operations, including air quality, water quality, waste management, reclamation and other environmental considerations. These laws and regulations can result in increased capital, operating and other costs, as a result of compliance, remediation, containment and monitoring obligations, particularly with regard to laws relating to power plant emissions. These laws and regulations generally require us to obtain and comply with a wide variety of environmental licenses, permits, inspections and other approvals. Both public officials and private individuals may seek to enforce applicable environmental laws and regulations. We cannot predict the financial or operational outcome of any related litigation that may arise.
ALLETE 2006 Form 10-K 24
RISK FACTORS (CONTINUED)
There are no assurances that existing environmental regulations will not be revised or that new regulations seeking to protect the environment will not be adopted or become applicable to us. Revised or additional regulations, which result in increased compliance costs or additional operating restrictions, particularly if those costs are not fully recoverable from customers, could have a material effect on our results of operations.
We cannot predict with certainty the amount or timing of all future expenditures related to environmental matters because of the difficulty of estimating such costs. There is also uncertainty in quantifying liabilities under environmental laws that impose joint and several liability on all potentially responsible parties.
THE OPERATION AND MAINTENANCE OF OUR GENERATING FACILITIES IN OUR REGULATED UTILITY AND NONREGULATED ENERGY OPERATIONS INVOLVE RISKS THAT COULD SIGNIFICANTLY INCREASE THE COST OF DOING BUSINESS.
The operation of generating facilities involves many risks, including start-up risks, breakdown or failure of facilities, the dependence on a specific fuel source, or the impact of unusual or adverse weather conditions or other natural events, as well as the risk of performance below expected levels of output or efficiency, the occurrence of any of which could result in lost revenue, increased expenses or both. A significant portion of Minnesota Power's facilities was constructed many years ago. In particular, older generating equipment, even if maintained in accordance with good engineering practices, may require significant capital expenditures to keep operating at peak efficiency. This equipment is also likely to require periodic upgrading and improvements due to changing environmental standards and technological advances. (See Item I - Environmental Matters.) Minnesota Power could be subject to costs associated with any unexpected failure to produce power, including failure caused by breakdown or forced outage, as well as repairing damage to facilities due to storms, natural disasters, wars, terrorist acts and other catastrophic events. Further, our ability to successfully and timely complete capital improvements to existing facilities or other capital projects is contingent upon many variables and subject to substantial risks. Should any such efforts be unsuccessful, we could be subject to additional costs and/or the write-off of our investment in the project or improvement.
OUR REGULATED UTILITY AND NONREGULATED ENERGY OPERATIONS MUST HAVE ADEQUATE AND RELIABLE TRANSMISSION AND DISTRIBUTION FACILITIES TO DELIVER ELECTRICITY TO ITS CUSTOMERS.
Minnesota Power depends on transmission and distribution facilities owned by other utilities, and transmission facilities primarily operated by MISO, as well as its own such facilities, to deliver the electricity it produces and sells to its customers, and to other energy suppliers. If transmission capacity is inadequate, our ability to sell and deliver electricity may be hindered, we may have to forego sales or we may have to buy more expensive wholesale electricity that is available in the capacity-constrained area. The cost to acquire or provide service may exceed the cost to serve other customers, resulting in lower gross margins. In addition, any infrastructure failure that interrupts or impairs delivery of electricity to our customers could negatively impact the satisfaction of our customers with our service.
IN OUR REGULATED UTILITY AND NONREGULATED ENERGY OPERATIONS THE PRICE OF ELECTRICITY AND FUEL MAY BE VOLATILE.
Volatility in market prices for electricity and fuel may result from:
- severe or unexpected weather conditions;
- seasonality;
- changes in electricity usage;
- transmission or transportation constraints, inoperability or
inefficiencies;
- availability of competitively priced alternative energy sources;
- changes in supply and demand for energy;
- changes in power production capacity;
- outages at Minnesota Power's generating facilities or those of our
competitors;
- changes in production and storage levels of natural gas, lignite, coal,
or crude oil and refined products;
- natural disasters, wars, sabotage, terrorist acts or other catastrophic
events; and
- federal, state, local and foreign energy, environmental, or other
regulation and legislation.
Since fluctuations in fuel expense related to our regulated utility operations are passed on to customers through our fuel clause, risk of volatility in market prices for fuel and electricity mainly impacts our nonregulated operations at this time.
25 ALLETE 2006 Form 10-K
RISK FACTORS (CONTINUED)
WE ARE DEPENDENT ON GOOD LABOR RELATIONS.
We believe our relations to be good with our approximately 1,500 employees. Failure to successfully renegotiate labor agreements could adversely affect the services we provide and our results of operations. Approximately 700 of these employees are members of either the International Brotherhood of Electrical Workers Local 31 or Local 1593. The labor agreement with Local 31 at Minnesota Power and SWL&P expires on January 31, 2009, and the labor agreement with Local 1593 at BNI Coal expires on March 31, 2008.
A DOWNTURN IN ECONOMIC CONDITIONS COULD ADVERSELY AFFECT OUR REAL ESTATE BUSINESS.
The ability of our real estate business to generate revenue is directly related to the Florida real estate market, the national and local economy in general, and changes in interest rates. While conditions in the Florida real estate market may fluctuate over time, continued demand for land is dependent on long-term prospects for strong, in-migration population expansion.
WE ARE EXPOSED TO RISKS ASSOCIATED WITH REAL ESTATE DEVELOPMENT.
Our real estate development activities entail risks that include construction delays or cost overruns, which may increase project development costs. In addition, the effects of the rebuilding efforts due to destructive weather, including hurricanes, could cause increased prices for construction materials and create labor shortages which could increase our development costs.
Our real estate development activities require significant capital expenditures. We obtain funds for our capital expenditures through cash flow from operations and financings, including the financings of the community development districts in which our development projects are located. We cannot be certain that the funds available from these sources will be sufficient to fund our required or desired capital expenditures for development. If we are unable to obtain sufficient funds, we may have to defer or otherwise limit our development activities.
OUR REAL ESTATE BUSINESS IS SUBJECT TO EXTENSIVE REGULATION THROUGH FLORIDA LAWS REGULATING PLANNING AND LAND DEVELOPMENT WHICH MAKES IT DIFFICULT AND EXPENSIVE FOR US TO CONDUCT OUR OPERATIONS.
Development of real property in Florida entails an extensive approval process involving overlapping regulatory jurisdictions. Real estate projects must generally comply with the provisions of the Local Government Comprehensive Planning and Land Development Regulation Act (Growth Management Act). In addition, development projects that exceed certain specified regulatory thresholds require approval of a comprehensive DRI application.
The Growth Management Act requires counties and cities to adopt comprehensive plans guiding and controlling future real property development in their respective jurisdictions. After a local government adopts its comprehensive plan, all development orders and development permits must be consistent with the plan. Each plan must address such topics as future land use, capital improvements, traffic circulation, sanitation, sewage, potable water, drainage and solid waste disposal. The local governments' comprehensive plans must also establish "levels of service" with respect to certain specified public facilities and services to residents. Local governments are prohibited from issuing development orders or permits if facilities and services are not operating at established levels of service, or if the projects for which permits are requested will reduce the level of service for public facilities below the level of service established in the local government's comprehensive plan. If the proposed development would reduce the established level of services below the level set by the plan, the development order will require that, at the outset of the project, the developer either sufficiently improve the services to meet the required level or provide financial assurances that the additional services will be provided as the project progresses.
The Growth Management Act, in some instances, can significantly affect the ability of developers to obtain local government approval in Florida. In many areas, infrastructure funding has not kept pace with growth. As a result, substandard facilities and services can delay or prevent the issuance of permits. Consequently, the Growth Management Act could adversely affect our ability to develop future real estate projects.
The DRI review process includes an evaluation of a project's impact on the environment, infrastructure and government services, and requires the involvement of numerous state and local environmental, zoning and community development agencies. Local government approval of any DRI is subject to appeal to Florida's Governor and Cabinet by the Florida Department of Community Affairs, and adverse decisions by the Governor and Cabinet are subject to judicial appeal. The DRI approval process is usually lengthy and costly, and conditions, standards or requirements may be imposed on a developer with respect to a particular project, which may materially increase the cost of the project.
Changes in the Growth Management Act or DRI review process or the enactment of new laws regarding the development of real property could adversely affect our ability to develop future real estate projects.
ALLETE 2006 Form 10-K 26
RISK FACTORS (CONTINUED)
COMPETITION FOR LAND COULD ADVERSELY AFFECT OUR REAL ESTATE BUSINESS.
Over the past few years, we have experienced an increase in competition for suitable land in the southeast United States real estate market. The availability of undeveloped land for purchase that meets our internal criteria depends on a number of factors outside our control, including land availability in general, competition with other developers and land buyers for desirable property, inflation in land prices, zoning, allowable development density and other regulatory requirements. Our long-term ability to acquire land suitable for development at reasonable prices in locations where we feel there is a viable market is crucial in maintaining our business success.
IF WE ARE NOT ABLE TO RETAIN OUR EXECUTIVE OFFICERS AND KEY EMPLOYEES, WE MAY NOT BE ABLE TO IMPLEMENT OUR BUSINESS STRATEGY AND OUR BUSINESS COULD SUFFER.
The success of our business heavily depends on the leadership of our executive officers, all of whom are employees-at-will and none of whom are subject to any agreements not to compete. If we lose the service of one or more of our executive officers or key employees, or if one or more of them decides to join a competitor or otherwise compete directly or indirectly with us, we may not be able to successfully manage our business or achieve our business objectives. We may have difficulty in retaining and attracting customers, developing new services, negotiating favorable agreements with customers and providing acceptable levels of customer service.
ITEM 1B. UNRESOLVED STAFF COMMENTS
None.
ITEM 2. PROPERTIES
Properties are included in the discussion of our 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 our business in Item 1 and are incorporated by reference herein.
We are involved in litigation arising in the normal course of business. Also in the normal course of business, we are involved in tax, regulatory and other governmental audits, inspections, investigations and other proceedings that involve state and federal taxes, safety, compliance with regulations, rate base and cost of service issues, among other things. We do not expect the outcome of these matters to have a material effect on our financial position or results of operations.
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 2006.
27 ALLETE 2006 Form 10-K
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
We have paid dividends without interruption on our common stock since 1948. A quarterly dividend of $0.41 per share on our common stock will be paid on March 1, 2007, to the holders of record on February 15, 2007. Our common stock is listed on the New York Stock Exchange under the symbol ALE and our CUSIP number is 018522300. Dividends paid per share, and the high and low prices for our common stock for the periods indicated as reported by the New York Stock Exchange on its NYSEnet website, are in the accompanying chart.
The amount and timing of dividends payable on our common stock are within the sole discretion of our Board of Directors. In 2006, we paid out 53% of our per share earnings in dividends.
Our 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, 2006, no retained earnings were restricted as a result of these provisions. At February 1, 2007, there were approximately 31,000 common stock shareholders of record.
2006 2005
-----------------------------------------------------------------------------------------
PRICE RANGE DIVIDENDS PRICE RANGE DIVIDENDS
QUARTER HIGH LOW PAID HIGH LOW PAID
-------------------------------------------------------------------------------------------------------------------------
First $47.81 $42.99 $0.3625 $44.40 $35.65 $0.3000
Second 48.55 44.34 0.3625 50.33 40.12 0.3150
Third 49.30 43.26 0.3625 51.70 42.80 0.3150
Fourth 47.84 42.55 0.3625 47.36 41.28 0.3150
-------------------------------------------------------------------------------------------------------------------------
Annual Total $1.4500 $1.2450
-------------------------------------------------------------------------------------------------------------------------
|
COMMON STOCK REPURCHASES. We did not repurchase any ALLETE common stock during the fourth quarter of 2006.
ALLETE 2006 Form 10-K 28
ITEM 6. SELECTED FINANCIAL DATA
Financial results by segment for the periods presented were impacted by the integration of our Taconite Harbor facility into the Regulated Utility segment effective January 1, 2006. The redirection of Taconite Harbor from our Nonregulated Energy Operations segment to our Regulated Utility segment was in accordance with the Company's Resource Plan, as approved by the MPUC. Under the terms of our Resource Plan, we have operated the Taconite Harbor facility as a rate-based asset within the Minnesota retail jurisdiction since January 1, 2006. Prior to January 1, 2006, we operated our Taconite Harbor facility as nonregulated generation (non-rate base generation sold at market-based rates primarily to the wholesale market). Historical financial results of Taconite Harbor for periods prior to the 2006 redirection are included in our Nonregulated Energy Operations segment.
Operating results of our Water Services businesses, our Automotive Services business and our telecommunications business are included in discontinued operations, and accordingly, amounts have been restated for all periods presented. (See Note 13.) Common share and per share amounts have also been adjusted for all periods to reflect our September 20, 2004, one-for-three common stock reverse split.
2006 2005 2004 2003 2002
----------------------------------------------------------------------------------------------------------------------------
MILLIONS
BALANCE SHEET
Assets
Current Assets $ 287.7 $ 373.5 $ 355.0 $ 216.1 $ 184.8
Discontinued Operations - Current - 0.4 13.1 483.9 477.3
Property, Plant and Equipment 921.6 860.4 849.6 888.2 852.0
Investments 189.1 117.7 124.5 175.7 170.9
Other Assets 135.0 <F1> 44.6 52.8 59.0 61.9
Discontinued Operations - Other - 2.2 36.4 1,278.4 1,400.3
----------------------------------------------------------------------------------------------------------------------------
$1,533.4 $1,398.8 $1,431.4 $3,101.3 $3,147.2
----------------------------------------------------------------------------------------------------------------------------
Liabilities and Shareholders' Equity
Current Liabilities $ 143.5 $ 106.7 $ 91.7 $ 182.1 $ 436.2
Discontinued Operations - Current - 13.0 24.5 344.1 302.0
Long-Term Debt 359.8 387.8 389.4 513.9 566.9
Mandatorily Redeemable Preferred Securities - - - - 75.0
Other Liabilities 364.3 <F1> 288.5 295.3 300.1 292.2
Discontinued Operations - - - 300.9 242.5
Shareholders' Equity 665.8 602.8 630.5 1,460.2 1,232.4
----------------------------------------------------------------------------------------------------------------------------
$1,533.4 $1,398.8 $1,431.4 $3,101.3 $3,147.2
----------------------------------------------------------------------------------------------------------------------------
INCOME STATEMENT
Operating Revenue
Regulated Utility $639.2 $575.6 $555.0 $510.0 $497.9
Nonregulated Energy Operations 65.0 113.9 106.8 106.6 84.7
Real Estate 62.6 47.5 41.9 42.6 33.6
Other 0.3 0.4 0.4 0.4 0.3
----------------------------------------------------------------------------------------------------------------------------
Total Operating Revenue 767.1 737.4 704.1 659.6 616.5
----------------------------------------------------------------------------------------------------------------------------
Operating Expenses
Fuel and Purchased Power 281.7 273.1 286.2 252.5 234.8
Operating and Maintenance 296.0 293.5 270.1 260.5 254.4
Kendall County Charge - 77.9 - - -
Depreciation 48.7 47.8 46.9 48.9 47.0
----------------------------------------------------------------------------------------------------------------------------
Total Operating Expenses 626.4 692.3 603.2 561.9 536.2
----------------------------------------------------------------------------------------------------------------------------
Operating Income from Continuing Operations 140.7 45.1 100.9 97.7 80.3
----------------------------------------------------------------------------------------------------------------------------
Other Income (Expense)
Interest Expense (27.4) (26.4) (31.7) (50.5) (49.3)
Other 14.9 1.1 (12.2) 2.3 6.9
----------------------------------------------------------------------------------------------------------------------------
Total Other Expense (12.5) (25.3) (43.9) (48.2) (42.4)
----------------------------------------------------------------------------------------------------------------------------
Income from Continuing Operations
Before Minority Interest and Income Taxes 128.2 19.8 57.0 49.5 37.9
Minority Interest 4.6 2.7 2.1 2.6 1.0
----------------------------------------------------------------------------------------------------------------------------
Income from Continuing Operations Before Income Taxes 123.6 17.1 54.9 46.9 36.9
Income Tax Expense (Benefit) 46.3 (0.5) 16.4 17.7 12.3
----------------------------------------------------------------------------------------------------------------------------
Income from Continuing Operations Before
Change in Accounting Principle 77.3 17.6 38.5 29.2 24.6
Income (Loss) from Discontinued Operations - Net of Tax (0.9) (4.3) 73.7 207.2 112.6
Change in Accounting Principle - Net of Tax - - (7.8) <F2> - -
----------------------------------------------------------------------------------------------------------------------------
Net Income 76.4 13.3 104.4 236.4 137.2
Common Stock Dividends 40.7 34.4 79.7 93.2 89.2
----------------------------------------------------------------------------------------------------------------------------
Earnings Retained in (Distributed from) Business $ 35.7 $(21.1) $ 24.7 $143.2 $ 48.0
----------------------------------------------------------------------------------------------------------------------------
<F1> Included $86.1 million of assets and $107.6 million of liabilities reflecting the adoption of SFAS 158 "Employers'
Accounting for Defined Benefit Pension and Other Postretirement Plans." (See Notes 2 and 16.)
<F2> Reflected the cumulative effect on prior years (to December 2003) of changing to the equity method of accounting
for investments in limited liability companies included in our emerging technology portfolio. (See Note 15.)
|
29 ALLETE 2006 Form 10-K
2006 2005 2004 2003 2002
-------------------------------------------------------------------------------------------------------------------------------
Shares Outstanding - Millions
Year-End 30.4 30.1 29.7 29.1 28.5
Average (a)
Basic 27.8 27.3 28.3 27.6 27.0
Diluted 27.9 27.4 28.4 27.8 27.2
Diluted Earnings (Loss) Per Share
Continuing Operations $2.77 $0.64 <F3><F4> $1.35 <F5> $1.05 $0.91 <F8>
Discontinued Operations (0.03) (0.16) 2.59 7.47 <F7> 4.13
Change in Accounting Principle - - (0.27) - -
-------------------------------------------------------------------------------------------------------------------------------
$2.74 $0.48 $3.67 $8.52 $5.04
-------------------------------------------------------------------------------------------------------------------------------
Return on Common Equity 12.1% 2.2% <F3><F4> 8.3% 17.7% 11.4%
Common Equity Ratio 63.1% 60.7% 61.7% 64.4% 51.7%
Dividends Paid Per Share $1.4500 $1.2450 $2.8425 $3.3900 $3.3000
Dividend Payout Ratio 53% 259% <F3><F4> 77% 40% 66%
Book Value Per Share at Year-End $21.90 $20.03 $21.23 $50.18 $43.24
Employees at Year-End 1,468 1,459 1,515 13,115 14,181
Income (Loss)
Regulated Utility $46.8 <F2> $ 45.7 $ 37.7 $ 32.4 $ 46.0
Nonregulated Energy Operations 3.7 <F2> (48.5) <F3> (2.9) 1.1 (11.3) <F8>
Investment in ATC 1.9 - - - -
Real Estate 22.8 17.5 14.3 13.6 10.8
Other 2.1 2.9 <F4> (10.6) <F5> (17.9) (20.9)
-------------------------------------------------------------------------------------------------------------------------------
Continuing Operations 77.3 17.6 38.5 29.2 24.6
Discontinued Operations (0.9) (4.3) 73.7 207.2 <F7> 112.6
Change in Accounting Principle - - (7.8) <F6> - -
-------------------------------------------------------------------------------------------------------------------------------
Net Income $76.4 $ 13.3 $104.4 $236.4 $137.2
-------------------------------------------------------------------------------------------------------------------------------
Average Electric Customers - Thousands 153.7 151.8 150.1 148.2 146.8
Electric Sales - Millions of MWh
Regulated Utility 12.8 <F2> 11.7 11.2 11.1 11.1
Nonregulated Energy Operations 0.2 <F2> 1.5 1.5 1.5 1.2
Company Use and Losses 0.3 0.5 0.9 0.7 0.7
-------------------------------------------------------------------------------------------------------------------------------
13.3 13.7 13.6 13.3 13.0
-------------------------------------------------------------------------------------------------------------------------------
Power Supply - Millions of MWh
Regulated Utility
Steam Generation 8.6 <F2> 7.2 6.5 7.1 7.2
Hydro Generation 0.3 0.5 0.5 0.4 0.5
Long-Term Purchases - Square Butte 2.1 2.3 2.0 2.3 2.3
Purchased Power 2.1 2.1 3.0 1.9 1.8
-------------------------------------------------------------------------------------------------------------------------------
13.1 12.1 12.0 11.7 11.8
-------------------------------------------------------------------------------------------------------------------------------
Nonregulated Energy Operations
Steam 0.2 <F2> 1.4 1.3 1.3 0.9
Purchased Power - 0.2 0.3 0.3 0.3
-------------------------------------------------------------------------------------------------------------------------------
0.2 1.6 1.6 1.6 1.2
-------------------------------------------------------------------------------------------------------------------------------
13.3 13.7 13.6 13.3 13.0
-------------------------------------------------------------------------------------------------------------------------------
Coal Sold - Millions of Tons 4.2 4.5 4.2 4.3 4.6
Real Estate Sales
Town Center - Commercial Square Feet 401,971 643,000 - - -
Residential Units 773 - - - -
Palm Coast - Residential Units 200 - - - -
Other Land - Acres 732 1,102 1,479 1,394 641
Lots - 7 211 265 1,425
-------------------------------------------------------------------------------------------------------------------------------
Capital Additions - Millions
Continuing Operations $109.4 $58.6 $57.8 $ 68.7 $ 81.7
Discontinued Operations - 4.5 21.4 67.6 119.5
-------------------------------------------------------------------------------------------------------------------------------
$109.4 $63.1 $79.2 $136.3 $ 201.2
-------------------------------------------------------------------------------------------------------------------------------
<F1> Excludes unallocated ESOP shares.
<F2> Effective January 1, 2006, our Taconite Harbor generating facility was redirected from Nonregulated Energy Operations
to Regulated Utility.
<F3> Impacted by a $50.4 million, or $1.84 per share, charge related to the assignment of the Kendall County power
purchase agreement. (See Note 10.)
<F4> Impacted by a $2.5 million, or $0.09 per share, deferred tax benefit due to comprehensive state tax planning initiatives
and a $3.7 million, or $0.13 per share, current tax benefit due to a positive resolution of income tax audit issues.
<F5> Included a $10.9 million, or $0.38 per share, after-tax debt prepayment cost incurred as part of ALLETE's
financial restructuring in preparation for the spin-off of Automotive Services (see Note 11) and an $11.5 million, or
$0.41 per share, gain on the sale of ADESA shares related to the Company's ESOP (see Note 17).
<F6> Reflected the cumulative effect on prior years (to December 2003) of changing to the equity method of accounting
for investments in limited liability companies included in our emerging technology portfolio. (See Note 15.)
<F7> Included a $71.6 million, or $2.59 per share, gain on the sale of the Water Services businesses.
<F8> Included a $5.5 million, or $0.20 per share, charge related to the indefinite delay of a generation project in
Superior, Wisconsin.
|
ALLETE 2006 Form 10-K 30
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion should be read in conjunction with our consolidated financial statements and notes to those statements and the other financial information appearing elsewhere in this report. In addition to historical information, the following discussion and other parts of this report contain forward-looking information that involves risks and uncertainties. Readers are cautioned that forward-looking statements should be read in conjunction with our disclosures in this Form 10-K under the headings: "Safe Harbor Statement Under the Private Securities Litigation Reform Act of 1995" located on page 4 and "Risk Factors" located in Item 1A. The risks and uncertainties described in this Form 10-K are not the only ones facing our Company. Additional risks and uncertainties that we are not presently aware of, or that we currently consider immaterial, may also affect our business operations. Our business, financial condition or results of operations could suffer if the concerns set forth in this Form 10-K are realized.
EXECUTIVE SUMMARY
ALLETE is a diversified company providing fundamental products and services since 1906. This includes our two core businesses--ENERGY and REAL ESTATE, as well as our former operations in the water, paper, telecommunications and automotive industries.
ENERGY is comprised of Regulated Utility, Nonregulated Energy Operations and Investment in ATC.
- REGULATED UTILITY includes retail and wholesale rate regulated electric, natural gas and water services in northeastern Minnesota and northwestern Wisconsin under the jurisdiction of state and federal regulatory authorities.
- NONREGULATED ENERGY OPERATIONS includes our coal mining activities in North Dakota, approximately 50 MW of nonregulated generation and Minnesota land sales.
In 2004 and 2005, Nonregulated Energy Operations also included nonregulated generation (non-rate base generation sold at market-based rates primarily to the wholesale market) from our Taconite Harbor facility in northern Minnesota, and generation secured through the Kendall County power purchase agreement.
- INVESTMENT IN ATC includes our equity ownership interest in ATC.
REAL ESTATE includes our Florida real estate operations.
OTHER includes our investments in emerging technologies, and earnings on cash and short-term investments.
We are committed to earning a financial return that rewards our shareholders, allows for reinvestment in our businesses, and sustains our growth. We strive to grow earnings and dividends that will result in a total shareholder return that is superior to that of similar companies. Our goal is to earn a financial return that will allow us to provide dividend increases while at the same time fund our growth initiatives.
Our management believes that we can best grow earnings through the combined financial performance of a limited number of significant business units. In addition to providing earnings growth opportunities, this mix of diverse businesses helps mitigate the potential financial risk inherent in the economic cycles of each individual business.
We believe that, in order to enhance our ability to achieve our long-term annual earnings growth goals, we must pursue a strategy of further expansion of our energy and/or real estate businesses, and/or a new industry segment outside of these two businesses. We will be disciplined and patient in our approach, with the direct involvement of our senior executives and Board of Directors.
We have provided fundamental products and services for 100 years, and we expect that our diversification efforts beyond our existing Energy and Real Estate businesses will generally be similarly focused. We currently anticipate that the size of an investment in a new industry segment could be in the range of $100 million to $500 million.
We achieved several milestones during 2006 that lay the groundwork for future success. These achievements include:
- Commencing ALLETE's investment in ATC;
- Starting construction on an aggressive air emissions control plan with
current cost recovery;
- Purchasing electricity from a new 50-MW wind facility in North Dakota
and signing an agreement to purchase power from a second 48-MW wind
facility;
- Maintaining a high level of electric sales to industrial customers;
- Signing a long-term contract for approximately 70 MW with a new large
industrial customer, PolyMet Mining;
- Receiving development order approval for our Ormond Crossings real
estate project; and
- Closing the first sales contracts at our Palm Coast Park development.
31 ALLETE 2006 Form 10-K
EXECUTIVE SUMMARY (CONTINUED)
2006 <F1> 2005 2004
----------------------------------------------------------------------------------------------------------------------------
MILLIONS EXCEPT PER SHARE AMOUNTS
Operating Revenue
Regulated Utility $639.2 $575.6 $555.0
Nonregulated Energy Operations 65.0 113.9 106.8
Real Estate 62.6 47.5 41.9
Other 0.3 0.4 0.4
----------------------------------------------------------------------------------------------------------------------------
$767.1 $737.4 $704.1
----------------------------------------------------------------------------------------------------------------------------
Operating Expenses
Regulated Utility $543.8 $486.0 $476.3
Nonregulated Energy Operations 61.4 186.6 <F2> 108.6
Real Estate 18.3 15.6 15.1
Other 2.9 4.1 3.2
----------------------------------------------------------------------------------------------------------------------------
$626.4 $692.3 $603.2
----------------------------------------------------------------------------------------------------------------------------
Interest Expense
Regulated Utility $20.2 $17.4 $18.5
Nonregulated Energy Operations 3.3 6.6 4.9
Real Estate - 0.1 0.3
Other 3.9 2.3 8.0
----------------------------------------------------------------------------------------------------------------------------
$27.4 $26.4 $31.7
----------------------------------------------------------------------------------------------------------------------------
Other Income (Expense)
Regulated Utility $ 0.9 $0.7 $ 0.1
Nonregulated Energy Operations 2.2 1.7 0.6
Investment in ATC 3.0 - -
Other 8.8 (1.3) (12.9) <F4>
----------------------------------------------------------------------------------------------------------------------------
$14.9 $1.1 $(12.2)
----------------------------------------------------------------------------------------------------------------------------
Income (Loss)
Regulated Utility $46.8 $45.7 $ 37.7
Nonregulated Energy Operations 3.7 (48.5) <F2> (2.9)
Investment in ATC 1.9 - -
Real Estate 22.8 17.5 14.3
Other 2.1 2.9 <F3> (10.6) <F4>
----------------------------------------------------------------------------------------------------------------------------
Continuing Operations 77.3 17.6 38.5
Discontinued Operations (0.9) (4.3) 73.7
Change in Accounting Principle - - (7.8)
----------------------------------------------------------------------------------------------------------------------------
Net Income $76.4 $13.3 $104.4
----------------------------------------------------------------------------------------------------------------------------
Diluted Average Shares of Common Stock 27.9 27.4 28.4
----------------------------------------------------------------------------------------------------------------------------
Diluted Earnings (Loss) Per Share of Common Stock
Continuing Operations $2.77 $0.64 <F2><F3> $1.35 <F4>
Discontinued Operations (0.03) (0.16) 2.59
Change in Accounting Principle - - (0.27)
----------------------------------------------------------------------------------------------------------------------------
$2.74 $0.48 $3.67
----------------------------------------------------------------------------------------------------------------------------
Return on Common Equity 12.1% 2.2% <F2><F3> 8.3%
----------------------------------------------------------------------------------------------------------------------------
<F1> Effective January 1, 2006, our Taconite Harbor generating facility was redirected from Nonregulated Energy Operations
to Regulated Utility.
<F2> Impacted by a $77.9 million ($50.4 million after tax, or $1.84 per share) charge related to the assignment of the
Kendall County power purchase agreement in April 2005. (See Note 10.)
<F3> Impacted by a $2.5 million, or $0.09 per share, deferred tax benefit due to comprehensive state tax planning
initiatives and a $3.7 million, or $0.13 per share, current tax benefit due to a positive resolution of income tax
audit issues.
<F4> Included an $18.5 million ($10.9 million after tax, or $0.38 per share) debt prepayment cost incurred as part of
ALLETE's financial restructuring in preparation for the spin-off of Automotive Services and an $11.5 million, or
$0.41 per share, gain on the sale of ADESA shares related to our ESOP.
|
ALLETE 2006 Form 10-K 32
EXECUTIVE SUMMARY (CONTINUED)
Net income for 2006 was $76.4 million, or $2.74 per diluted share ($13.3 million, or $0.48 per diluted share for 2005; $104.4 million, or $3.67 per diluted share for 2004). Net income for 2006 was up $63.1 million from 2005 reflecting:
- the absence of the Kendall County Charge ($50.4 million recorded in
2005);
- the absence of Kendall County operating losses ($1.9 million recorded in
2005);
- the absence of emerging technology impairments ($3.3 million recorded in
2005);
- the absence of the loss on the sale of our telecommunication business
($3.6 million recorded in 2005);
- increased income from Real Estate ($5.3 million);
- increased earnings on cash and short-term investments ($2.6 million);
- income from our investment in ATC ($1.9 million in 2006); and
- increased income from Regulated Utility ($1.1 million).
These factors were partially offset by the absence of tax benefits recorded in 2005--a $3.7 million current tax benefit due to the positive resolution of income tax audit issues and a $2.5 million deferred tax benefit due to comprehensive state tax planning initiatives.
Financial results for continuing operations for the periods discussed in this Form 10-K were significantly impacted by the following five transactions not representative of ongoing operations:
- KENDALL COUNTY CHARGE. In 2005, we incurred a $77.9 million ($50.4
million after tax, or $1.84 per share) charge due to the assignment of
the Kendall County power purchase agreement to Constellation Energy
Commodities (Kendall County Charge). (See Note 10.)
- POSITIVE RESOLUTION OF TAX AUDIT ISSUES. In 2005, we recognized a $3.7
million, or $0.13 per share, current tax benefit due to a positive
resolution of income tax audit issues.
- STATE TAX PLANNING INITIATIVES. In 2005, we implemented comprehensive
state tax planning initiatives, which resulted in current and ongoing
tax savings, and a deferred tax benefit of $2.5 million, or $0.09 per
share.
- DEBT PREPAYMENT COST. In 2004, we incurred an $18.5 million ($10.9
million after tax, or $0.38 per share) debt prepayment cost as part of
ALLETE's financial restructuring in preparation for the spin-off of
Automotive Services.
- GAIN ON SALE OF ADESA SHARES. In 2004, we recognized a nontaxable $11.5
million, or $0.41 per share, gain on the sale of
ADESA shares related to our ESOP. (See Note 17.)
Income from continuing operations was $77.3 million, or $2.77 per diluted share,
for 2006, an increase of $59.7 million, or $2.13 per diluted share, from 2005.
Excluding the three 2005 transactions not representative of ongoing operations
mentioned above, 2006 diluted earnings per share from continuing operations was
up 23% from 2005, exceeding our expected earnings growth for 2006 of 15% to 20%.
(See Non-GAAP Financial Measures.)
Financial results by segment for the periods presented and discussed in this Form 10-K were impacted by the integration of our Taconite Harbor facility into the Regulated Utility segment effective January 1, 2006. The redirection of Taconite Harbor from our Nonregulated Energy Operations segment to our Regulated Utility segment was in accordance with the Company's Resource Plan, as approved by the MPUC, to help meet forecasted base load energy requirements. Under the terms of our Resource Plan, we have operated the Taconite Harbor facility as a rate-based asset within the Minnesota retail jurisdiction since January 1, 2006. Prior to January 1, 2006, we operated our Taconite Harbor facility as nonregulated generation. Historical financial results of Taconite Harbor for periods prior to the 2006 redirection are included in our Nonregulated Energy Operations segment.
KILOWATTHOURS SOLD 2006 2005 2004
---------------------------------------------------------------------------------------------------------------------------
MILLIONS
Regulated Utility
Retail and Municipals
Residential 1,100 1,102 1,053
Commercial 1,335 1,327 1,282
Industrial 7,206 7,130 7,071
Municipals 911 877 823
Other 79 79 79
---------------------------------------------------------------------------------------------------------------------------
Total Retail and Municipals 10,631 10,515 10,308
Other Power Suppliers 2,153 1,142 918
---------------------------------------------------------------------------------------------------------------------------
Total Regulated Utility 12,784 11,657 11,226
Nonregulated Energy Operations 240 1,521 1,496
---------------------------------------------------------------------------------------------------------------------------
Total Kilowatthours Sold 13,024 13,178 12,722
---------------------------------------------------------------------------------------------------------------------------
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33 ALLETE 2006 Form 10-K
EXECUTIVE SUMMARY (CONTINUED)
REAL ESTATE 2006 2005 2004
REVENUE AND SALES ACTIVITY QUANTITY AMOUNT QUANTITY AMOUNT QUANTITY AMOUNT
---------------------------------------------------------------------------------------------------------------------------
DOLLARS IN MILLIONS
Revenue from Land Sales
Town Center Sales
Commercial Sq. Ft. 401,971 $10.8 643,000 $15.2 - -
Residential Units 773 12.9 - - - -
Palm Coast Park
Residential Unit 200 3.0 - - - -
Other Land Sales
Acres 732 24.4 1,102 38.1 1,479 $32.8
Lots - - 7 0.4 211 4.5
---------------------------------------------------------------------------------------------------------------------------
Contract Sales Price<F1> 51.1 53.7 37.3
Revenue Recognized from
Previously Deferred Sales 9.7 - -
Deferred Revenue (3.8) (10.0) (1.5)
Adjustments <F2> (0.9) (1.7) -
---------------------------------------------------------------------------------------------------------------------------
Revenue from Land Sales 56.1 42.0 35.8
Other Revenue 6.5 5.5 6.1
---------------------------------------------------------------------------------------------------------------------------
$62.6 $47.5 $41.9
---------------------------------------------------------------------------------------------------------------------------
<F1> Reflected total contract sales price on closed land transactions. Land sales are recorded using a percentage-
of-completion method. (See Critical Accounting Estimates and Note 2.)
<F2> Contributed development dollars, which are credited to cost of real estate sold.
|
NET INCOME
REGULATED UTILITY contributed income of $46.8 million in 2006 ($45.7 million in 2005; $37.7 million in 2004). Earnings were slightly higher in 2006 than 2005 as demand from our industrial customers continued to be strong. Kilowatthour sales to industrial customers increased 76 million, or 1%, in 2006. Overall, Regulated Utility kilowatthour sales increased 1,127 million, or 10%, reflecting the inclusion of Taconite Harbor and its pre-existing wholesale energy sales obligations in Regulated Utility since January 1, 2006.
In 2005, income was higher than 2004 due to a 4% increase in overall regulated utility kilowatthour electric sales. Healthier economic conditions in Minnesota Power's service territory combined with warmer weather in the summer of 2005 contributed to the increase in kilowatthour sales. Higher pension expense ($1.0 million) and an increase in maintenance expense ($2.0 million) were partially offset by the absence of Split Rock Energy expenses ($1.2 million) and lower interest expense ($0.6 million).
NONREGULATED ENERGY OPERATIONS reported income of $3.7 million in 2006 (a loss of $48.5 million in 2005; a loss of $2.9 million in 2004). In April 2005, we completed the assignment of our Kendall County power purchase agreement to Constellation Energy Commodities. As a result of this transaction, we incurred a charge to operating expenses totaling $50.4 million after tax in the second quarter of 2005. In 2006, financial results reflected the absence of income from Taconite Harbor, which is now reported as part of Regulated Utility, and operating losses from Kendall County ($1.9 million in 2005; $8.5 million in 2004). In 2004, the Kendall County operating loss included a $0.7 million cost to terminate a transmission contract.
Income from our coal operations was up $0.2 million from 2005 primarily due to a 16% increase in the delivery price per ton reflecting higher reimbursable coal production expenses. Tons of coal sold were down 7% from 2005 in part due to an outage at Minnkota Power's Unit 1 in 2006. In 2005, income from our coal operations was up $1.3 million from 2004, primarily due to a 7% increase in tons of coal sold.
INVESTMENT IN ATC contributed income of $1.9 million in 2006. We began investing in ATC in May 2006. As of December 31, 2006, our equity investment balance in ATC was $53.7 million, representing approximately a 7% ownership interest. (See Notes 6 and 8.)
ALLETE 2006 Form 10-K 34
NET INCOME (CONTINUED)
REAL ESTATE contributed income of $22.8 million in 2006 ($17.5 million in 2005; $14.3 million in 2004), reflecting continued strong demand for real estate in Florida. Income was higher in 2006 primarily due to the recognition of deferred earnings from prior land sales. The timing of the closing of real estate sales varies from period to period and impacts comparisons between years. As of December 31, 2006, we had $4.1 million of deferred profit on sales of real estate, before taxes and minority interest, on our balance sheet. Most of this deferred profit relates to Town Center which will be recognized over the next several years as development obligations are completed. Since land is being sold before completion of the project infrastructure, revenue and cost of real estate sold are recorded using a percentage-of-completion method as development obligations are completed. (See Note 2.)
REAL ESTATE
PENDING CONTRACTS CONTRACT
AT DECEMBER 31, 2006 QUANTITY <F1> SALES PRICE
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DOLLARS IN MILLIONS
Town Center
Commercial Sq. Ft. 786,400 $ 24.2
Residential Units 1,010 15.9
Palm Coast Park
Commercial Sq. Ft. 50,000 2.5
Residential Units 2,409 60.3
Other Land <F2>
Acres 196 10.9
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Total Pending Land Sales Under Contract $113.8
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<F1> Acreage amounts are approximate and shown on a gross basis, including wetlands and minority interest. Acreage amounts may
vary due to platting or surveying activity. Wetland amounts vary by property and are often not formally determined prior
to sale. Commercial square feet and residential units are estimated and include minority interest. The actual property
allocation at full build-out may be different than these estimates.
<F2> Includes land located in Ormond Beach and Palm Coast in northeast Florida and other land located in Cape Coral in
southwest Florida, all of which are not included in development projects.
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At December 31, 2006, total pending land sales under contract were $113.8 million and are anticipated to close at various times through 2012. Prices on these contracts range from $20 to $50 per commercial square foot, $8,000 to $34,000 per residential unit and $11,000 to $1,774,200 per acre for all other properties. Prices per acre are stated on a gross acreage basis and are dependent on the type and location of the properties sold. The majority of the other properties under contract are zoned commercial or mixed use. In addition to minimum base price contracts, certain contracts allow us to receive participation revenue from land sales to third parties if various formula-based criteria are achieved.
If a purchaser defaults under terms of a contract, our remedies generally include retention of the purchaser's deposit and the ability to remarket the property to other prospective buyers. In many cases, the purchaser has also incurred significant costs in planning, designing and marketing of the property under contract before the contract closes.
OTHER reflected income of $2.1 million in 2006 ($2.9 million of income in 2005; a $10.6 million loss in 2004). In 2006, income from Other was down $0.8 million from 2005 primarily due to the absence of tax benefits recorded in 2005--a $3.7 million current tax benefit due to the positive resolution of income tax audit issues and a $2.5 million deferred tax benefit due to comprehensive state tax planning initiatives. In addition, a $0.9 million increase in interest expense was more than offset by a $2.6 increase in earnings on cash and short-term investments, the absence of impairments of $3.3 million related to certain investments in our emerging technology portfolio and the absence of a $0.6 million charge recognized in 2005 for the probable payment under our guarantee of Northwest Airlines debt.
In 2005, income from Other was up $13.5 million from 2004. Financial results for 2005 reflected the $3.7 million current tax benefit and the $2.5 million deferred tax benefit previously mentioned, a $3.4 million decline in interest expense as a result of lower debt balances, and a $1.9 million increase in earnings on cash and short-term investments. Cash was higher in 2005 than 2004 due to proceeds received from the sale of Enventis Telecom in 2005 as well as earnings on proceeds received from the sale of our Water Services businesses in 2004 and 2003, and proceeds received from ADESA in 2004. Equity losses related to investments in venture capital funds declined in 2005 ($0 in 2005; $1.6 million in 2004) as did impairments related to certain investments in our emerging technology portfolio ($3.3 million in 2005; $4.1 million in 2004). Financial results for 2004 also included an $11.5 million gain on the sale of ADESA stock related to our ESOP (see Note 17), which was partially offset by a $10.9 million debt prepayment cost associated with the retirement of long-term debt as a part of our financial restructuring in preparation for the spin-off of ADESA.
35 ALLETE 2006 Form 10-K
NET INCOME (CONTINUED)
DISCONTINUED OPERATIONS includes our Automotive Services business that was spun off on September 20, 2004, costs incurred by ALLETE associated with the spin-off of ADESA, our Water Services businesses that we sold over the three-year period from 2003 to 2005 and our telecommunications business, which we sold in December 2005. Discontinued operations reflected a $0.9 million loss in 2006 (a $4.3 million loss in 2005; $73.7 million of income in 2004).
In 2006, discontinued operations reflected a $0.9 million loss resulting from additional legal and administrative expenses related to exiting the Water Services businesses (a $2.5 million loss in 2005; a $1.3 million loss in 2004). In 2005, administrative and other expenses were incurred to support Florida Water transfer proceedings. A $1.0 million rate-base settlement charge related to the sale of 63 of Florida Water systems to Aqua Utilities Florida, Inc. was also recorded in 2005. Gains in 2004 from the sale of our North Carolina assets and the remaining systems in Florida were offset by an adjustment to gains reported in 2003. The adjustment to gains reported in 2003 resulted primarily from an arbitration award in December 2004 relating to a gain-sharing provision on a system sold in 2003. The majority of our Florida systems were sold in the fourth quarter of 2003. North Carolina assets were sold in June 2004. Our wastewater assets in Georgia were sold in February 2005.
Automotive Services contributed income of $74.4 million in 2004.
Financial results for our telecommunications business reflected a loss of $1.8 million in 2005 (income of $0.6 million in 2004). In 2005, we recorded a $3.6 million loss on the sale of this business. In 2005, income from operations was $1.2 million higher than 2004 primarily due to increased margins on telecommunication services.
CHANGE IN ACCOUNTING PRINCIPLE reflected the cumulative effect on prior years (to December 31, 2003) of changing to the equity method of accounting for investments in limited liability companies included in our emerging technology portfolio. (See Note 15.)
2006 COMPARED TO 2005
REGULATED UTILITY
OPERATING REVENUE was up $63.6 million, or 11%, from 2005, reflecting increased kilowatthour sales and increased fuel clause recoveries. Electric sales increased 1,127 million kilowatthours, or 10%, mostly due to the addition of Taconite Harbor wholesale power obligations to the Regulated Utility segment effective January 1, 2006. In 2006, the majority of Taconite Harbor sales are reflected in sales to other power suppliers. Sales to other power suppliers were 2,153 million kilowatthours and $94.3 million (1,142 million kilowatthours and $52.8 million in 2005). Absent the inclusion of pre-existing Taconite Harbor wholesale energy sales obligations, sales to other power suppliers were down reflecting less excess energy available for sale due to more planned outages at Company generating facilities in 2006 than 2005. Electric sales to retail and municipal customers increased 116 million kilowatthours, or 1%, and $23.5 million, mainly due to strong demand from industrial customers. Fuel clause recoveries were higher in 2006 as a result of increased fuel and purchased power expenses in 2006. Natural gas revenue was down $2.8 million from 2005 reflecting decreased usage due to warmer weather in 2006.
OPERATING EXPENSES were up $57.8 million, or 12%, from 2005.
FUEL AND PURCHASED POWER EXPENSE. Fuel and purchased power expense was up $38.0 million from 2005, reflecting the inclusion of Taconite Harbor operations beginning in 2006 ($22.8 million) and increased purchased power expense due to higher prices paid for purchased power, less Company hydro generation available as a result of below normal precipitation levels, and planned maintenance at Company generating facilities in 2006.
OTHER OPERATING EXPENSES. In total, other operating expenses were up $19.8
million from 2005. Employee compensation was up $7.3 million primarily due
to the inclusion of Taconite Harbor, annual wage increases and the
inclusion of union employees in our results sharing compensation awards
program. Depreciation expense increased $4.8 million primarily due to the
inclusion of Taconite Harbor and a full year of depreciation of projects
capitalized in 2005. In total, plant maintenance expense increased $4.7
million reflecting the inclusion of Taconite Harbor maintenance in 2006
($4.0 million), increased planned maintenance expense at Boswell Unit 4
($1.6 million) and increased equipment fuel expenses ($0.9 million)
partially offset by a decrease in maintenance expense at Boswell Unit 3
($1.8 million). In 2005, planned maintenance was performed at Boswell Unit
3 while the unit was down due to a cooling tower failure. Pension expense
increased $2.2 million primarily due to a reduction in the discount rate
(5.50% in 2006; 5.75% in 2005). Insurance expense was up $1.0 million due
to increased premiums. Vegetation management expense was up $0.7 million
due to more completed in 2006. Property taxes were up $0.7 million due to
higher mill rates in 2006. Purchased natural gas expense was down $2.7
million due to decreased natural gas sales.
INTEREST EXPENSE was up $2.8 million, or 16%, from 2005, reflecting the inclusion of Taconite Harbor in 2006 partially offset by lower effective interest rates (5.92% in 2006; 6.07% in 2005).
ALLETE 2006 Form 10-K 36
2006 COMPARED TO 2005 (CONTINUED)
NONREGULATED ENERGY OPERATIONS
OPERATING REVENUE was down $48.9 million, or 43%, from 2005 due to the absence of revenue from Taconite Harbor ($55.1 million in 2005) and Kendall County ($3.1 million in 2005). Effective January 1, 2006, Taconite Harbor is reported as part of Regulated Utility. Kendall County operations ceased to be included with our operations effective April 1, 2005, when the Company assigned the power purchase agreement to Constellation Energy Commodities. Coal revenue, realized under cost plus a fixed fee agreements, was up $3.7 million from 2005 reflecting a 16% increase in the delivery price per ton due to higher reimbursable coal production expenses (see operating expenses below). In 2006, tons of coal sold were down 7% from 2005 in part due to an outage at Minnkota Power's Unit 1 in 2006.
OPERATING EXPENSES were down $125.2 million, or 67%, from 2005 reflecting the absence of a $77.9 million charge related to the assignment of the Kendall County power purchase agreement to Constellation Energy Commodities on April 1, 2005, expenses related to Taconite Harbor ($49.3 million in 2005) and other expenses related to Kendall County ($6.3 million in 2005) that were incurred prior to April 1, 2005. Expenses related to coal operations were up $3.4 million reflecting increased equipment lease costs ($1.3 million), higher fuel expenses ($0.6 million) and increased parts and supplies ($0.9 million).
INTEREST EXPENSE was down $3.3 million, or 50%, primarily due to the absence of Taconite Harbor in 2006.
OTHER INCOME (EXPENSE) reflected $0.5 million more income in 2006 due to increased Minnesota land sales.
INVESTMENT IN ATC
OTHER INCOME (EXPENSE) reflected $3.0 million of income in 2006 from our equity investment in ATC, resulting from our share of ATC's earnings.
REAL ESTATE
OPERATING REVENUE was up $15.1 million, or 32%, from 2005, due to the recognition of revenue from prior land sales at our Town Center development project, which are accounted for under the percentage-of-completion method. Revenue from land sales was $56.1 million in 2006 which included $9.7 million of previously deferred revenue. In 2005, revenue from land sales was $42.0 million. Sales at Town Center represented 773 residential units and the rights to build up to 401,971 square feet of commercial space in 2006 (643,000 commercial square feet in 2005). Sales at Palm Coast Park represented 200 residential units in 2006. In 2006, 732 acres of other land were sold (1,102 acres and 7 lots in 2005). The first land sales for Town Center were recorded in June 2005 and the first land sales at Palm Coast Park were recorded in August 2006. At December 31, 2006, revenue of $5.6 million ($11.5 million at December 31, 2005) was deferred and will be recognized on a percentage-of-completion basis as development obligations are completed.
OPERATING EXPENSES were up $2.7 million, or 17%, from 2005 reflecting a $1.6 million increase in the cost of real estate sold ($10.2 million in 2006; $8.6 million in 2005) due to the recognition of the cost of real estate sold at our Town Center development project which were previously deferred under the percentage-of-completion method. Selling expenses increased $0.6 million due to higher broker commission in 2006 and recognition of prior year's selling expenses at our Town Center development project which were previously deferred under the percentage-of-completion method. Property tax expense was $0.2 million higher in 2006 due to increased assessment values and higher rates. At December 31, 2006, cost of real estate sold totaling $1.3 million ($2.2 million at December 31, 2005) and selling expenses of $0.2 million ($0.3 million at December 31, 2005), primarily related to Town Center land sales, were deferred until development obligations are completed.
OTHER
OPERATING EXPENSES were down $1.2 million, or 29%, from 2005, reflecting lower general and administrative expenses in 2006.
INTEREST EXPENSE was up $1.6 million, or 70%, from 2005, reflecting interest on additional taxes owed on the gain on the sale of our Florida Water assets and state tax audits, and higher variable rates in 2006.
OTHER INCOME (EXPENSE) reflected $10.1 million more income in 2006 due to a $4.4 million increase in earnings on cash and short-term investments due to higher rates and higher average balances in 2006, the absence of $5.1 million of impairments related to certain investments in our emerging technology portfolio recorded in 2005 and the absence of a $1.0 million charge recognized in 2005 for the probable payment under our guarantee of Northwest Airlines debt.
37 ALLETE 2006 Form 10-K
2006 COMPARED TO 2005 (CONTINUED)
INCOME TAXES
For the year ended December 31, 2006, the effective tax rate from continuing operations before minority interest was 36.1% (2.5% benefit for the year ended December 31, 2005). The increase in the effective rate compared to last year was primarily due to the lower income from continuing operations in 2005 as a result of the Kendall County Charge, and one-time tax benefits realized in 2005 for adjustments to our deferred tax assets and liabilities as a result of comprehensive state tax planning initiatives, and positive resolution of audit issues. The effective rate of 36.1% for the year ended December 31, 2006, was less than the combined state and federal statutory rate because of investment tax credits, deductions for Medicare health subsidies, depletion and the expected use of state capital loss carryforwards.
2005 COMPARED TO 2004
REGULATED UTILITY
OPERATING REVENUE was up $20.6 million, or 4%, from 2004. Revenue from other power suppliers was up $15.4 million from 2004 due to a 224 million, or 24%, increase in kilowatthour sales and higher market prices. In 2005, changes in scheduled plant outages resulted in more energy available for sale than in 2004. Transmission revenue was up $4.2 million from 2004, reflecting increased MISO-related revenue. Revenue from sales to retail and municipal customers was down $2.4 million, primarily due to lower fuel clause recoveries in 2005. (See operating expenses below.) Kilowatthour sales to retail and municipal customers remained strong--up 207 million, or 2%, from 2004, reflecting increased usage. Residential and municipal customer usage was higher in 2005 due to higher than normal summer temperatures in 2005. Commercial usage was higher due to stronger economic conditions in our electric service territory in 2005. Sales to industrial customers were similar to last year because, as in 2004, the Company's industrial customers were operating at high production levels, with taconite and paper production at or near capacity. Overall, regulated utility kilowatthour sales were up 431 million, or 4%, from 2004. Revenue from natural gas sales was up $2.5 million due to increased prices in the natural gas component of sales.
OPERATING EXPENSES were up $9.7 million, or 2%, from 2004. Fuel and purchased power expense was down $1.4 million from 2004 due to fewer outages. In 2004, increased purchased power was necessitated by outages at Company generating facilities and the Square Butte generating facility. Maintenance expense was up $3.4 million from 2004, reflecting planned maintenance performed at Boswell Units 1, 2 and 3 during 2005, partially offset by lower maintenance expense related to Boswell Unit 4 and Laskin Unit 1. In 2004, maintenance expense increased due to maintenance scheduled for 2005 and 2006 that was performed while Boswell Unit 4 was down as a result of a generator failure. Other operating expenses were $7.7 million higher in 2005--MISO transmission costs increased $4.1 million, natural gas purchases increased $2.6 million due to higher prices and pension expense increased $1.7 million primarily due to a reduction in the discount rate (5.75% in 2005; 6.00% in 2004). These increases were partially offset by the absence of $2.0 million of expenses related to Split Rock Energy, which we exited in March 2004.
INTEREST EXPENSE was down $1.1 million from 2004, primarily due to lower effective interest rates (6.07% in 2005; 6.67% in 2004).
NONREGULATED ENERGY OPERATIONS
OPERATING REVENUE was up $7.1 million, or 7%, from 2004. Revenue from Taconite Harbor increased $14.0 million from 2004, primarily due to higher demand as a result of two 5-year contracts (175 MW in total) that began in May 2005. Coal revenue, realized under cost plus a fixed fee agreements, was up $5.0 million from 2004, reflecting a 7% increase in tons of coal sold and an 8% increase in the delivery price per ton due to higher reimbursable coal production expenses. (See operating expenses below.) BNI Coal sold fewer tons of coal in 2004 due to a scheduled outage at the Square Butte generating facility. Revenue from Kendall County was down $13.4 million from 2004, reflecting the absence of operations since April 2005 when the Kendall County power purchase agreement was assigned to Constellation Energy Commodities. Overall, nonregulated kilowatthour sales were up 2% from 2004.
OPERATING EXPENSES were up $78.0 million, or 72%, from 2004, primarily due to the $77.9 million charge related to the assignment of the Kendall County power purchase agreement to Constellation Energy Commodities in April 2005. Nonregulated generation fuel and purchased power expense was down $11.7 million from 2004, reflecting the absence of Kendall County operations. Operating and maintenance expenses at Taconite Harbor were higher in 2005, reflecting a $2.3 million increase in SO2 emission allowance expense, a $1.0 million increase in contract services due to a longer than anticipated scheduled outage as well as unscheduled outages, and a $1.2 million increase in depreciation expense as a result of capitalized projects being completed and placed into operation. Expenses related to our coal operations were up $3.9 million, in part due to higher expenses associated with equipment repairs, increased fuel costs and a $2.1 million increase in lease expense related to the dragline.
ALLETE 2006 Form 10-K 38
2005 COMPARED TO 2004 (CONTINUED)
NONREGULATED ENERGY OPERATIONS (CONTINUED)
INTEREST EXPENSE was up $1.7 million from 2004, reflecting higher
allocations in 2005.
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OTHER INCOME (EXPENSE) reflected $1.1 million more income in 2005. Income from customer contract services was up $0.4 million from 2004. Income from Minnesota land sales was up $0.7 million from 2004, primarily due to an adjustment recorded as a result of an MPUC land reevaluation.
REAL ESTATE
OPERATING REVENUE was up $5.6 million, or 13%, from 2004, reflecting strong land sales offset by the deferral of revenue associated with certain real estate sales. Revenue from land sales was $42.0 million in 2005 ($35.8 million in 2004). Town Center land sales accounted for $4.5 million of land sale revenue in 2005. In 2005, revenue of $10.0 million, primarily related to Town Center land sales, was deferred until development obligations are completed ($1.5 million in 2004). Revenue from lot sales was lower in 2005 because in January 2004 we sold the remaining 184 lots at Sugarmill Woods for $3.9 million, essentially exiting the lot sales business. In 2005, 1,102 acres and 7 lots were sold. Town Center sales included assignments of rights to build up to 643,000 square feet of commercial space. In 2004, 1,479 acres and 211 lots were sold. Revenue from our brokerage business, Cape Properties, Inc., was down $0.7 million, reflecting unusually strong sales in 2004.
OPERATING EXPENSES were up $0.5 million, or 3%, from 2004. Cost of real estate sold was $2.1 million higher in 2005 ($8.6 million in 2005; $6.5 million in 2004) due to the type and location of real estate sold. In 2005, cost of real estate sold totaling $2.2 million ($0.4 million in 2004) and selling expense of $0.3 million, primarily related to Town Center land sales, were deferred until development obligations are completed. Expenses for our brokerage business were down $0.2 million due to unusually strong sales in 2004. Selling expenses were down $1.1 million from 2004 due to lower transaction costs and fewer brokerage commissions on 2005 sales. Property taxes were down $0.3 million from 2004, reflecting a reduction in land owned.
OTHER
OPERATING EXPENSES were up $0.9 million, or 28%, from 2004, primarily due to increased compensation expenses.
INTEREST EXPENSE was down $5.7 million from 2004, primarily due to lower debt balances. The Company repaid a $53 million balance on a credit agreement in April 2004 and $125 million of 7.80% Senior Notes in July 2004. A combination of internally-generated funds, proceeds from the sale of our Water Services assets and proceeds received from ADESA were used to repay the debt.
OTHER INCOME (EXPENSE) reflected $11.6 million less expense in 2005. Other income (expense) in 2005 reflected a $3.2 million increase in earnings on excess cash, a $1.2 million decrease in equity losses from our emerging technology investments and a $1.0 million charge to recognize the probable payment under our guarantee of Northwest Airlines debt. We also recorded $5.1 million of impairments related to certain investments in our emerging technology portfolio in 2005 ($6.5 million in 2004). In 2004, other income (expense) included an $18.5 million debt prepayment cost related to the early redemption of $125 million in senior notes, an $11.5 million gain on the sale of ADESA shares held in our ESOP (see Note 17), and $0.9 million of income from a rabbi trust established to secure certain deferred executive compensation.
INCOME TAXES. The effective tax rate from continuing operations before minority interest was a 2.5% benefit in 2005 (28.8% expense in 2004). Income taxes in 2005 were affected by three major items, the adjustment of our deferred taxes from comprehensive state tax planning initiatives, a current tax benefit from the positive resolution of audit issues and the inability to use state capital loss carryforwards. The adjustment of our deferred tax assets and liabilities resulted in a deferred tax benefit. We received an audit report resolving open issues that resulted in a current tax benefit. These items decreased our overall tax expense. The emerging technology investment impairments recorded in March 2005 and the Kendall County Charge recorded in April 2005 created capital losses. The current benefit for these items was limited to a federal benefit for income tax purposes. The state tax benefit from these items is not expected to be realized currently or in future periods. The benefit related to these state net capital loss carryforwards was fully offset by a valuation allowance. This resulted in an increase in our overall tax expense. Current taxes also increased in 2005 due to the expiration of the accelerated depreciation deduction allowed by the Jobs and Growth Tax Relief Act of 2003, which expired December 31, 2004. An increase in the Federal Medicare subsidy and the new Domestic Manufacturing Deduction contributed to lower taxes in 2005. Income taxes for 2004 were primarily affected as a result of the benefit of the nontaxable gain from the sale of ADESA common stock in our ESOP. (See Note 13.)
39 ALLETE 2006 Form 10-K
NON-GAAP FINANCIAL MEASURES
We prepare financial statements in accordance with GAAP. Along with this information, we disclose and discuss certain non-GAAP financial information in our quarterly earnings releases, on investor conference calls and during investor conferences and related events. Management believes that non-GAAP financial data supplements our GAAP financial statements by providing investors with additional information which enhances the investors' overall understanding of our financial performance and the comparability of our operating results from period to period. The presentation of this additional information is not meant to be considered in isolation or as a substitute for our results of operations prepared and presented in accordance with GAAP.
As earlier mentioned, financial results for 2005 were significantly impacted by the following transactions:
- A $50.4 million after tax, or $1.84 per share, charge due to the
assignment of the Kendall County power purchase agreement to
Constellation Energy Commodities (see Note 10);
- A $3.7 million, or $0.13 per share, current tax benefit due to a
positive resolution of income tax audit issues; and
- A $2.5 million, or $0.09 per share, deferred tax benefit due to
comprehensive state tax planning initiatives.
In 2004, financial results were significantly impacted by the following transactions:
- A $10.9 million after tax, or $0.38 per share, debt prepayment cost as
part of ALLETE's financial restructuring in preparation for the
spin-off of Automotive Services (see Note 11); and
- An $11.5 million after tax, or $0.41 per share, gain on the sale of
ADESA shares related to our ESOP (see Note 17).
Since these transactions significantly impacted the financial results from continuing operations in 2005 and 2004, we believe that for comparative purposes and a more accurate reflection of our ongoing operations, it is useful to present diluted earnings per share from continuing operations for each applicable period excluding the impact of these items. The table below reconciles actual reported diluted earnings per share from continuing operations before change in accounting principle to the adjusted results that exclude these transactions in the respective periods.
FOR THE YEAR ENDED DECEMBER 31 2006 2005 2004
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DILUTED EARNINGS PER SHARE OF COMMON STOCK
Continuing Operations Before Change in Accounting Principle $2.77 $0.64 $1.35
Add: Kendall County Charge - 1.84 -
Debt Prepayment Cost - - 0.38
Less: Gain on Sale of ADESA Shares - - 0.41
Positive Resolution of Tax Audit Issues - 0.13 -
State Tax Planning Initiatives - 0.09 -
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$2.77 $2.26 $1.32
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CRITICAL ACCOUNTING ESTIMATES
The preparation of financial statements and related disclosures in conformity with generally accepted accounting principles requires management to make various estimates and assumptions that affect amounts reported in the consolidated financial statements. These estimates and assumptions may be revised, which may have a material effect on the consolidated financial statements. Thus, actual results could differ from the amounts reported and disclosed herein. These policies are discussed with the Audit Committee of our Board of Directors on a regular basis. The following represent the policies we believe are most critical to our business and the understanding of our results of operations.
REAL ESTATE REVENUE AND EXPENSE RECOGNITION. We account for sales of real estate in accordance with SFAS 66, "Accounting for Sales of Real Estate." Revenue from commercial and residential properties is recorded at the time of closing using the full profit recognition method, provided that cash collections are at least 20% of the contract price and the other requirements of SFAS 66 are met. However, if we are obligated to perform significant development activities subsequent to the date of the sale, we recognize revenue using the percentage-of-completion method. This method of accounting requires that we recognize gross profit based upon the relationship of development costs incurred to the total estimated costs to develop the parcels. During each reporting period, we must estimate the total costs to be incurred until project completion, including development overhead and interest capitalization costs. These total cost estimates will impact the recognition of profit on sales. The costs are allocated to each lot or parcel based on the relative sales value method. These estimates affect the amount of costs relieved as each lot is sold and incorrect estimates may result in a misstatement of the cost of real estate sold. Additionally, we must estimate the selling price of each individual lot or parcel that is included in inventory for inclusion in the inventory cost model. If the estimated selling prices of the lots are inaccurate, a material difference in the timing of recording cost of real estate sold for the lots sold could occur.
ALLETE 2006 Form 10-K 40
CRITICAL ACCOUNTING ESTIMATES (CONTINUED)
We record land held for sale at the lower of cost or fair value, which is determined by the evaluation of individual land parcels. Real estate costs include the cost of land acquired, subsequent development costs and costs of improvements, capitalized development period interest, real estate taxes and payroll costs of certain employees devoted directly to the development effort. Based on the relative sales value of the parcels within each development project, we capitalize the real estate costs incurred to the cost of real estate parcels in accordance with SFAS 67, "Accounting for Costs and Initial Rental Operations of Real Estate Projects." When real estate is sold, we include the actual costs incurred and the estimate of future completion costs allocated to the parcel(s) sold, based upon the relative sales value method in the cost of real estate sold. We include land held for sale in Investments on our consolidated balance sheet. In certain cases, we pay fees or construct improvements to mitigate offsite traffic impacts. In return, we receive traffic impact fee credits. We recognize revenue from the sale of traffic impact fee credits when payment is received. In addition to minimum base price contracts, certain contracts allow us to receive participation revenue from land sales to third parties if various formula-based criteria are achieved.
We annually review the real estate carrying value for impairment. If circumstances indicate that the carrying value may not be recoverable, we record an impairment and adjust the related assets to their estimated fair value less costs to sell.
IMPAIRMENT OF LONG-LIVED ASSETS. We account for our long-lived assets at depreciated historical cost. A long-lived asset is tested for recoverability whenever events or changes in circumstances indicate that its carrying amount may not be recoverable. We conduct this assessment using SFAS 144, "Accounting for the Impairment and Disposal of Long-Lived Assets." Judgments and uncertainties affecting the application of accounting for asset impairment include economic conditions affecting market valuations, changes in our business strategy, and changes in our forecast of future operating cash flows and earnings. We would recognize an impairment only if the carrying amount of a long-lived asset is not recoverable from its undiscounted future cash flows. Management judgment is involved in both deciding if testing for recoverability is necessary and in estimating undiscounted future cash flows.
PENSION AND POSTRETIREMENT HEALTH AND LIFE ACTUARIAL ASSUMPTIONS. We account for our pension and postretirement benefit obligations in accordance with the provisions of SFAS 158, "Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans," SFAS 87, "Employers' Accounting for Pensions," and SFAS 106, "Employers' Accounting for Postretirement Benefits Other Than Pensions." These standards require the use of assumptions in determining our obligations and annual cost of our pension and postretirement benefits. An important actuarial assumption for pension and other postretirement benefit plans is the expected long-term rate of return on plan assets. In establishing this assumption, we consider the diversification and allocation of plan assets, the actual long-term historical performance for the type of securities invested in, the actual long-term historical performance of plan assets and the impact of current economic conditions, if any, on long-term historical returns. Our pension asset allocation is approximately 65% equity, 30% fixed-rate and 5% other securities. Equity securities consist of a mix of market capitalization sizes and also include investments in real estate and venture capital funds. We currently use an expected long-term rate of return of 9% in our actuarial determination of our pension and other postretirement expense. We annually review our expected long-term rate of return assumption and will adjust it to respond to any changing market conditions. A 1/2% decrease in the expected long-term rate of return would increase the annual expense for pension and other postretirement benefits by approximately $1 million after tax; conversely, a 1/2% increase in the expected long-term rate of return would decrease the annual expense by approximately $1 million after tax.
Currently for plan valuation purposes, we use a discount rate of 5.75%. The discount rate is determined considering high-quality long-term corporate bond rates at the valuation date. The discount rate is compared to the Citigroup Pension Discount Curve adjusted for ALLETE's specific cash flows. We believe the adjusted discount curve used in this comparison does not materially differ in duration and cash flows for our pension obligation. The Audit Committee of the Board of Directors annually reviews and approves the rate of return and discount rate used for pension valuation and accounting purposes. (See Note 16.)
REGULATORY ACCOUNTING. Our regulated utility operations are subject to the provisions of SFAS 71, "Accounting for the Effects of Certain Types of Regulation" (SFAS 71). SFAS 71 requires us to reflect the effect of regulatory decisions in our financial statements. Regulatory assets or liabilities arise as a result of a difference between accounting principles generally accepted in the U.S. and the accounting principles imposed by the regulatory agencies. Regulatory assets generally represent incurred costs that have been deferred as they are probable of recovery in customer rates. Regulatory liabilities generally represent obligations to make refunds to customers and amounts collected in rates for which the related costs have not yet been incurred.
We recognize regulatory assets and liabilities in accordance with applicable state and federal regulatory rulings. The recoverability of regulatory assets is periodically assessed by considering factors such as, but not limited to, changes in regulatory rules and rate orders issued by applicable regulatory agencies. The assumptions and judgments used by regulatory authorities may have an impact on the recovery of costs, the rate of return on invested capital, and the timing and amount of assets to be recovered by rates. A change in these assumptions may result in a material impact on our results of operations. (See Note 5.)
41 ALLETE 2006 Form 10-K
CRITICAL ACCOUNTING ESTIMATES (CONTINUED)
VALUATION OF INVESTMENTS. As part of our emerging technology portfolio, we have several minority investments in venture capital funds and direct investments in privately-held, start-up companies. We account for our investment in venture capital funds under the equity method and account for our direct investments in privately-held companies under the cost method because of our ownership percentage. These investments are included in Investments on our consolidated balance sheet. Our policy is to review these investments for impairment on a quarterly basis by assessing such factors as continued commercial viability of products, cash flow and earnings. Any impairment would reduce the carrying value of the investment and be recognized as a loss. In 2006, we did not record an impairment loss on these investments ($5.1 million pretax in 2005).
PROVISION FOR ENVIRONMENTAL REMEDIATION. Our businesses are subject to regulation by various federal, state and local authorities concerning environmental matters. We review environmental matters on a quarterly basis. Accruals for environmental matters are recorded when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated, based on current law and existing technologies. These accruals are adjusted periodically as assessment and remediation efforts progress, or as additional technical or legal information becomes available. Accruals for environmental liabilities are included in the balance sheet at undiscounted amounts and exclude claims for recoveries from insurance or other third parties. Costs related to environmental contamination treatment and cleanup are charged to expense. We do not currently anticipate that potential expenditures for environmental remediation and cleanup will be material; however, if we become subject to more stringent remediation at known sites, if we discover additional contamination or previously unknown sites, or if we become subject to related personal or property damage, we could incur material costs in connection with our environmental remediation.
TAXATION. We are required to make judgments regarding the potential tax effects of various financial transactions and our ongoing operations to estimate our obligations to taxing authorities. These tax obligations include income, real estate and use taxes. These judgments include reserves for potential adverse outcomes regarding tax positions that we have taken. We must also assess our ability to generate capital gains to realize tax benefits associated with capital losses expected to be generated in future periods. Capital losses may be deducted only to the extent of capital gains realized during the year of the loss or during the three prior or five succeeding years for federal purposes, and fifteen succeeding years for Minnesota purposes. As of December 31, 2006, we have, where appropriate, recorded a valuation allowance against our deferred tax assets associated with realized capital losses and impairments to reduce the deferred tax assets to the amount we estimate is more likely than not to be realized. While we believe the resulting tax reserve balances as of December 31, 2006, reflect the most likely outcome of these tax matters in accordance with SFAS 109, "Accounting for Income Taxes," the ultimate amount of capital losses resulting in tax benefits could differ from the net amount of deferred tax assets at December 31, 2006.
OUTLOOK
ALLETE is committed to earning a financial return that rewards its shareholders, allows for reinvestment in its businesses and sustains growth. In the last 10 years, our average annual total shareholder return was 17%. By comparison, the Standard & Poor's 500 Index averaged 8% for the same period. We believe that, in order to enhance our ability to achieve our long-term annual earnings growth goals, we must pursue a strategy of further expansion of our energy and/or real estate businesses, and/or a new industry segment outside of these two businesses.
EARNINGS GUIDANCE. In 2007, we expect ALLETE's diluted earnings per share from continuing operations to be in the range of $2.95 to $3.05. The growth in earnings per share is expected to come primarily from our larger full-year investment in ATC. We also expect increased sales at our Real Estate operations and continued strong sales at our Regulated Utility operations. This earnings projection does not include an impact from any investment we may make in new growth opportunities.
ENERGY. As part of our strategy, we will leverage the strengths of our Regulated Utility business to improve our strategic and financial outlook and seek growth opportunities in close geographic proximity to existing operations in the Midwest. In addition, we will evaluate growth opportunities through merger, acquisition or asset additions in our region. We believe our energy businesses are well positioned to successfully deal with the issues affecting the electric utility industry and to compete successfully. Our access to and ownership of low-cost power are our greatest strengths. We anticipate that we will have ready access to sufficient funds for capital investments. We believe electric industry deregulation is unlikely in Minnesota or Wisconsin in the next five years.
RATE CASES. Minnesota Power does not expect to file a request to increase rates for its retail utility operations during 2007. We will, however, continue to monitor the costs of serving our retail customers and evaluate the need for a rate filing in the future. Minnesota Power's retail rates are based on a 1994 MPUC retail rate order.
ALLETE 2006 Form 10-K 42
OUTLOOK (CONTINUED)
In May 2006, SWL&P filed an application with the PSCW for authority to increase retail utility rates on its electric, natural gas and water services an average of 5.2%, and requested an 11.7% return on common equity. An order was issued in December 2006 that allows for an 11.1% return on common equity. New rates became effective January 1, 2007, and reflect a 2.8% average increase in retail utility rates for SWL&P customers (a 2.8% increase in electric rates, a 1.4% increase in natural gas rates and an 8.6% increase in water rates). The rate case allowed for a $1.7 million increase in annual revenue requirements. The approved rates were lower than originally requested due to the subsequent removal of costs for a new water tower and electric substation from the original request. Both of these projects are now estimated to be in service in late 2008 because of delays in obtaining all the necessary construction approvals. SWL&P plans to file for another rate increase request in 2008.
INDUSTRIAL CUSTOMERS. Approximately 50% of our Regulated Utility kilowatthour sales are made to our Large Power Customers in the taconite, paper and pulp, and pipeline industries. Based on our research of the taconite industry, Minnesota taconite production for 2007 is anticipated to be about 40 million tons (production was 40 million tons in 2006; 41 million tons in 2005 and in 2004).
There was a slight slowdown for two of our customers in the paper industry in late December 2006 and early January 2007 due to slightly lower demand for their products and a need to balance orders with inventory. It is not known whether this trend will continue further into 2007. In addition, the wood products industry is operating at reduced levels reflecting a decrease in the number of new housing starts.
Our pipeline customers continued to operate at or above historic pumping levels during 2006 and forecast operating at record pumping levels in 2007. As Western Canadian oil sands reserves continue to develop and expand, pipeline operators served by the Company are executing expansion plans to transport additional crude oil supply to United States markets. We believe we are strategically positioned to serve these expanding pipeline facilities as Canadian supply continues to grow and displace domestic and imported Gulf Coast production.
Several natural resource-based companies have been making significant progress developing new projects in northeastern Minnesota. Minnesota Power has actively supported these projects which include paper, ferrous and non-ferrous developments. If some or all of these projects are completed, Minnesota Power could serve between 100 MW and 400 MW of new load. In 2006, a contract for approximately 70 MW was successfully negotiated with PolyMet Mining, a new customer planning to start a copper, nickel and precious metals (non-ferrous) mining operation in late 2008. If PolyMet's environmental permits are received and start-up is achieved, the contract with PolyMet Mining will run through at least 2018. The PolyMet Mining electric service agreement requires MPUC approval.
ADDITIONAL GENERATION NEEDS. In 2006, the MPUC approved our Resource Plan, which detailed our forecasted retail energy needs and our projected demand along with our energy sourcing options to meet these projected requirements. We project an additional capacity need of approximately 150 MW by 2010, with another 200 MW of capacity needed by 2015. One of the key components in meeting our future needs was the redirection of our Taconite Harbor generating facility from Nonregulated Energy Operations to Regulated Utility operations effective January 1, 2006. We have also entered into a 50-MW long-term power purchase agreement with Manitoba Hydro which extends from May 2009 to April 2015 that is pending regulatory approval. We began purchasing the output from the 50-MW Oliver Wind I project in North Dakota under a 25-year power purchase agreement with an affiliate of FPL Energy in late December 2006. In January 2007, we announced plans for a second, 48-MW North Dakota wind project (Oliver Wind II) that is expected to be operational by the end of 2007, pending regulatory and other approvals. In addition, we are continuing to pursue the purchase of renewable energy from a new 25-MW to 30-MW wind facility that would be located in northeastern Minnesota, subject to a power purchase agreement and regulatory approvals.
We are also exploring construction and purchase options for our anticipated resource needs by 2015. Minnesota Power, Basin Electric Power Cooperative, Minnkota Power and Montana-Dakota Utilities Company are continuing a study that will evaluate the feasibility of a joint lignite-fueled generating resource in the vicinity of the existing Milton R. Young generating station (which includes Square Butte) near Center, North Dakota. We are also continuing to study the feasibility of the construction of a natural gas-fired electric generating facility which could be located in northwestern Wisconsin or northeastern Minnesota. Any final resource decision by Minnesota Power is subject to MPUC and other approvals.
We anticipate that our winter peak demand requirements by customers in our service territory will increase at an average annual growth rate of 1.5% through 2011. We continue to make investments to maintain and improve the integrity of our generating, transmission and distribution assets, and maintain environmental compliance.
43 ALLETE 2006 Form 10-K
OUTLOOK (CONTINUED)
AREA AND BOSWELL UNIT 3 EMISSION REDUCTION PLANS. In May 2006, the MPUC approved our filing for cost recovery of planned expenditures to reduce emissions to meet pending federal requirements at Taconite Harbor and Laskin under the AREA Plan. The AREA Plan approval allows Minnesota Power to recover Minnesota jurisdictional costs for SO2, NOX and mercury emission reductions made at these facilities without a rate proceeding. Minnesota cost recovery from retail customers will include return on investment, depreciation, and incremental operations and maintenance expenses. Minnesota Power completed installation of new equipment at the first of two Laskin units at the end of November 2006, with the first of three Taconite Harbor unit installations anticipated to be completed by mid-2007. Work on all units at Taconite Harbor and Laskin is anticipated to be completed by the end of 2008. Cost recovery filings are required to be made 90 days prior to the anticipated in-service date for the equipment at each unit, with rate recovery beginning the month following the in-service date. We began cost recovery of AREA plan costs in December 2006 with the placement in service of Laskin Unit 2. We filed with the MPUC for cost recovery on Laskin Unit 1 in January 2007 and expect to begin cost recovery in May 2007. We anticipate beginning cost recovery on Taconite Harbor Unit 2 in mid-2007 and Taconite Harbor Units 1 and 3 in 2008. AREA plan expenditures as of December 31, 2006, were $11.4 million.
In May 2006, we announced plans to make emission reduction investments at our Boswell Unit 3 generating unit. Plans include reductions of particulate, SO2, NOX and mercury emissions to meet pending federal and state requirements. The estimated capital cost for these reductions is approximately $200 million, $14 million of which was spent in 2006 for design engineering and related costs. The balance is expected to be spent from 2007 through 2009 and is included in the $233 million the Company expects to spend for environmental upgrades from 2007 through 2011. (See Capital Requirements.) In October 2006, we submitted a filing to the MPCA for approval of the Boswell Unit 3 emission reduction plan. A filing with the MPUC for approval of Minnesota jurisdictional related expenditures on Boswell Unit 3 was made in January 2007 to allow cost recovery on these investments from retail customers without a rate proceeding. MPUC approval would authorize a cash return on construction work in progress during the construction phase and allow recovery for a return on investment, depreciation, and incremental operations and maintenance expenses once the unit is placed into service in late 2009. We expect to begin cost recovery on construction work in progress in 2008. In 2007, we will be filing with the MPUC a request to extend the asset life for depreciation purposes on Boswell Unit 3 from 8 years to 29 years. We anticipate approval of this filing in 2007. This extension will reduce 2007 depreciation expense by approximately $5 million.
CAIR AND CAMR. In March 2005, the EPA issued its Clean Air Interstate Rule (CAIR) which would reduce emissions of SO2 and NOX. In November 2005, the EPA granted reconsideration of the CAIR. Minnesota Power filed comments for reconsideration arguing that the state of Minnesota did not belong in CAIR and that SO2 allocations proposed under the CAIR were unfair. CAIR was finalized by the EPA in March 2006 when the EPA determined it would not make any changes to the CAIR as a result of the petitions for reconsideration. Petitions for Review, including Minnesota Power's, remain pending at the Court of Appeals, with resolution of the Petitions for Review anticipated in 2008. In March 2005, the EPA issued its Clean Air Mercury Rule (CAMR). The EPA granted reconsideration of the CAMR in October 2005 and finalized the rule in early 2006. Minnesota Power is not participating in the Petitions for Review of the CAMR. The final outcomes of these regulatory proceedings are expected to require significant capital investments in the 2008 to 2012 timeframe. (See Capital Requirements.)
MISO AND FUEL CLAUSE. As a result of MISO Day 2 implementation in April 2005, energy transactions to serve retail customers are sourced through wholesale transactions with MISO as the counterparty. We filed a petition with the MPUC in February 2005 to amend our fuel clause to accommodate costs and revenue related to MISO Day 2 market implementation. In April 2005, the MPUC approved interim ratemaking treatment of MISO Day 2 costs, which allowed these costs to be recovered through the fuel clause, subject to refund with interest.
In December 2005, the MPUC issued an order which denied recovery through the fuel clause of uplift charges, congestion revenue and expenses, and administrative costs related to Minnesota Power's MISO Day 2 market activities. This denial created a refund obligation. Minnesota Power requested rehearing of the order in a filing made with the MPUC in January 2006. Three other Minnesota utilities affected by the order also filed for rehearing, as did the DOC and MISO. In February 2006, the MPUC granted rehearing of the MISO Day 2 docket and suspended the refund obligation for charges recovered through the fuel clause denied in the December 2005 order. The MPUC also ordered a review of MISO Day 2 costs to determine which costs should be recovered on a current basis through the fuel clause and which costs were more appropriately deferred for potential recovery through base rates. The Company worked with other Minnesota utilities, the DOC and other stakeholders to review MISO Day 2 costs and to prepare a joint report and recommendations. The joint report and recommendations were filed with the MPUC in June 2006. A technical conference on the report was held with the MPUC on October 31, 2006. At a hearing November 9, 2006, the MPUC approved current recovery of nearly all MISO Day 2 charges.
ALLETE 2006 Form 10-K 44
OUTLOOK (CONTINUED)
On December 20, 2006, the MPUC issued an order allowing Minnesota Power and the other utilities involved in the MISO Day 2 proceeding to continue recovering MISO Day 2 charges through the Minnesota retail fuel clause except for MISO Day 2 administrative charges. On January 8, 2007, this order was challenged by the Minnesota OAG, which has sought reconsideration. The rehearing has been opposed by Minnesota Power and the other utilities, as well as MISO. The reconsideration request is currently pending before the MPUC. The MPUC has until March 9, 2007, to act on the Minnesota OAG's request. The order, if upheld, grants deferred accounting treatment for three MISO Day 2 charge types that were determined to be administrative charges. Under the order, Minnesota Power would refund through customer bills approximately $2 million of administrative charges previously collected through the fuel clause between April 1, 2005, and December 31, 2006, and record these administrative charges as a regulatory asset. Minnesota Power would be permitted to continue accumulating MISO Day 2 administrative charges after December 31, 2006, as a regulatory asset until it files its next rate case, at which time recovery for such charges will be determined. This order would remove the subject to refund requirement of the two interim orders, and include extensive fuel clause reporting requirements that would be reviewed in Minnesota Power's monthly and annual fuel clause filings with the MPUC. There would be no impact on earnings as a result of this ruling. The Company is unable to predict the outcome of this matter.
As a result of the MPUC's December 2006 order allowing recovery of nearly all MISO Day 2 charges through the fuel clause, on December 28, 2006, Minnesota Power rescinded its December 2005 Letter of Intent to Withdraw from MISO.
INVESTMENT IN ATC. In December 2005, we entered into an agreement with Wisconsin Public Service Corporation and WPS Investments, LLC that provides for our Wisconsin subsidiary, Rainy River Energy Corporation - Wisconsin, to invest $60 million in ATC. In May 2006, the PSCW reviewed and approved the request that allows us to invest in ATC. During 2006, we invested $51.4 million in ATC. We plan to invest an additional $8.6 million in ATC in early 2007 to reach our $60 million investment commitment and estimated 8% ownership interest. As of December 31, 2006, our equity investment balance in ATC was $53.7 million, representing approximately a 7% ownership interest. (See Note 6.) We will have the opportunity to make additional investments in ATC through general capital calls based upon our pro-rata investment level in ATC.
REAL ESTATE. We have a diversified mix of property under contract and available for sale--residential, commercial and industrial--in desirable Florida locations (see Item 1 - Real Estate). A large portion of our real estate inventory is located in Florida's Flagler and Volusia Counties, an area with one of the fastest growing populations in the United States. We expect this population growth to continue, which will increase the demand for real estate in the area. Rapid residential growth over the past few years in our markets has created a steady demand for our commercial properties. As of December 31, 2006, we had $113.8 million of pending contracts scheduled to close over the next several years. We believe the long-term growth indicators for Florida real estate remain strong.
Progress continues on our three major planned development projects in Florida--Town Center, which will be a new downtown for Palm Coast; Palm Coast Park, which is located in northwest Palm Coast; and Ormond Crossings, which is located in Ormond Beach along Interstate 95. Other ongoing land sales and rental income at the retail shopping center in Winter Haven provide us with additional revenue.
ALLETE Properties plans to maximize the value of the property it currently owns through entitlement, infrastructure improvements and orderly sales of properties. In addition to managing its current real estate inventory, ALLETE Properties is focused on identifying, acquiring and entitling vacant land in Florida and other parts of the southeast United States.
As of December 31, 2006, we had $4.1 million of deferred profit on sales of real estate, before taxes and minority interest, on our balance sheet. Most of the deferred profit relates to Town Center which will be recognized over the next several years as development obligations are completed.
TOWN CENTER. Throughout 2005 and 2006, our marketing program targeted a blend of office, retail commercial, residential and mixed-use project developers. In 2006, a Publix grocery store anchored retail center opened and construction started on an 84,000 square foot medical center. Twenty other projects are in the permitting stage, 11 of which are expected to break ground in 2007. Future marketing efforts will focus on attracting the following additional land uses to Town Center: residential apartments, assisted living facilities, business park uses and restaurants.
Pending land sales under contract for properties at Town Center totaled $40.1 million at December 31, 2006. We have the opportunity to receive participation revenue as part of one of these sales contracts. Among the pending Town Center sales contracts is a contract with Developers Realty Corporation (DRC) to develop projects in the downtown core area and a large retail shopping center on a 50-acre tract. DRC has entered into an agreement to form a joint venture with Weingarten Realty Investors (Weingarten). DRC/Weingarten has a commitment from a major national retail anchor for the retail shopping center.
Sites have also been set aside for a new city hall, an arts and entertainment center, and other public uses. At build-out, Town Center is expected to include over 2,900 residential units, including lodging facilities and 3.7 million square feet of various types of commercial space, including a movie theater. Future market conditions will determine how quickly Town Center is built out.
45 ALLETE 2006 Form 10-K
OUTLOOK (CONTINUED)
PALM COAST PARK. We began selling property at Palm Coast Park in August 2006. Three developers who have purchased land at Palm Coast Park have started planning, engineering design and permitting of their respective projects. Since land is being sold before completion of the project infrastructure, revenue and cost of real estate sold are recorded using a percentage-of-completion method.
In 2006, the Palm Coast Park District issued $31.8 million of tax-exempt, 5.7% Special Assessment Bonds, the majority of which will be used to fund the construction of the major infrastructure improvements at Palm Coast Park, and to mitigate traffic and environmental impacts at Palm Coast Park. Major infrastructure construction began in December 2006 and is expected to be completed in 2007. Commercial and industrial lots will be offered for sale in 2007, with closings anticipated to begin in 2008. We anticipate that the Palm Coast Park District will need to issue additional bonds to pay for the development of residential and commercial properties.
At December 31, 2006, pending land sales under contract for properties at Palm Coast Park totaled $62.8 million. We have the opportunity to receive participation revenue as part of these sales contracts. One of the pending sales contracts, for the sale of five residential tracts and one commercial tract for a total of $52.5 million, provides for closings in 2007, 2008 and 2009. The project, which is named Sawmill Creek, will include up to 1,469 residential housing units, a championship golf course and neighborhood retail office space, along with a community park and an elementary and middle school. Other pending land sale contracts include a residential tract for an affordable condominium project and a 600-unit single-family residential project that will be connected to the existing Matanzas Woods golf course neighborhood.
ORMOND CROSSINGS. In December 2006, we received DRI approval from the city of Ormond Beach for our 6,000-acre Ormond Crossings project. This is a key approval necessary to develop up to 3,700 residential units and 5 million commercial square feet within Ormond Crossings. Most of Ormond Crossings is located in the city of Ormond Beach in Volusia County; the remainder of the development is an adjacent piece of unincorporated land in neighboring Flagler County. A development order from Flagler County is under review by the Flagler County Commission and, if approved, we will receive entitlements for up to 700 additional residential units. Actual build-out of Ormond Crossings, however, will consider market demand as well as infrastructure and mitigation costs.
After an agreement is finalized with the Florida Department of Transportation concerning traffic mitigation costs, we will determine the best economic build-out of the project. The agreement and economic analysis are expected to be completed in 2007.
Engineering design and permitting will be ongoing as the project is developed and sites are sold. We anticipate Ormond Crossings land sales closings starting in 2009.
OTHER. We have the potential to recognize gains or losses on the sale of investments in our emerging technology portfolio. We plan to sell investments in our emerging technology portfolio as shares are distributed to us. Some restrictions on sales may apply, including, but not limited to, underwriter lock-up periods that typically extend for 180 days following an initial public offering. We have committed to make additional investments in certain emerging technology holdings. The total future commitment was $2.5 million at December 31, 2006, and is expected to be invested in 2007. We do not have plans to make any additional investments beyond this commitment.
INCOME TAXES. ALLETE's aggregate federal and multi-state statutory tax rate is expected to be approximately 40% for 2007. On an ongoing basis ALLETE, has certain tax credits and other tax adjustments that will reduce the expected effective tax rate to approximately 38% for 2007. These tax credits and adjustments historically have included items such as investment tax credits, depletion allowances, Medicare prescription reimbursement as well as other items. The effective rate will also be impacted by such items as changes in income from operations before minority interest and income taxes, state and federal tax law changes that become effective during the year, business combinations and configuration changes, tax planning initiatives and resolution of prior years' tax matters. Based upon our earnings per share guidance for 2007, we expect our effective tax rate for 2007 to approximate 38%.
LIQUIDITY AND CAPITAL RESOURCES
CASH FLOW ACTIVITIES
Our strategy includes growing our businesses both internally by expanding facilities, services and operations (see Capital Requirements), and externally through acquisitions.
We believe our financial condition is strong, as evidenced by cash and cash equivalents of $44.8 million, $104.5 million of short-term investments and a debt to total capital ratio of 37% at December 31, 2006.
ALLETE 2006 Form 10-K 46
LIQUIDITY AND CAPITAL RESOURCES (CONTINUED)
OPERATING ACTIVITIES. Cash from operating activities was $142.5 million for 2006 ($53.5 million for 2005; $175.0 million for 2004). Cash from operating activities was higher in 2006 than 2005, primarily due to the $77.9 million Kendall County Charge in 2005 and related $24.3 million federal tax refund received in 2006. Cash also increased $4.4 million in 2006 due to the collection of customer receivables which were up as a result of colder weather in December 2005. Other differences between 2006 and 2005 include an additional $9 million cash used for inventories in 2006 and the payment of approximately $13 million of 2005 accrued liabilities. Additional inventories primarily reflect coal purchases in anticipation of maintenance on coal handling equipment.
Cash from operating activities was lower in 2005 than 2004 due to the absence of cash from discontinued operations ($2.3 million in 2005; $108.8 million in 2004). In 2004, we spun off our Automotive Services business and essentially completed the exit from our Water Services businesses. The lower cash from operations was partially offset by the collection of a $6.7 million outstanding receivable at December 31, 2004, from ATC for work on the Duluth-to-Wausau transmission line and other receivables, and an additional $7.5 million of deferred profit on real estate activities.
INVESTING ACTIVITIES. Cash used for investing activities was $154.7 million for 2006 (cash from investing activities of $3.9 million for 2005; cash used for investing activities of $126.5 million for 2004). Gross proceeds from the sale of available-for-sale securities were $608.8 million in 2006 ($376.0 million in 2005; $1.9 million in 2004) and purchases were $596.4 million ($343.7 million in 2005; $149.5 million in 2004). Cash used for investing activities was higher in 2006 than 2005, primarily due to $51.4 million invested in ATC and a $43.7 million increase in expenditures for property, plant and equipment due to major environmental construction projects.
Cash from investing activities was higher in 2005 than 2004, primarily due to a $179.9 million increase in net proceeds received from the sale of short-term investments and $35.5 million received from the sale of Enventis Telecom. These increases were partially offset by the absence of $66.0 million proceeds received in 2004 from the sale of our remaining Water Services businesses and $12.0 million received from Split Rock Energy in 2004 upon termination of the joint venture.
FINANCING ACTIVITIES. Cash used for financing activities was $32.6 million for 2006 ($13.9 million for 2005; $228.7 million for 2004). Cash used for financing activities was higher in 2006 than 2005 primarily due to an additional $7.2 million in dividends paid as a result of more shares outstanding, a higher dividend rate and fewer shares of common stock issued under our long-term incentive compensation plan. In 2006, we refinanced $77.8 million of long-term debt at lower rates.
Cash used for financing activities was lower in 2005 than 2004 primarily due to significant debt repayment ($35.7 million in 2005; $241.1 million in 2004). In 2005, we refinanced $35 million of long-term debt at a lower rate. In 2004, we repaid $3.5 million of industrial development revenue bonds and $125 million of senior notes, and refinanced $111 million of pollution control refunding revenue bonds at a lower rate. In addition, $53 million from a previous credit agreement was paid off early in 2004. Proceeds from the sale of our Water Services assets in 2003 and 2004, and proceeds received from ADESA in 2004 were used to repay the debt in 2004. Cash used for financing activities was also lower in 2005 than 2004 due to lower dividends paid following the spin-off of Automotive Services.
In 2006, our Town Center development project was financed with tax-exempt bonds issued by the Town Center District and a revolving development loan. In March 2005, the Town Center District issued $26.4 million of tax-exempt, 6% Capital Improvement Revenue Bonds, Series 2005, which are payable over 31 years (by May 1, 2036). The bond proceeds (less capitalized interest, a debt service reserve fund and cost of issuance) were used to pay for the construction of a portion of the major infrastructure improvements at Town Center. The bonds are payable from and secured by the revenue derived from assessments imposed, levied and collected by the Town Center District. The assessments represent an allocation of the costs of the improvements, including bond financing costs, to the lands within the Town Center District benefiting from the improvements. The assessments were billed to Town Center landowners beginning in November 2006. To the extent that we still own land at the time of the assessment, we recognize the cost of our portion of these assessments, based upon our ownership of benefited property. At December 31, 2006, we owned approximately 73% of the assessable land in the Town Center District.
Our Palm Coast Park development project in Florida is being financed with
tax-exempt bonds issued by the Palm Coast Park District. In May 2006, Palm Coast
Park District issued $31.8 million of tax-exempt, 5.7% Special Assessment Bonds,
Series 2006 which are payable over 31 years (by May 1, 2037). The bond proceeds
(less capitalized interest, a debt service reserve fund and cost of issuance)
are being used to fund the construction of the major infrastructure improvements
at Palm Coast Park, and to mitigate traffic and environmental impacts. The bonds
are payable from and secured by the revenue derived from assessments imposed,
levied and collected by the Palm Coast Park District. The assessments represent
an allocation of the costs of the improvements, including bond financing costs,
to the lands within the Palm Coast Park District benefiting from the
improvements. The assessments will be billed to Palm Coast Park landowners
beginning in November 2007. To the extent that we still own land at the time of
the assessment, we will recognize the cost of our portion of these assessments,
based upon our ownership of benefited property. At December 31, 2006, we owned
97% of the assessable land in the Palm Coast Park District.
47 ALLETE 2006 Form 10-K
LIQUIDITY AND CAPITAL RESOURCES (CONTINUED)
WORKING CAPITAL. Additional working capital, if and when needed, generally is provided by the sale of commercial paper. We have 0.6 million original issue shares of our common stock available for issuance through INVEST DIRECT, our direct stock purchase and dividend reinvestment plan. We have bank lines of credit aggregating $170.0 million, the majority of which expire in January 2012. In January 2006, we renewed, increased and extended a committed, syndicated, unsecured revolving credit facility with LaSalle Bank National Association, as Agent, for $150 million (Line) with a maturity date of January 11, 2011. The Line was subsequently extended for an additional year in December 2006 and currently matures on January 11, 2012. At our request and subject to certain conditions, the Line may be increased to $200 million and extended for two additional 12-month periods. We may prepay amounts outstanding under the Line in whole or in part at our discretion. Additionally, we may irrevocably terminate or reduce the size of the Line prior to maturity. The Line may be used for general corporate purposes, working capital and to provide liquidity in support of our commercial paper program. The amount and timing of future sales of our securities will depend upon market conditions and our specific needs. We may sell securities to meet capital requirements, to provide for the retirement or early redemption of issues of long-term debt, to reduce short-term debt and for other corporate purposes.
SECURITIES
In March 2001, ALLETE, ALLETE Capital II and ALLETE Capital III, jointly filed a registration statement with the SEC, pursuant to Rule 415 under the Securities Act of 1933. The registration statement, which has been declared effective by the SEC, relates to the possible issuance of a remaining aggregate amount of $387 million of securities, which may include ALLETE common stock, first mortgage bonds and other debt securities, and ALLETE Capital II and ALLETE Capital III preferred trust securities. ALLETE also previously filed a registration statement, which has been declared effective by the SEC, relating to the possible issuance of $25 million of first mortgage bonds and other debt securities. We may sell all or a portion of the remaining registered securities if warranted by market conditions and our capital requirements. Any offer and sale of the above-mentioned securities will be made only by means of a prospectus meeting the requirements of the Securities Act of 1933 and the rules and regulations thereunder.
In March 2006, we issued $50 million in principal amount of First Mortgage Bonds, 5.69% Series due March 1, 2036, in the private placement market. Proceeds were used to redeem $50 million in principal amount of First Mortgage Bonds, 7% Series due March 1, 2008.
In July 2006, the Collier County Industrial Development Authority (Authority or Issuer) issued $27.8 million of Industrial Development Variable Rate Demand Refunding Revenue Bonds Series 2006 due 2025 (Refunding Bonds) on behalf of ALLETE. The interest rate on these bonds was 3.94% at December 31, 2006. Pursuant to a financing agreement between the Authority and ALLETE dated as of July 1, 2006, ALLETE is obligated to make payments to the Issuer sufficient to pay all principal and interest on the Refunding Bonds. ALLETE's obligations under the financing agreement are supported by a direct pay letter of credit. Proceeds from the Refunding Bonds and internally generated funds were used to redeem $29.1 million of outstanding Collier County Industrial Development Refunding Revenue Bonds 6.5% Series 1996 due 2025 on August 9, 2006. As a result of an early redemption premium, we recognized a $0.6 million pre-tax charge to other expense in the third quarter of 2006.
On February 1, 2007, we issued $60 million in principal amount of First Mortgage Bonds, 5.99% Series due February 1, 2027, in the private placement market. Proceeds were used to retire $60 million in principal amount of First Mortgage Bonds, 7% Series on February 15, 2007.
FINANCIAL COVENANTS
Our lines of credit and letters of credit supporting certain long-term debt arrangements contain financial covenants. The most restrictive covenant requires ALLETE to maintain a quarterly ratio of its funded debt to total capital of less than or equal to .65 to 1.00. Failure to meet this covenant could give rise to an event of default, if not corrected after notice from the lender, in which event ALLETE may need to pursue alternative sources of funding. Some of ALLETE's debt arrangements contain "cross-default" provisions that would result in an event of default if there is a failure under other financing arrangements to meet payment terms or to observe other covenants that would result in an acceleration of payments due. As of December 31, 2006, ALLETE was in compliance with its financial covenants.
OFF-BALANCE SHEET ARRANGEMENTS
Off-balance sheet arrangements are discussed in Note 8.
CONTRACTUAL OBLIGATIONS AND COMMERCIAL COMMITMENTS
Our long-term debt obligations, including long-term debt due within one year, represent the principal amount of bonds, notes and loans which are recorded on our consolidated balance sheet, plus interest. The table below assumes the interest rate in effect at December 31, 2006, remains constant through the remaining term.
ALLETE 2006 Form 10-K 48
LIQUIDITY AND CAPITAL RESOURCES (CONTINUED)
Unconditional purchase obligations represent our Square Butte power purchase agreements, and minimum purchase commitments under coal and rail contracts.
Under our power purchase agreement with Square Butte that extends through 2026, we are obligated to pay our pro rata share of Square Butte's costs based on our entitlement to the output of Square Butte's 455 MW coal-fired generating unit near Center, North Dakota. Our 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. The following table reflects our share of future debt service based on our output entitlement of approximately 60% in 2007, 55% in 2008 and 50% thereafter. (See Note 8.)
Under an agreement with Wisconsin Public Service Corporation and WPS
Investments, LLC, we have a commitment to invest $60 million in ATC. During
2006, we invested $51.4 million in ATC. We plan to invest an additional $8.6
million in ATC in early 2007 to reach our $60 million investment commitment.
(See Notes 6 and 8.)
PAYMENTS DUE BY PERIOD
------------------------------------------------------------------------------
CONTRACTUAL OBLIGATIONS LESS THAN 1 TO 3 4 TO 5 AFTER
AS OF DECEMBER 31, 2006 TOTAL 1 YEAR YEARS YEARS 5 YEARS
-------------------------------------------------------------------------------------------------------------------------
MILLIONS
Long-Term Debt <F1> $ 639.7 $ 46.7 $ 65.1 $31.2 $496.7
Operating Lease Obligations 86.5 8.2 21.1 11.4 45.8
Unconditional Purchase Obligations 321.2 53.7 58.0 26.2 183.3
Investment in ATC 8.6 8.6 - - -
-------------------------------------------------------------------------------------------------------------------------
$1,056.0 $117.2 $144.2 $68.8 $725.8
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<F1> Includes interest and assumes variable interest rate in effect at December 31, 2006, remains constant through
remaining term.
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We expect to contribute approximately $6 million to our postretirement health and life plans in 2007. We are not required to make any contributions to our defined benefit pension plans in 2007. We are unable to predict contribution levels to our defined benefit pension plans after 2007.
EMERGING TECHNOLOGY PORTFOLIO. We have investments in emerging technologies through minority investments in venture capital funds and privately-held, start-up companies. We have committed to make additional investments in certain emerging technology holdings. The total future commitment was $2.5 million at December 31, 2006 ($3.1 million at December 31, 2005; $4.5 million at December 31, 2004) and is expected to be invested in 2007. We do not have plans to make any additional investments beyond this commitment.
CREDIT RATINGS
Our securities have been rated by Standard & Poor's and by Moody's. Rating agencies use both quantitative and qualitative measures in determining a company's credit rating. These measures include business risk, liquidity risk, competitive position, capital mix, financial condition, predictability of cash flows, management strength and future direction. Some of the quantitative measures can be analyzed through a few key financial ratios, while the qualitative ones are more subjective. The disclosure of these credit ratings is not a recommendation to buy, sell or hold our securities. Ratings are subject to revision or withdrawal at any time by the assigning rating organization. Each rating should be evaluated independently of any other rating.
CREDIT RATINGS STANDARD & POOR'S MOODY'S
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Issuer Credit Rating BBB+ Baa2
Commercial Paper A-2 P-2
Senior Secured
First Mortgage Bonds A Baa1
Pollution Control Bonds A Baa1
Unsecured Debt
Collier County Industrial Development Revenue Bonds - Fixed Rate BBB -
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PAYOUT RATIO
In 2006, we paid out 53% (259% in 2005; 77% in 2004) of our per share earnings in dividends. The payout ratio in 2005 was impacted by a $1.84 per diluted share charge resulting from our assignment of the Kendall County power purchase agreement to Constellation Energy Commodities in April 2005. (See Note 10.)
On January 26, 2007, our Board of Directors increased the dividend on ALLETE common stock by 13%, declaring a dividend of $0.41 per share payable March 1, 2007, to shareholders of record at the close of business February 15, 2007.
49 ALLETE 2006 Form 10-K
CAPITAL REQUIREMENTS
CONTINUING OPERATIONS. Capital additions for 2006 totaled $109.4 million ($58.6 million in 2005; $57.8 million in 2004). Expenditures for 2006 included $107.5 million for Regulated Utility and $1.9 million for Nonregulated Energy Operations. Internally-generated funds were the source of funding for these expenditures.
Capital additions are expected to be $179 million in 2007 and estimated to total about $700 million for 2008 through 2011. The 2007 amount includes $88 million for federal or state required environmental compliance projects at generation facilities (primarily for our AREA and Boswell Unit 3 emission reduction plans), $86 million for other regulated system component replacements and upgrades and $5 million for upgrades within Nonregulated Energy Operations. Over the next five years, we expect to use internally-generated funds and new issue debt to fund our projected capital additions. Approximately $145 million of the estimated capital additions for 2008 through 2011 relate to federal or state required environmental upgrades at our generation facilities, $450 million is for other regulated system replacements and upgrades, while $95 million is for possible generation resource additions linked to potential load growth identified in our Resource Plan filing.
Real estate development expenditures are and will be funded with a revolving development loan and tax-exempt bonds issued by community development districts. The Palm Coast Park District issued $31.8 million of tax-exempt bonds in May 2006. Bond proceeds of $26.3 million will be used for environmental and traffic mitigation, and the construction of infrastructure improvements at Palm Coast Park, with the remaining funds to be used for capitalized interest, a debt service reserve fund and costs of issuance. We anticipate that the Palm Coast Park District will need to issue additional bonds to pay for the development of retail commercial, office and industrial lots at Palm Coast Park. Company expenditures related to our real estate developments in Florida increase the carrying value of our land assets, which are classified as Investments on our consolidated balance sheet.
DISCONTINUED OPERATIONS. There were no capital additions for discontinued operations in 2006 ($4.5 million in 2005; $21.4 million in 2004).
ENVIRONMENTAL AND OTHER MATTERS
As previously mentioned in our Critical Accounting Estimates section, our businesses are subject to regulation of environmental matters by various federal, state and local authorities. Due to future stricter environmental requirements through legislation and/or rulemaking, we anticipate that potential expenditures for environmental matters will be material and will require significant capital investments. We are unable to predict the outcome of the issues discussed in Note 8. (See Item 1 - Environmental Matters.)
MARKET RISK
SECURITIES INVESTMENTS
AVAILABLE-FOR-SALE SECURITIES. At December 31, 2006, our available-for-sale securities portfolio consisted of securities in a grantor trust established to fund certain employee benefits included in Investments, and various auction rate bonds and variable rate demand notes included as Short-Term Investments. Our available-for-sale securities portfolio had a fair value of $130.1 million at December 31, 2006 ($139.5 million at December 31, 2005) and a total unrealized after-tax gain of $4.0 million at December 31, 2006 ($2.1 million at December 31, 2005).
We use the specific identification method as the basis for determining the cost of securities sold. Our policy is to review, on a quarterly basis, available-for-sale securities for other than temporary impairment by assessing such factors as the share price trends and the impact of overall market conditions. As a result of our periodic assessments, we did not record any impairments on our available-for-sale securities in 2006 or 2005.
EMERGING TECHNOLOGY PORTFOLIO. As part of our emerging technology portfolio, we have several minority investments in venture capital funds and direct investments in privately-held, start-up companies. We account for our investment in venture capital funds under the equity method and account for our direct investments in privately-held companies under the cost method because of our ownership percentage. The total carrying value of our emerging technology portfolio was $9.2 million at December 31, 2006, and December 31, 2005. Our policy is to review these investments quarterly for impairment by assessing such factors as continued commercial viability of products, cash flow and earnings. Any impairment would reduce the carrying value of the investment. Our basis in direct investments in privately-held companies included in the emerging technology portfolio was zero at December 31, 2006, and at December 31, 2005. In 2005, we recorded $5.1 million ($3.3 million after tax) of impairments related to our direct investments in certain privately-held, start-up companies whose future business prospects had significantly diminished. Developments at these companies indicated that future commercial viability was unlikely, as was new financing necessary to continue development. In 2004, we recorded $6.5 million ($4.1 million after tax) of impairments.
ALLETE 2006 Form 10-K 50
MARKET RISK (CONTINUED)
INTEREST RATE RISK
We are exposed to risks resulting from changes in interest rates as a result of our issuance of variable rate debt. We manage our interest rate risk by varying the issuance and maturity dates of our fixed rate debt, limiting the amount of variable rate debt, and continually monitoring the effects of market changes in interest rates. The table below presents the long-term debt obligations and the corresponding weighted average interest rate at December 31, 2006.
PRINCIPAL CASH FLOW BY EXPECTED MATURITY DATE
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INTEREST RATE SENSITIVE FAIR
FINANCIAL INSTRUMENTS 2007 2008 2009 2010 2011 THEREAFTER TOTAL VALUE
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DOLLARS IN MILLIONS
Long-Term Debt
Fixed Rate $21.3 $7.0 $2.0 $0.9 $0.9 $275.6 $307.7 $305.8
Average Interest Rate - % 6.7 7.1 5.4 6.5 6.5 5.7 5.8
Variable Rate $8.4 - $8.2 $3.6 - $61.6 $81.8 $81.8
Average Interest Rate - % <F1> 5.9 - 3.9 3.6 - 3.9 4.1
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<F1> Assumes rate in effect at December 31, 2006, remains constant through remaining term.
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The interest rate on variable rate long-term debt is reset on a periodic basis reflecting current market conditions. Based on the variable rate debt outstanding at December 31, 2006, and assuming no other changes to our financial structure, an increase or decrease of 100 basis points would impact the amount of pretax interest expense by $0.8 million. This amount was determined by considering the impact of a hypothetical 100 basis point change to the average variable interest rate on the variable rate debt held as of December 31, 2006.
COMMODITY PRICE RISK
Our regulated utility operations in Minnesota and Wisconsin incur costs for fuel (primarily coal), power and natural gas purchased for resale in our regulated service territories, and related transportation. Our regulated utilities' exposure to price risk for these commodities is significantly mitigated by the current ratemaking process and regulatory environment, which generally allows a fuel clause surcharge if costs are in excess of those in our last rate filing. Conversely, costs below those in our last rate filing result in a rate credit. We seek to prudently manage our customers' exposure to price risk by entering into contracts of various durations and terms for the purchase of coal and power (in Minnesota), power and natural gas (in Wisconsin), and related transportation costs.
POWER MARKETING
Our power marketing activities consist of (1) purchasing energy in the wholesale market for resale in our regulated service territories when retail energy requirements exceed generation output, and (2) selling excess available generation and purchased power.
From time to time, our utility operations may have excess generation that is temporarily not required by retail and municipal customers in our regulated service territory. We actively sell this generation to the wholesale market to optimize the value of our generating facilities. This generation is generally sold in the MISO market at market prices.
Approximately 200 MW of generation from our Taconite Harbor facility in northern Minnesota has been sold through various long-term capacity and energy contracts. Long-term, we have entered into two capacity and energy sales contracts totaling 175 MW (201 MW including a 15% reserve), which were effective May 1, 2005, and expire on April 30, 2010. Both contracts contain fixed monthly capacity charges and fixed minimum energy charges. One contract provides for an annual escalator to the energy charge based on increases in our cost of coal, subject to a small minimum annual escalation. The other contract provides that the energy charge will be the greater of a fixed minimum charge or an amount based on the variable production cost of a combined-cycle, natural gas unit. Our exposure in the event of a full or partial outage at our Taconite Harbor facility is significantly limited under both contracts. When the buyer is notified at least two months prior to an outage, there is no exposure. Outages with less than two months' notice are subject to an annual duration limitation typical of this type of contract. We also have a 50-MW capacity and energy sales contract that extends through April 2008, with formula pricing based on variable production cost of a combustion-turbine, natural gas unit.
NEW ACCOUNTING STANDARDS
New accounting standards are discussed in Note 2.
51 ALLETE 2006 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 our consolidated financial statements as of December 31, 2006 and 2005, and for each of the three years in the period ended December 31, 2006, and supplementary data, also included, which are indexed in Item 15(a).
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
Not applicable.
ITEM 9A. CONTROLS AND PROCEDURES
CONCLUSION REGARDING THE EFFECTIVENESS OF DISCLOSURE CONTROLS AND PROCEDURES
Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of our disclosure controls and procedures, as such term is defined under Rule 13a-15(e) promulgated under the Securities Exchange Act of 1934, as amended (Exchange Act). Based on this evaluation, our principal executive officer and our principal financial officer concluded that our disclosure controls and procedures were effective as of the end of the period covered by this annual report.
MANAGEMENT'S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING
Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f). Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control--Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our evaluation under the framework in Internal Control--Integrated Framework, our management concluded that our internal control over financial reporting was effective as of December 31, 2006.
Our management's assessment of the effectiveness of our internal control over financial reporting as of December 31, 2006, has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report which is included herein.
ITEM 9B. OTHER INFORMATION
None.
ALLETE 2006 Form 10-K 52
PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Unless otherwise stated, the information required for this Item is incorporated by reference herein from our Proxy Statement for the 2007 Annual Meeting of Shareholders (2007 Proxy Statement) under the following headings:
- DIRECTORS. The information regarding directors will be included in the
"Election of Directors" section;
- AUDIT COMMITTEE FINANCIAL EXPERT. The information regarding the Audit
Committee financial expert will be included in the "Report of the Audit
Committee" section;
- AUDIT COMMITTEE MEMBERS. The identity of the Audit Committee members
is included in the "Report of the Audit Committee" section;
- EXECUTIVE OFFICERS. The information regarding executive officers is
included in Part I of this Form 10-K; and
- SECTION 16(a) COMPLIANCE. The information regarding Section 16(a)
compliance will be included in the "Section 16(a) Beneficial Ownership
Reporting Compliance" section.
Our 2007 Proxy Statement will be filed with the SEC within 120 days after the end of our 2006 fiscal year.
CODE OF ETHICS. We have adopted a written Code of Ethics that applies to all of our employees, including our chief executive officer, chief financial officer and controller. A copy of our Code of Ethics is available on our Website at www.allete.com and print copies are available upon request without charge. Any amendment to the Code of Ethics or any waiver of the Code of Ethics will be disclosed on our Website at www.allete.com promptly following the date of such amendment or waiver.
CORPORATE GOVERNANCE. The following documents are available on our Website at www.allete.com and print copies are available upon request:
- Corporate Governance Guidelines;
- Audit Committee Charter;
- Executive Compensation Committee Charter; and
- Corporate Governance and Nominating Committee Charter.
Any amendment to these documents will be disclosed on our Website at www.allete.com promptly following the date of such amendment.
ITEM 11. EXECUTIVE COMPENSATION
The information required for this Item is incorporated by reference herein from the "Compensation of Executive Officers," the "Compensation Committee Report" and the "Director Compensation" sections in our 2007 Proxy Statement. The "Compensation of Executive Officers" section will include our Compensation Discussion and Analysis.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
The information required for this Item is incorporated by reference herein from the "Security Ownership of Certain Beneficial Owners," the "Security Ownership of Management" and the "Equity Compensation Plan Information" sections in our 2007 Proxy Statement.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
The information required for this Item is incorporated by reference herein from the "Corporate Governance" section in our 2007 Proxy Statement.
We have adopted a Related Person Transaction Policy which is available on our Website at www.allete.com. Print copies are available, free of charge, upon request. Any amendment to this policy will be disclosed on our Website at www.allete.com promptly following the date of such amendment.
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
The information required by this Item is incorporated by reference herein from the "Report of the Audit Committee" section in our 2007 Proxy Statement.
53 ALLETE 2006 Form 10-K
PART IV
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
(a) Certain Documents Filed as Part of this Form 10-K.
(1) Financial Statements Page
ALLETE
Report of Independent Registered Public Accounting Firm............ 59
Consolidated Balance Sheet at December 31, 2006 and 2005........... 60
For the Three Years Ended December 31, 2006
Consolidated Statement of Income.............................. 61
Consolidated Statement of Cash Flows.......................... 62
Consolidated Statement of Shareholders' Equity................ 63
Notes to Consolidated Financial Statements......................... 64-95
(2) Financial Statement Schedules
Schedule II - ALLETE Valuation and Qualifying Accounts and Reserves... 96
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All other schedules have been omitted either because the information is not required to be reported by ALLETE or because the information is included in the consolidated financial statements or the notes.
(3) Exhibits including those incorporated by reference.
EXHIBIT NUMBER
*3(a)1 - Articles of Incorporation, amended and restated as of May 8, 2001 (filed as Exhibit 3(b) to the March 31, 2001, Form 10-Q, File No. 1-3548).
*3(a)2 - Amendment to Articles of Incorporation, effective 12:00 p.m.
Eastern Time on September 20, 2004 (filed as Exhibit 3 to the
September 21, 2004, Form 8-K, File No. 1-3548).
*3(a)3 - Amendment to Certificate of Assumed Name, filed with the Minnesota Secretary of State on May 8, 2001 (filed as Exhibit 3(a) to the March 31, 2001, Form 10-Q, File No. 1-3548).
*3(b) - Bylaws, as amended effective August 24, 2004 (filed as Exhibit 3 to the August 25, 2004, Form 8-K, File No. 1-3548).
*4(a)1 - Mortgage and Deed of Trust, dated as of September 1, 1945, between Minnesota Power & Light Company (now ALLETE) and The Bank of New York (formerly Irving Trust Company) and Douglas J. MacInnes (successor to Richard H. West), Trustees (filed as Exhibit 7(c), File No. 2-5865).
*4(a)2 - Supplemental Indentures to ALLETE'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
Twenty-first October 1, 2000 333-54330 4(c)3
Twenty-second July 1, 2003 1-3548 (June 30, 2003 Form 10-Q) 4
Twenty-third August 1, 2004 1-3548 (Sept. 30, 2004 Form 10-Q) 4(a)
Twenty-fourth March 1, 2005 1-3548 (March 31, 2005 Form 10-Q) 4
Twenty-fifth December 1, 2005 1-3548 (March 31, 2006 Form 10-Q) 4
4(a)3 - Twenty-Sixth Supplemental Indenture, dated as of October 1,
2006, between ALLETE and The Bank of New York and Douglas J.
MacInnes, as Trustees.
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ALLETE 2006 Form 10-K 54
EXHIBIT NUMBER
*4(b)1 - Indenture of Trust, dated as of August 1, 2004, between the City of Cohasset, Minnesota and U.S. Bank National Association, as Trustee relating to $111 Million Collateralized Pollution Control Refunding Revenue Bonds (filed as Exhibit 4(b) to the September 30, 2004, Form 10-Q, File No. 1-3548).
*4(b)2 - Loan Agreement, dated as of August 1, 2004, between the City of Cohasset, Minnesota and ALLETE relating to $111 Million Collateralized Pollution Control Refunding Revenue Bonds (filed as Exhibit 4(c) to the September 30, 2004, Form 10-Q, File No. 1-3548).
*4(c)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(c)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(d) - Amended and Restated Rights Agreement, dated as of July 12, 2006, between ALLETE and the Corporate Secretary of ALLETE, as Rights Agent (filed as Exhibit 4 to the July 14, 2006, Form 8-K, File No. 1-3548).
*10(a) - Power Purchase and Sale Agreement, dated as of May 29, 1998, between Minnesota Power, Inc. (now ALLETE) and Square Butte Electric Cooperative (filed as Exhibit 10 to the June 30, 1998, Form 10-Q, File No. 1-3548).
*10(b) - Amended and Restated Withdrawal Agreement (without Exhibits and Schedules), dated January 30, 2004, by and between Great River Energy and Minnesota Power (now ALLETE) (filed as Exhibit 10(p) to the 2003 Form 10-K, File No. 1-3548).
*10(c) - Master Agreement (without Appendices and Exhibits), dated December 28, 2004, by and between Rainy River Energy Corporation and Constellation Energy Commodities Group, Inc. (filed as Exhibit 10(c) to the 2004 Form 10-K, File No. 1-3548).
*10(d)1 - Fourth Amended and Restated Committed Facility Letter (without
Exhibits), dated January 11, 2006, by and among ALLETE and
LaSalle Bank National Association, as Agent (filed as Exhibit
10 to the January 17, 2006, Form 8-K, File No. 1-3548).
*10(d)2 - First Amendment to Fourth Amended and Restated Committed
Facility Letter dated June 19, 2006, by and among ALLETE and
LaSalle Bank National Association, as Agent (filed as Exhibit
10(a) to the June 30, 2006, Form 10-Q, File No. 1-3548).
10(d)3 - Second Amendment to Fourth Amended and Restated Committed
Facility Letter dated December 14, 2006, by and among ALLETE
and LaSalle Bank National Association, as Agent.
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*10(e)1 - Financing Agreement between Collier County Industrial Development Authority and ALLETE dated as of July 1, 2006 (filed as Exhibit 10(b)1 to the June 30, 2006, Form 10-Q, File No. 1-3548).
*10(e)2 - Letter of Credit Agreement, dated as of July 5, 2006, among ALLETE, the Participating Banks and Wells Fargo Bank, National Association, as Administrative Agent and Issuing Bank (filed as Exhibit 10(b)2 to the June 30, 2006, Form 10-Q, File No. 1-3548).
*10(f) - Master Separation Agreement, dated June 4, 2004, between
ALLETE, Inc. and ADESA, Inc. (filed as Exhibit 10.1 to ADESA,
Inc.'s June 30, 2004, Form 10-Q, File No. 1-32198).
*10(g) - Agreement (without Exhibit) dated December 16, 2005, among
ALLETE, Wisconsin Public Service Corporation and WPS
Investments, LLC (filed as Exhibit 10 to the December 21, 2005
Form 8-K, File No. 1-3548).
+*10(h)1 - Minnesota Power (now ALLETE) Executive Annual Incentive Plan,
as amended, effective January 1, 1999 with amendments through
January 2003 (filed as Exhibit 10 to the September 30, 2003,
Form 10-Q, File No. 1-3548).
+*10(h)2 - November 2003 Amendment to the ALLETE Executive Annual
Incentive Plan (filed as Exhibit 10(t)2 to the 2003 Form 10-K,
File No. 1-3548).
+*10(h)3 - July 2004 Amendment to the ALLETE Executive Annual Incentive
Plan (filed as Exhibit 10(a) to the June 30, 2004, Form 10-Q,
File No. 1-3548).
55 ALLETE 2006 Form 10-K
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EXHIBIT NUMBER
+10(h)4 - January 2007 Amendment to the ALLETE Executive Annual Incentive
Plan.
+*10(h)5 - Form of ALLETE Executive Annual Incentive Plan 2006 Award -
President of ALLETE Properties (filed as Exhibit 10(b) to the
January 30, 2006, Form 8-K, File No. 1-3548).
+*10(h)6 - Form of ALLETE Executive Annual Incentive Plan 2006 Award
(filed as Exhibit 10 to the February 17, 2006, Form 8-K,
File No. 1-3548).
+10(h)7 - Form of ALLETE Executive Annual Incentive Plan Awards Effective
2007.
+*10(i)1 - ALLETE and Affiliated Companies Supplemental Executive
Retirement Plan, as amended and restated, effective January 1,
2004 (filed as Exhibit 10(u) to the 2003 Form 10-K, File No.
1-3548).
+*10(i)2 - January 2005 Amendment to the ALLETE and Affiliated Companies
Supplemental Executive Retirement Plan (filed as Exhibit 10(b)
to the March 31, 2005, Form 10-Q, File No. 1-3548).
+*10(i)3 - August 2006 Amendments to the ALLETE and Affiliated Companies
Supplemental Executive Retirement Plan (filed as Exhibit 10(a)
to the September 30, 2006, Form 10-Q, File No. 1-3548).
+10(i)4 - December 2006 Amendments to the ALLETE and Affiliated Companies
Supplemental Executive Retirement Plan.
+*10(j)1 - Minnesota Power and Affiliated Companies 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(j)2 - Amendments through December 2003 to the Minnesota Power and
Affiliated Companies Executive Investment Plan I (filed as
Exhibit 10(v)2 to the 2003 Form 10-K, File No. 1-3548).
+*10(j)3 - July 2004 Amendment to the Minnesota Power and Affiliated
Companies Executive Investment Plan I (filed as Exhibit 10(b)
to the June 30, 2004, Form 10-Q, File No. 1-3548).
+*10(j)4 - August 2006 Amendment to the Minnesota Power and Affiliated
Companies Executive Investment Plan I (filed as Exhibit 10(b)
to the September 30, 2006, Form 10-Q, File No. 1-3548).
+*10(k)1 - Minnesota Power and Affiliated Companies 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(k)2 - Amendments through December 2003 to the Minnesota Power and
Affiliated Companies Executive Investment Plan II (filed as
Exhibit 10(w)2 to the 2003 Form 10-K, File No. 1-3548).
+*10(k)3 - July 2004 Amendment to the Minnesota Power and Affiliated
Companies Executive Investment Plan II (filed as Exhibit 10(c)
to the June 30, 2004, Form 10-Q, File No. 1-3548).
+*10(k)4 - August 2006 Amendment to the Minnesota Power and Affiliated
Companies Executive Investment Plan II (filed as Exhibit 10(c)
to the September 30, 2006, Form 10-Q, File No. 1-3548).
+*10(l) - 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(m)1 - ALLETE Executive Long-Term Incentive Compensation Plan as
amended and restated effective January 1, 2006 (filed as
Exhibit 10 to the May 16, 2005, Form 8-K, File No. 1-3548).
+*10(m)2 - Form of ALLETE Executive Long-Term Incentive Compensation
Plan 2006 Nonqualified Stock Option Grant (filed as Exhibit
10(a)1 to the January 30, 2006, Form 8-K, File No. 1-3548).
+*10(m)3 - Form of ALLETE Executive Long-Term Incentive Compensation Plan
2006 Performance Share Grant (filed as Exhibit 10(a)2 to the
January 30, 2006, Form 8-K, File No. 1-3548).
+*10(m)4 - Form of ALLETE Executive Long-Term Incentive Compensation Plan
2006 Long-Term Cash Incentive Award - President of ALLETE
Properties (filed as Exhibit 10(a)3 to the January 30, 2006,
Form 8-K, File No. 1-3548).
+*10(m)5 - Form of ALLETE Executive Long-Term Incentive Compensation Plan
2006 Stock Grant - President of ALLETE Properties (filed as
Exhibit 10(a)4 to the January 30, 2006, Form 8-K, File No.
1-3548).
+10(m)6 - Form of ALLETE Executive Long-Term Incentive Compensation Plan
Nonqualified Stock Option Grant Effective 2007.
+10(m)7 - Form of ALLETE Executive Long-Term Incentive Compensation Plan
Performance Share Grant Effective 2007.
+10(m)8 - Form of ALLETE Executive Long-Term Incentive Compensation Plan
Long-Term Cash Incentive Award Effective 2007.
+10(m)9 - Form of ALLETE Executive Long-Term Incentive Compensation Plan
Stock Grant Effective 2007.
+*10(n)1 - Minnesota Power (now ALLETE) Director Stock Plan, effective
January 1, 1995 (filed as Exhibit 10 to the March 31, 1995 Form
10-Q, File No. 1-3548).
+*10(n)2 - Amendments through December 2003 to the Minnesota Power (now
ALLETE) Director Stock Plan (filed as Exhibit 10(z)2 to the
2003 Form 10-K, File No. 1-3548).
|
ALLETE 2006 Form 10-K 56
EXHIBIT NUMBER
+*10(n)3 - July 2004 Amendment to the ALLETE Director Stock Plan (filed
as Exhibit 10(e) to the June 30, 2004, Form 10-Q, File No.
1-3548).
+10(n)4 - January 2007 Amendment to the ALLETE Director Stock Plan.
+*10(n)5 - ALLETE Director Compensation Summary Effective May 1, 2005
(filed as Exhibit 10 to the June 30, 2005, Form 10-Q, File No.
1-3548).
+10(n)6 - ALLETE Non-Management Director Compensation Summary Effective
February 15, 2007.
+*10(o)1 - Minnesota Power (now ALLETE) Director Compensation Deferral
Plan Amended and Restated, effective January 1, 1990 (filed as
Exhibit 10(ac) to the 2002 Form 10-K, File No. 1-3548).
+*10(o)2 - October 2003 Amendment to the Minnesota Power (now ALLETE)
Director Compensation Deferral Plan (filed as Exhibit 10(aa)2
to the 2003 Form 10-K, File No. 1-3548).
+*10(o)3 - January 2005 Amendment to the ALLETE Director Compensation
Deferral Plan (filed as Exhibit 10(c) to the March 31, 2005,
Form 10-Q, File No. 1-3548).
+*10(o)4 - August 2006 Amendment to the ALLETE Director Compensation
Deferral Plan (filed as Exhibit 10(d) to the September 30,
2006, Form 10-Q, File No. 1-3548).
+*10(p) - ALLETE Director Compensation Trust Agreement, effective
October 11, 2004 (filed as Exhibit 10(a) to the September 30,
2004, Form 10-Q, File No. 1-3548).
12 - Computation of Ratios of Earnings to Fixed Charges.
21 - Subsidiaries of the Registrant.
23(a) - Consent of Independent Registered Public Accounting Firm.
23(b) - Consent of General Counsel.
31(a) - Rule 13a-14(a)/15d-14(a) Certification by the Chief Executive
Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of
2002.
31(b) - Rule 13a-14(a)/15d-14(a) Certification by the Chief Financial
Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of
2002.
32 - Section 1350 Certification of Annual Report by the Chief
Executive Officer and Chief Financial Officer Pursuant to
Section 906 of the Sarbanes-Oxley Act of 2002.
99 - ALLETE News Release dated February 16, 2007, announcing 2006
|
earnings. (THIS EXHIBIT HAS BEEN FURNISHED AND SHALL NOT BE DEEMED "FILED" FOR PURPOSES OF SECTION 18 OF THE SECURITIES EXCHANGE ACT OF 1934, NOR SHALL IT BE DEEMED INCORPORATED BY REFERENCE IN ANY FILING UNDER THE SECURITIES ACT OF 1933, EXCEPT AS SHALL BE EXPRESSLY SET FORTH BY SPECIFIC REFERENCE IN SUCH FILING.)
We are a party to another long-term debt instrument, $38,995,000 of City of
Cohasset, Minnesota, Variable Rate Demand Revenue Refunding Bonds (ALLETE,
formerly Minnesota Power & Light Company, Project) Series 1997A, Series 1997B,
Series 1997C and Series 1997D that, pursuant to Regulation S-K, Item
601(b)(4)(iii), is not filed as an exhibit since the total amount of debt
authorized under this omitted instrument does not exceed 10% of our total
consolidated assets. We will furnish copies of this instrument to the SEC upon
its request.
57 ALLETE 2006 Form 10-K
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.
ALLETE, INC.
Dated: February 16, 2007 By Donald J. Shippar
----------------------------------------
Donald J. Shippar
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
------------------------------------------------------------------------------------------------------------------------------------
Donald J. Shippar Chairman, President, Chief Executive Officer February 16, 2007
---------------------------------------- and Director
Donald J. Shippar
Mark A. Schober Senior Vice President and Chief Financial Officer February 16, 2007
----------------------------------------
Mark A. Schober
Steven Q. DeVinck Controller February 16, 2007
----------------------------------------
Steven Q. DeVinck
Kathleen A. Brekken Director February 16, 2007
----------------------------------------
Kathleen A. Brekken
Heidi J. Eddins Director February 16, 2007
----------------------------------------
Heidi J. Eddins
James J. Hoolihan Director February 16, 2007
----------------------------------------
James J. Hoolihan
Peter J. Johnson Director February 16, 2007
----------------------------------------
Peter J. Johnson
Madeleine W. Ludlow Director February 16, 2007
----------------------------------------
Madeleine W. Ludlow
George L. Mayer Director February 16, 2007
----------------------------------------
George L. Mayer
Roger D. Peirce Director February 16, 2007
----------------------------------------
Roger D. Peirce
Jack I. Rajala Director February 16, 2007
----------------------------------------
Jack I. Rajala
Nick Smith Director February 16, 2007
----------------------------------------
Nick Smith
Bruce W. Stender Director February 16, 2007
----------------------------------------
Bruce W. Stender
|
ALLETE 2006 Form 10-K 58
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Shareholders of ALLETE, Inc.
We have completed integrated audits of ALLETE, Inc.'s consolidated financial statements and of its internal control over financial reporting as of December 31, 2006, in accordance with the standards of the Public Company Accounting Oversight Board (United States). Our opinions, based on our audits, are presented below.
In our opinion, the consolidated financial statements listed in the index appearing under Item 15(a)(1) present fairly, in all material respects, the financial position of ALLETE, Inc. and its subsidiaries (the Company) at December 31, 2006 and 2005, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2006 in conformity with accounting principles generally accepted in the United States of America. In addition, in our opinion, the financial statement schedule listed in the accompanying index under Item 15(a)(2) presents fairly, in all material respects, the information set forth therein when read in conjunction with the related consolidated financial statements. These financial statements and financial statement schedule are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements and financial statement schedule based on our audits. We conducted our audits of these statements in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit of financial statements 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 our opinion.
As discussed in Note 15 to the consolidated financial statements, in 2004 the Company changed its method of accounting for investments in limited liability companies in accordance with EITF 03-16, "Accounting for Investments in Limited Liability Companies." As discussed in Note 16 to the consolidated financial statements, in 2006 the Company adopted SFAS 158, "Employer's Accounting for Defined Benefit Pension and Other Postretirement Plans." As discussed in Note 17 to the consolidated financial statements, in 2006 the Company changed the manner in which it accounts for share-based compensation.
Also, in our opinion, management's assessment, included in Management's Report on Internal Control Over Financial Reporting appearing under Item 9A, that the Company maintained effective internal control over financial reporting as of December 31, 2006 based on criteria established in Internal Control--Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), is fairly stated, in all material respects, based on those criteria. Furthermore, in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2006, based on criteria established in Internal Control--Integrated Framework issued by the COSO. The Company's management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting. Our responsibility is to express opinions on management's assessment and on the effectiveness of the Company's internal control over financial reporting based on our audit. We conducted our audit of internal control over financial reporting in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. An audit of internal control over financial reporting includes obtaining an understanding of internal control over financial reporting, evaluating management's assessment, testing and evaluating the design and operating effectiveness of internal control, and performing such other procedures as we consider necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinions.
A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
PricewaterhouseCoopers LLP
PricewaterhouseCoopers LLP
Minneapolis, Minnesota
February 12, 2007, except as to Note 7 for which the date is February 15, 2007
59 ALLETE 2006 Form 10-K
CONSOLIDATED FINANCIAL STATEMENTS
ALLETE CONSOLIDATED BALANCE SHEET
DECEMBER 31 2006 2005
-----------------------------------------------------------------------------------------------------------------------------
MILLIONS
ASSETS
Current Assets
Cash and Cash Equivalents $ 44.8 $ 89.6
Short-Term Investments 104.5 116.9
Accounts Receivable (Less Allowance of $1.1 and $1.0) 70.9 79.1
Inventories 43.4 33.1
Prepayments and Other 23.8 23.8
Deferred Income Taxes 0.3 31.0
Discontinued Operations - 0.4
-----------------------------------------------------------------------------------------------------------------------------
Total Current Assets 287.7 373.9
Property, Plant and Equipment - Net 921.6 860.4
Investments 189.1 117.7
Other Assets 135.0 44.6
Discontinued Operations - 2.2
-----------------------------------------------------------------------------------------------------------------------------
TOTAL ASSETS $1,533.4 $1,398.8
-----------------------------------------------------------------------------------------------------------------------------
LIABILITIES AND SHAREHOLDERS' EQUITY
LIABILITIES
Current Liabilities
Accounts Payable $ 53.5 $ 44.7
Accrued Taxes 23.3 19.1
Accrued Interest 8.6 7.4
Long-Term Debt Due Within One Year 29.7 2.7
Deferred Profit on Sales of Real Estate 4.1 8.6
Other 24.3 24.2
Discontinued Operations - 13.0
-----------------------------------------------------------------------------------------------------------------------------
Total Current Liabilities 143.5 119.7
Long-Term Debt 359.8 387.8
Deferred Income Taxes 130.8 138.4
Other Liabilities 226.1 144.1
Minority Interest 7.4 6.0
-----------------------------------------------------------------------------------------------------------------------------
Total Liabilities 867.6 796.0
-----------------------------------------------------------------------------------------------------------------------------
COMMITMENTS AND CONTINGENCIES
-----------------------------------------------------------------------------------------------------------------------------
SHAREHOLDERS' EQUITY
Common Stock Without Par Value, 43.3 Shares Authorized
30.4 and 30.1 Shares Outstanding 438.7 421.1
Unearned ESOP Shares (71.9) (77.6)
Accumulated Other Comprehensive Loss (8.8) (12.8)
Retained Earnings 307.8 272.1
-----------------------------------------------------------------------------------------------------------------------------
Total Shareholders' Equity 665.8 602.8
-----------------------------------------------------------------------------------------------------------------------------
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $1,533.4 $1,398.8
-----------------------------------------------------------------------------------------------------------------------------
The accompanying notes are an integral part of these statements.
|
ALLETE 2006 Form 10-K 60
ALLETE CONSOLIDATED STATEMENT OF INCOME
FOR THE YEAR ENDED DECEMBER 31 2006 2005 2004
-----------------------------------------------------------------------------------------------------------------------------
MILLIONS EXCEPT PER SHARE AMOUNTS
OPERATING REVENUE $767.1 $737.4 $704.1
-----------------------------------------------------------------------------------------------------------------------------
OPERATING EXPENSES
Fuel and Purchased Power 281.7 273.1 286.2
Operating and Maintenance 296.0 293.5 270.1
Kendall County Charge - 77.9 -
Depreciation 48.7 47.8 46.9
-----------------------------------------------------------------------------------------------------------------------------
Total Operating Expenses 626.4 692.3 603.2
-----------------------------------------------------------------------------------------------------------------------------
OPERATING INCOME FROM CONTINUING OPERATIONS 140.7 45.1 100.9
-----------------------------------------------------------------------------------------------------------------------------
OTHER INCOME (EXPENSE)
Interest Expense (27.4) (26.4) (31.7)
Other 14.9 1.1 (12.2)
-----------------------------------------------------------------------------------------------------------------------------
Total Other Expense (12.5) (25.3) (43.9)
-----------------------------------------------------------------------------------------------------------------------------
INCOME FROM CONTINUING OPERATIONS
BEFORE MINORITY INTEREST AND INCOME TAXES 128.2 19.8 57.0
MINORITY INTEREST 4.6 2.7 2.1
-----------------------------------------------------------------------------------------------------------------------------
INCOME FROM CONTINUING OPERATIONS
BEFORE INCOME TAXES 123.6 17.1 54.9
INCOME TAX EXPENSE (BENEFIT) 46.3 (0.5) 16.4
-----------------------------------------------------------------------------------------------------------------------------
INCOME FROM CONTINUING OPERATIONS
BEFORE CHANGE IN ACCOUNTING PRINCIPLE 77.3 17.6 38.5
INCOME (LOSS) FROM DISCONTINUED OPERATIONS - NET OF TAX (0.9) (4.3) 73.7
CHANGE IN ACCOUNTING PRINCIPLE - NET OF TAX - - (7.8)
-----------------------------------------------------------------------------------------------------------------------------
NET INCOME $ 76.4 $ 13.3 $104.4
-----------------------------------------------------------------------------------------------------------------------------
AVERAGE SHARES OF COMMON STOCK
Basic 27.8 27.3 28.3
Diluted 27.9 27.4 28.4
-----------------------------------------------------------------------------------------------------------------------------
BASIC EARNINGS (LOSS) PER SHARE OF COMMON STOCK
Continuing Operations $2.78 $0.65 $1.37
Discontinued Operations (0.03) (0.16) 2.60
Change in Accounting Principle - - (0.28)
-----------------------------------------------------------------------------------------------------------------------------
$2.75 $0.49 $3.69
-----------------------------------------------------------------------------------------------------------------------------
DILUTED EARNINGS (LOSS) PER SHARE OF COMMON STOCK
Continuing Operations $2.77 $0.64 $1.35
Discontinued Operations (0.03) (0.16) 2.59
Change in Accounting Principle - - (0.27)
-----------------------------------------------------------------------------------------------------------------------------
$2.74 $0.48 $3.67
-----------------------------------------------------------------------------------------------------------------------------
DIVIDENDS PER SHARE OF COMMON STOCK $1.4500 $1.2450 $2.8425
-----------------------------------------------------------------------------------------------------------------------------
The accompanying notes are an integral part of these statements.
|
61 ALLETE 2006 Form 10-K
ALLETE CONSOLIDATED STATEMENT OF CASH FLOWS
FOR THE YEAR ENDED DECEMBER 31 2006 2005 2004
-----------------------------------------------------------------------------------------------------------------------------
MILLIONS
OPERATING ACTIVITIES
Net Income $ 76.4 $ 13.3 $104.4
(Income) Loss from Discontinued Operations 0.9 4.3 (73.7)
Income from Equity Investments (1.8) - -
Change in Accounting Principle - - 7.8
Loss on Impairment of Investments - 5.1 6.5
Depreciation 48.7 47.8 46.9
Deferred Income Taxes 27.8 (34.2) (1.1)
Minority Interest 4.6 2.7 2.1
Stock Compensation Expense 1.8 1.5 1.0
Bad Debt Expense 0.7 1.1 0.9
Changes in Operating Assets and Liabilities
Accounts Receivable 7.5 (1.4) (22.9)
Inventories (10.3) (1.3) (0.3)
Prepayments and Other (2.3) (2.5) (3.6)
Accounts Payable 5.1 4.9 0.2
Other Current Liabilities 0.2 5.8 (4.8)
Other Assets (4.3) 8.2 6.2
Other Liabilities 1.0 (4.1) (3.4)
Net Operating Activities from Discontinued Operations (13.5) 2.3 108.8
-----------------------------------------------------------------------------------------------------------------------------
Cash from Operating Activities 142.5 53.5 175.0
-----------------------------------------------------------------------------------------------------------------------------
INVESTING ACTIVITIES
Proceeds from Sale of Available-For-Sale Securities 608.8 376.0 1.9
Payments for Purchase of Available-For-Sale Securities (596.4) (343.7) (149.5)
Changes to Investments (52.0) (1.1) 12.4
Expenditures for Property, Plant and Equipment (102.3) (58.6) (57.8)
Other (15.0) 0.6 2.0
Net Investing Activities from Discontinued Operations 2.2 30.7 64.5
-----------------------------------------------------------------------------------------------------------------------------
Cash from (for) Investing Activities (154.7) 3.9 (126.5)
-----------------------------------------------------------------------------------------------------------------------------
FINANCING ACTIVITIES
Issuance of Common Stock 15.8 21.0 49.0
Issuance of Long-Term Debt 77.8 35.0 120.8
Reacquired Common Stock - - (5.8)
Changes in Notes Payable - Net - - (53.0)
Reductions of Long-Term Debt (78.9) (35.7) (241.1)
Dividends on Common Stock and Distributions to Minority Shareholders (43.9) (36.7) (79.7)
Net Increase (Decrease) in Book Overdrafts (3.4) 3.4 -
Net Financing Activities for Discontinued Operations - (0.9) (18.9)
-----------------------------------------------------------------------------------------------------------------------------
Cash for Financing Activities (32.6) (13.9) (228.7)
-----------------------------------------------------------------------------------------------------------------------------
CHANGE IN CASH AND CASH EQUIVALENTS (44.8) 43.5 (180.2)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD 89.6 46.1 226.3
-----------------------------------------------------------------------------------------------------------------------------
CASH AND CASH EQUIVALENTS AT END OF PERIOD <F1> $ 44.8 $ 89.6 $ 46.1
-----------------------------------------------------------------------------------------------------------------------------
<F1> Included $2.4 million of cash from Discontinued Operations at December 31, 2004.
The accompanying notes are an integral part of these statements.
|
ALLETE 2006 Form 10-K 62
ALLETE CONSOLIDATED STATEMENT OF SHAREHOLDERS' EQUITY
ACCUMULATED
TOTAL OTHER UNEARNED
SHAREHOLDERS' RETAINED COMPREHENSIVE ESOP COMMON
EQUITY EARNINGS INCOME (LOSS) SHARES STOCK
-----------------------------------------------------------------------------------------------------------------------------
MILLIONS
Balance at December 31, 2003 $1,460.2 $631.9 $14.5 $(45.4) $859.2
Comprehensive Income
Net Income 104.4 104.4
Other Comprehensive Income - Net of Tax
Unrealized Gains on Securities - Net 0.7 0.7
Foreign Currency Translation Adjustments (23.5) (23.5)
Additional Pension Liability (3.1) (3.1)
--------
Total Comprehensive Income 78.5
Common Stock Issued - Net 43.2 43.2
ADESA IPO 70.1 70.1
Spin-Off of ADESA (963.6) (363.4) (600.2)
Receipt of ADESA Stock by ESOP 54.3 26.5 27.8
Purchase of ALLETE Shares by ESOP (35.6) (35.6)
Dividends Declared (79.7) (79.7)
ESOP Shares Earned 3.1 3.1
-----------------------------------------------------------------------------------------------------------------------------
Balance at December 31, 2004 630.5 293.2 (11.4) (51.4) 400.1
Comprehensive Income
Net Income 13.3 13.3
Other Comprehensive Income - Net of Tax
Unrealized Gains on Securities - Net 0.6 0.6
Additional Pension Liability (2.0) (2.0)
--------
Total Comprehensive Income 11.9
Common Stock Issued - Net 21.0 21.0
Dividends Declared (34.4) (34.4)
Purchase of ALLETE Shares by ESOP (30.3) (30.3)
ESOP Shares Earned 4.1 4.1
-----------------------------------------------------------------------------------------------------------------------------
Balance at December 31, 2005 602.8 272.1 (12.8) (77.6) 421.1
Comprehensive Income
Net Income 76.4 76.4
Other Comprehensive Income - Net of Tax
Unrealized Gains on Securities - Net 1.9 1.9
Additional Pension Liability 6.4 6.4
--------
Total Comprehensive Income 84.7
Adjustment to initially apply SFAS 158 -
Net of Tax (4.3) (4.3)
Common Stock Issued - Net 17.6 17.6
Dividends Declared (40.7) (40.7)
ESOP Shares Earned 5.7 5.7
-----------------------------------------------------------------------------------------------------------------------------
Balance at December 31, 2006 $ 665.8 $307.8 $(8.8) $(71.9) $438.7
-----------------------------------------------------------------------------------------------------------------------------
The accompanying notes are an integral part of these statements.
|
63 ALLETE 2006 Form 10-K
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NOTE 1. BUSINESS SEGMENTS
Presented below are the operating results and other financial information related to our reporting segments. For a description of our reporting segments, see Note 2.
Financial results by segment for the periods presented were impacted by the integration of our Taconite Harbor facility into the Regulated Utility segment, effective January 1, 2006. The redirection of Taconite Harbor from our Nonregulated Energy Operations segment to our Regulated Utility segment was in accordance with the Company's Resource Plan, as approved by the MPUC. Under the terms of our Resource Plan, we have operated the Taconite Harbor facility as a rate-based asset within the Minnesota retail jurisdiction since January 1, 2006. Prior to January 1, 2006, we operated our Taconite Harbor facility as nonregulated generation (non-rate base generation sold at market-based rates primarily to the wholesale market). Historical financial results of Taconite Harbor for periods prior to the 2006 redirection are included in our Nonregulated Energy Operations segment.
Effective the third quarter of 2006, financial results for our equity investment in ATC have been reported as a separate segment. ATC is a Wisconsin-based public utility that owns and maintains electric transmission assets in parts of Wisconsin, Michigan, Minnesota and Illinois. ATC provides transmission service under rates regulated by the FERC that are set in accordance with the FERC's policy of establishing the independent operation and ownership of, and investment in, transmission facilities. (See Note 6.)
ENERGY
-------------------------------------
NONREGULATED
REGULATED ENERGY INVESTMENT REAL
CONSOLIDATED UTILITY OPERATIONS IN ATC ESTATE OTHER
-----------------------------------------------------------------------------------------------------------------------
MILLIONS
2006
Operating Revenue $767.1 $639.2 $65.0 - $62.6 $0.3
Fuel and Purchased Power 281.7 281.7 - - - -
Operating and Maintenance 296.0 217.9 57.1 - 18.2 2.8
Depreciation Expense 48.7 44.2 4.3 - 0.1 0.1
-----------------------------------------------------------------------------------------------------------------------
Operating Income (Loss) from
Continuing Operations 140.7 95.4 3.6 - 44.3 (2.6)
Interest Expense (27.4) (20.2) (3.3) - - (3.9)
Other Income 14.9 0.9 2.2 $3.0 - 8.8
-----------------------------------------------------------------------------------------------------------------------
Income from Continuing Operations
Before Minority Interest
and Income Taxes 128.2 76.1 2.5 3.0 44.3 2.3
Minority Interest 4.6 - - - 4.6 -
-----------------------------------------------------------------------------------------------------------------------
Income from Continuing Operations
Before Income Taxes 123.6 76.1 2.5 3.0 39.7 2.3
Income Tax Expense (Benefit) 46.3 29.3 (1.2) 1.1 16.9 0.2
-----------------------------------------------------------------------------------------------------------------------
Income from Continuing Operations 77.3 $ 46.8 $ 3.7 $1.9 $22.8 $2.1
----------------------------------------------------------------
Loss from Discontinued Operations -
Net of Tax (0.9)
----------------------------------------------------
Net Income $ 76.4
----------------------------------------------------
Total Assets $1,533.4 $1,143.3 $81.3 $53.7 $89.8 $165.3
Capital Additions $109.4 $107.5 $1.9 - - -
-----------------------------------------------------------------------------------------------------------------------
|
ALLETE 2006 Form 10-K 64
NOTE 1. BUSINESS SEGMENTS (CONTINUED)
ENERGY
-------------------------------------
NONREGULATED
REGULATED ENERGY INVESTMENT REAL
CONSOLIDATED UTILITY OPERATIONS IN ATC ESTATE OTHER
-----------------------------------------------------------------------------------------------------------------------
MILLIONS
2005
Operating Revenue $737.4 $575.6 $113.9 - $47.5 $ 0.4
Fuel and Purchased Power 273.1 243.7 29.4 - - -
Operating and Maintenance 293.5 202.9 71.2 - 15.5 3.9
Kendall County Charge 77.9 - 77.9 - - -
Depreciation Expense 47.8 39.4 8.1 - 0.1 0.2
-----------------------------------------------------------------------------------------------------------------------
Operating Income (Loss) from
Continuing Operations 45.1 89.6 (72.7) - 31.9 (3.7)
Interest Expense (26.4) (17.4) (6.6) - (0.1) (2.3)
Other Income (Expense) 1.1 0.7 1.7 - - (1.3)
-----------------------------------------------------------------------------------------------------------------------
Income (Loss) from
Continuing Operations Before
Minority Interest and Income Taxes 19.8 72.9 (77.6) - 31.8 (7.3)
Minority Interest 2.7 - - - 2.7 -
-----------------------------------------------------------------------------------------------------------------------
Income (Loss) from
Continuing Operations
Before Income Taxes 17.1 72.9 (77.6) - 29.1 (7.3)
Income Tax Expense (Benefit) (0.5) 27.2 (29.1) - 11.6 (10.2)
-----------------------------------------------------------------------------------------------------------------------
Income (Loss) from Continuing Operations 17.6 $ 45.7 $(48.5) - $17.5 $ 2.9
----------------------------------------------------------------
Loss from Discontinued Operations -
Net of Tax (4.3)
----------------------------------------------------
Net Income $ 13.3
----------------------------------------------------
Total Assets $1,398.8 <F1> $909.5 $185.2 - $73.7 $227.8
Capital Additions $63.1 <F1> $46.5 $12.1 - - -
-----------------------------------------------------------------------------------------------------------------------
2004
Operating Revenue $704.1 $555.0 $106.8 - $41.9 $ 0.4
Fuel and Purchased Power 286.2 245.1 41.1 - - -
Operating and Maintenance 270.1 191.7 60.3 - 15.0 3.1
Depreciation Expense 46.9 39.5 7.2 - 0.1 0.1
-----------------------------------------------------------------------------------------------------------------------
Operating Income (Loss)
from Continuing Operations 100.9 78.7 (1.8) - 26.8 (2.8)
Interest Expense (31.7) (18.5) (4.9) - (0.3) (8.0)
Other Income (Expense) (12.2) 0.1 0.6 - - (12.9)
-----------------------------------------------------------------------------------------------------------------------
Income (Loss) from
Continuing Operations Before
Minority Interest and Income Taxes 57.0 60.3 (6.1) - 26.5 (23.7)
Minority Interest 2.1 - - - 2.1 -
-----------------------------------------------------------------------------------------------------------------------
Income (Loss) from Continuing Operations
Before Income Taxes 54.9 60.3 (6.1) - 24.4 (23.7)
Income Tax Expense (Benefit) 16.4 22.6 (3.2) - 10.1 (13.1)
-----------------------------------------------------------------------------------------------------------------------
Income (Loss) from Continuing Operations 38.5 $ 37.7 $ (2.9) - $14.3 $(10.6)
----------------------------------------------------------------
Income from Discontinued Operations -
Net of Tax 73.7
Change in Accounting Principle -
Net of Tax (7.8)
----------------------------------------------------
Net Income $104.4
----------------------------------------------------
Total Assets $1,431.4 <F1> $902.8 $161.4 - $75.1 $242.6
Capital Additions $79.2 <F1> $41.7 $15.7 - - $0.4
-----------------------------------------------------------------------------------------------------------------------
<F1> Discontinued Operations represented $2.6 million of total assets in 2005($49.5 million in 2004) and $4.5 million
of capital additions in 2005 ($21.4 million in 2004).
|
65 ALLETE 2006 Form 10-K
NOTE 2. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES
FINANCIAL STATEMENT PREPARATION. References in this report to "we," "us" and "our" are to ALLETE and its subsidiaries, collectively. We prepare our financial statements in conformity with accounting principles generally accepted in the United States of America. 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. Our consolidated financial statements include the accounts of ALLETE and all of our majority-owned subsidiary companies. All material intercompany balances and transactions have been eliminated in consolidation.
BUSINESS SEGMENTS. Our Regulated Utility, Nonregulated Energy Operations, Real Estate, Investment in ATC and Other segments were determined in accordance with SFAS 131, "Disclosures about Segments of an Enterprise and Related Information." Segmentation is based on the manner in which we operate, assess, and allocate resources to the business. We measure performance of our operations through budgeting and monitoring of contributions to consolidated net income by each business segment. Discontinued Operations includes our telecommunications business, which we sold on December 30, 2005, our Automotive Services business that was spun off in September 2004, costs associated with the spin-off of ADESA incurred by ALLETE, and our Water Services businesses, the majority of which were sold in 2003.
REGULATED UTILITY includes retail and wholesale rate-regulated electric, natural gas and water services in northeastern Minnesota and northwestern Wisconsin. Minnesota Power, an operating division of ALLETE, and SWL&P, a wholly-owned subsidiary, provide regulated utility electric service to 154,000 retail customers in northeastern Minnesota and northwestern Wisconsin. Approximately 39% of regulated utility electric revenue is from Large Power Customers (33% of consolidated revenue). Large Power Customers consist of five taconite producers, four paper and pulp mills, two pipeline companies and one manufacturer under all-requirements contracts with expiration dates extending from February 2008 through October 2013. Revenue of $89.0 million (11.6% of consolidated revenue) was received from one taconite producer in 2006 (11.3% in 2005; 12.6% in 2004). Regulated utility rates are under the jurisdiction of Minnesota and Wisconsin, and federal regulatory authorities. Billings are rendered on a cycle basis. Revenue is accrued for service provided but not billed. Regulated utility electric rates include adjustment clauses that: (1) bill or credit customers for fuel and purchased energy costs above or below the base levels in rate schedules; (2) bill retail customers for the recovery of conservation improvement program expenditures not collected in base rates; and (3) bill customers for the recovery of certain environmental expenditures. Fuel and purchased power expense is deferred to match the period in which the revenue for fuel and purchased power expense is collected from customers pursuant to the fuel adjustment clause.
Minnesota Power withdrew from Split Rock Energy, a joint venture with Great River Energy, in 2004. Upon withdrawal, we received a $12.0 million distribution in 2004. We accounted for our 50% ownership interest in Split Rock Energy under the equity method of accounting. For the year ended December 31, 2004, our pre-tax equity income from Split Rock Energy was less than $0.1 million. In 2004, prior to our withdrawal, we made power purchases from Split Rock Energy of $6.2 million and power sales to Split Rock Energy of $1.9 million.
NONREGULATED ENERGY OPERATIONS includes our coal mining activities in North Dakota, approximately 50 MW of nonregulated generation and Minnesota land sales. 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 60% (323 MW) of its output to Minnesota Power under a long-term contract. (See Note 8.) Coal sales are recognized when delivered at the cost of production plus a specified profit per ton of coal delivered.
In 2004 and 2005, Nonregulated Energy Operations included nonregulated generation (non-rate base generation sold at market-based rates to the wholesale market) from our Taconite Harbor facility in northern Minnesota and generation secured through the Kendall County power purchase agreement. To help meet forecasted base load energy requirements effective January 1, 2006, Taconite Harbor was integrated into our Regulated Utility business in accordance with the terms of our Resource Plan, as approved by the MPUC. The Kendall County power purchase agreement was assigned to Constellation Energy Commodities in April 2005. (See Note 10.)
INVESTMENT IN ATC includes our approximate 7% equity ownership interest in ATC, a Wisconsin-based public utility that owns and maintains electric transmission assets in parts of Wisconsin, Michigan, Minnesota and Illinois. ATC provides transmission service under rates regulated by the FERC that are set in accordance with the FERC's policy of establishing the independent operation and ownership of, and investment in, transmission facilities. (See Note 6 and 8.)
REAL ESTATE includes our Florida real estate operations. Our real estate operations include several wholly-owned subsidiaries and an 80% ownership in Lehigh Acquisition Corporation, which are consolidated in ALLETE's financial statements. All of our Florida real estate companies are principally engaged in real estate acquisitions, development and sales.
Full profit recognition is recorded on sales upon closing, provided cash collections are at least 20% of the contract price and the other requirements of SFAS 66, "Accounting for Sales of Real Estate," are met. In certain cases, where there are
ALLETE 2006 Form 10-K 66
NOTE 2. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
obligations to perform significant development activities after the date of sale, we recognize profit on a percentage-of-completion basis in accordance with SFAS 66. Pursuant to this method of accounting, gross profit is recognized based upon the relationship of development costs incurred as of that date to the total estimated costs to develop the parcels, including all related amenities or common costs of the entire project. Revenue and cost of real estate sold in excess of the amount recognized based on the percentage-of-completion method is deferred and recognized as revenue and cost of real estate sold during the period in which the related development costs are incurred. Revenue and cost of real estate sold are recorded net as Deferred Profit on Sales of Real Estate on our consolidated balance sheet. In addition to minimum base price contracts, certain contracts allow us to receive participation revenue from land sales to third parties if various formula-based criteria are achieved.
In certain cases, we pay fees or construct improvements to mitigate offsite traffic impacts. In return, we receive traffic impact fee credits. We recognize revenue from the sale of traffic impact fee credits when payment is received.
Land held for sale is recorded at the lower of cost or fair value determined by the evaluation of individual land parcels and is included in Investments on our consolidated balance sheet. Real estate costs include the cost of land acquired, subsequent development costs and costs of improvements, capitalized development period interest, real estate taxes and payroll costs of certain employees devoted directly to the development effort. These real estate costs incurred are capitalized to the cost of real estate parcels based upon the relative sales value of parcels within each development project in accordance with SFAS 67, "Accounting for Costs and Initial Rental Operations of Real Estate Projects." When real estate is sold, the cost of real estate sold includes the actual costs incurred and the estimate of future completion costs allocated to the real estate sold based upon the relative sales value method.
Whenever events or circumstances indicate that the carrying value of the real estate may not be recoverable, impairments would be recorded and the related assets would be adjusted to their estimated fair value, less costs to sell.
OTHER includes investments in emerging technologies, and earnings on cash and short-term investments. As part of our emerging technology portfolio, we have several minority investments in venture capital funds and direct investments in privately-held, start-up companies. We account for our investment in venture capital funds under the equity method and account for our direct investments in privately-held companies under the cost method because of our ownership percentage. Short-term investments consist of auction rate bonds and variable rate demand notes, and are classified as available-for-sale securities. All income generated from these short-term investments is recorded as interest income.
PROPERTY, PLANT AND EQUIPMENT. Property, plant and equipment are recorded at original cost and are reported on the balance sheet net of accumulated depreciation. Expenditures for additions and significant replacements and improvements are capitalized; maintenance and repair costs are expensed as incurred. Expenditures for major plant overhauls are also accounted for using this same policy. Gains or losses on nonregulated property, plant and equipment are recognized when they are retired or otherwise disposed. When regulated utility property, plant and equipment are retired or otherwise disposed, no gain or loss is recognized, pursuant to SFAS 71, "Accounting for the Effects of Certain Types of Regulations." Our Regulated Utility operations capitalize an allowance for funds used during construction, which includes both an interest and equity component.
LONG-LIVED ASSET IMPAIRMENTS. We account for our long-lived assets at depreciated historical cost. A long-lived asset is tested for recoverability whenever events or changes in circumstances indicate that its carrying amount may not be recoverable. We conduct this assessment using SFAS 144, "Accounting for the Impairment and Disposal of Long-Lived Assets." Judgments and uncertainties affecting the application of accounting for asset impairment include economic conditions affecting market valuations, changes in our business strategy, and changes in our forecast of future operating cash flows and earnings. We would recognize an impairment loss only if the carrying amount of a long-lived asset is not recoverable from its undiscounted future cash flows. Management judgment is involved in both deciding if testing for recoverability is necessary and in estimating undiscounted future cash flows.
ACCOUNTS RECEIVABLE. Accounts receivable are reported on the balance sheet net of an allowance for doubtful accounts. The allowance is based on our evaluation of the receivable portfolio under current conditions overall portfolio quality, review of specific problems and such other factors that, in our judgment, deserve recognition in estimating losses.
ACCOUNTS RECEIVABLE
DECEMBER 31 2006 2005
--------------------------------------------------------------------------------------------------------------------------
MILLIONS
Trade Accounts Receivable
Billed $58.5 $65.5
Unbilled 13.5 14.6
Less: Allowance for Doubtful Accounts 1.1 1.0
--------------------------------------------------------------------------------------------------------------------------
Total Accounts Receivable - Net $70.9 $79.1
--------------------------------------------------------------------------------------------------------------------------
|
67 ALLETE 2006 Form 10-K
NOTE 2. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
INVENTORIES. Inventories are stated at the lower of cost or market.
INVENTORIES DECEMBER 31 2006 2005 -------------------------------------------------------------------------------------------------------------------------- MILLIONS Fuel $18.9 $11.0 Materials and Supplies 24.5 22.1 -------------------------------------------------------------------------------------------------------------------------- Total Inventories $43.4 $33.1 -------------------------------------------------------------------------------------------------------------------------- |
UNAMORTIZED DISCOUNT AND PREMIUM ON DEBT. Discount and premium on debt are deferred and amortized over the terms of the related debt instruments using the effective interest method.
CASH AND CASH EQUIVALENTS. We consider all investments purchased with original maturities of three months or less to be cash equivalents.
SUPPLEMENTAL STATEMENT OF CASH FLOW INFORMATION. Amounts presented for 2005 and 2004 have been revised to eliminate intercompany interest payments from cash paid during the period for Interest - Net of Amounts Capitalized.
CONSOLIDATED STATEMENT OF CASH FLOWS
SUPPLEMENTAL DISCLOSURE
FOR THE YEAR ENDED DECEMBER 31 2006 2005 2004
--------------------------------------------------------------------------------------------------------------------------
MILLIONS
Cash Paid During the Period for
Interest - Net of Amounts Capitalized $25.3 $24.6 $41.2
Income Taxes $34.5 <F1> $27.1 $75.7
Noncash Investing Activities
Accounts Payable for Capital Additions to
Property Plant and Equipment $7.1 - -
--------------------------------------------------------------------------------------------------------------------------
<F1> Net of a $24.3 million cash refund.
|
AVAILABLE-FOR-SALE SECURITIES. Available-for-sale securities are recorded at fair value with unrealized gains and losses included in accumulated other comprehensive income (loss), net of tax. Unrealized losses that are other than temporary are recognized in earnings. Our auction rate securities and variable rate demand notes classified as available-for-sale securities, however, are recorded at cost. Their cost approximates fair market value as they typically reset every 7 to 35 days. Despite the long-term nature of their stated contractual maturities, we have the ability to quickly liquidate these securities. We use the specific identification method as the basis for determining the cost of securities sold. Our policy is to review on a quarterly basis available-for-sale securities for other than temporary impairment by assessing such factors as the share price trends and the impact of overall market conditions.
ACCOUNTING FOR STOCK-BASED COMPENSATION. Effective January 1, 2006, we adopted the fair value recognition provisions of SFAS 123R, "Share-Based Payment," using the modified prospective transition method. Under this method, we recognize compensation expense for all share-based payments granted after January 1, 2006, and those granted prior to but not yet vested as of January 1, 2006. Under the fair value recognition provisions of SFAS 123R, we recognize stock-based compensation net of an estimated forfeiture rate and only recognize compensation expense for those shares expected to vest over the required service period of the award. Prior to our adoption of SFAS 123R, we accounted for share-based payments under Accounting Principles Board Opinion No. 25, "Accounting for Stock Issued to Employees" and related interpretations. (See Note 17.)
FOREIGN CURRENCY TRANSLATION. Results of operations for our Canadian and Mexican automotive subsidiaries prior to the spin-off of ADESA in 2004 were translated into United States dollars using the average exchange rates during the applicable periods. Assets and liabilities were translated into United States dollars using the exchange rate on the balance sheet date. Resulting translation adjustments were recorded in Accumulated Other Comprehensive Income (Loss) in Shareholders' Equity.
ALLETE 2006 Form 10-K 68
NOTE 2. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
PREPAYMENTS AND OTHER CURRENT ASSETS DECEMBER 31 2006 2005 --------------------------------------------------------------------------------------------------------------------------- MILLIONS Deferred Fuel Adjustment Clause $15.1 $13.5 Other 8.7 10.3 --------------------------------------------------------------------------------------------------------------------------- Total Prepayments and Other Current Assets $23.8 $23.8 --------------------------------------------------------------------------------------------------------------------------- |
OTHER ASSETS
DECEMBER 31 2006 2005
---------------------------------------------------------------------------------------------------------------------------
MILLIONS
Future Benefit Obligations Under
Defined Benefit Pension and Other Postretirement Plans $ 86.1 -
Other 48.9 $44.6
---------------------------------------------------------------------------------------------------------------------------
Total Other Assets $135.0 $44.6
---------------------------------------------------------------------------------------------------------------------------
|
OTHER LIABILITIES
DECEMBER 31 2006 2005
---------------------------------------------------------------------------------------------------------------------------
MILLIONS
Deferred Regulatory Credits (See Note 5) $ 33.8 $ 31.8
Deferred Compensation 34.2 34.8
Future Benefit Obligation Under
Defined Benefit Pension and Other Postretirement Plans 107.6 27.2
Asset Retirement Obligations (See Note 3) 27.2 25.3
Other 23.3 25.0
---------------------------------------------------------------------------------------------------------------------------
Total Other Liabilities $226.1 $144.1
---------------------------------------------------------------------------------------------------------------------------
|
ENVIRONMENTAL LIABILITIES. We review environmental matters on a quarterly basis. Accruals for environmental matters are recorded when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated, based on current law and existing technologies. These accruals are adjusted periodically as assessment and remediation efforts progress or as additional technical or legal information becomes available. Accruals for environmental liabilities are included in the balance sheet at undiscounted amounts and exclude claims for recoveries from insurance or other third parties. Costs related to environmental contamination treatment and cleanup are charged to operating expense unless recoverable in rates from customers.
INCOME TAXES. We file a consolidated federal income tax return. We account for income taxes using the liability method as prescribed by SFAS 109, "Accounting for Income Taxes." Under the liability method, deferred income tax assets and liabilities are established for all temporary differences in the book and tax basis of assets and liabilities, based upon enacted tax laws and rates applicable to the periods in which the taxes become payable. Due to the effects of regulation on Minnesota Power, certain adjustments made to deferred income taxes are, in turn, recorded as regulatory assets or liabilities. Investment tax credits have been recorded as deferred credits and are being amortized to income tax expense over the service lives of the related property.
EXCISE TAXES. We collect excise taxes from our customers levied by government entities. These taxes are stated separately on the billing to the customer and recorded as a liability to be remitted to the government entity. We account for the collection and payment of these taxes on the net basis and neither the amounts collected or paid are reflected on our consolidated statement of income.
NEW ACCOUNTING STANDARDS. INTERPRETATION NO. 48. In June 2006, the FASB issued Interpretation No. 48, "Accounting for Uncertainty in Income Taxes - an Interpretation of FASB Statement No. 109" (Interpretation No. 48). Interpretation No. 48 clarifies the accounting for uncertain tax positions in accordance with SFAS 109, "Accounting for Income Taxes." Pursuant to Interpretation No. 48, we will be required to recognize in our financial statements the largest tax benefit of a tax position that is "more-likely-than-not" to be sustained, on audit, based solely on the technical merits of the position as of the reporting date. Only tax positions that meet the "more-likely-than-not" threshold at that date may be recognized. The term "more-likely-than-not" means a likelihood of more than 50%. Interpretation No. 48 also provides guidance on new disclosure requirements, reporting and accrual of interest and penalties, accounting in interim periods and transition. The cumulative effect of initially applying Interpretation No. 48 will be recognized as a change in accounting principle as of the date of adoption. We are currently evaluating the impact of applying this interpretation as of January 1, 2007, the effective date of the interpretation. We do not expect Interpretation No. 48 to have a material impact on our financial position, results of operations or cash flows.
69 ALLETE 2006 Form 10-K
NOTE 2. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
SFAS 157. In September 2006, the FASB issued SFAS 157, "Fair Value Measurements" (SFAS 157), to increase consistency and comparability in fair value measurements by defining fair value, establishing a framework for measuring fair value in generally accepted accounting principles, and expanding disclosures about fair value measurements. SFAS 157 emphasizes that fair value is a market-based measurement, not an entity-specific measurement. It clarifies the extent to which fair value is used to measure recognized assets and liabilities, the inputs used to develop the measurements, and the effect of certain measurements on earnings for the period. SFAS 157 is effective for financial statements issued for fiscal years beginning after November 15, 2007, and will be applied on a prospective basis. We are currently evaluating the impact that the adoption of SFAS 157 will have on our financial position, results of operations and cash flows.
NOTE 3. PROPERTY, PLANT AND EQUIPMENT
PROPERTY, PLANT AND EQUIPMENT
DECEMBER 31 2006 <F1> 2005
---------------------------------------------------------------------------------------------------------------------------
MILLIONS
Regulated Utility $1,575.8 $1,457.4
Construction Work in Progress 71.4 21.2
Accumulated Depreciation (781.3) (743.5)
---------------------------------------------------------------------------------------------------------------------------
Regulated Utility Plant - Net 865.9 735.1
---------------------------------------------------------------------------------------------------------------------------
Nonregulated Energy Operations 88.5 160.6
Construction Work in Progress 2.6 3.7
Accumulated Depreciation (40.1) (43.9)
---------------------------------------------------------------------------------------------------------------------------
Nonregulated Energy Operations Plant - Net 51.0 120.4
---------------------------------------------------------------------------------------------------------------------------
Other Plant - Net 4.7 4.9
---------------------------------------------------------------------------------------------------------------------------
Property, Plant and Equipment - Net $ 921.6 $ 860.4
---------------------------------------------------------------------------------------------------------------------------
<F1> Effective January 1, 2006, our Taconite Harbor generating facility was redirected from Nonregulated Energy Operations
to Regulated Utility.
|
Depreciation is computed using the straight-line method over the estimated useful lives of the various classes of plant. The MPUC and the PSCW have approved depreciation rates for our Regulated Utility plant.
ESTIMATED USEFUL LIVES OF PROPERTY, PLANT AND EQUIPMENT
---------------------------------------------------------------------------------------------------------------------------
Regulated Utility - Generation 3 to 30 years Nonregulated Energy Operations 5 to 35 years
Transmission 40 to 60 years Other Plant 5 to 30 years
Distribution 30 to 70 years
---------------------------------------------------------------------------------------------------------------------------
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ASSET RETIREMENT OBLIGATIONS. Pursuant to SFAS 143, "Accounting for Asset Retirement Obligations," we recognize, at fair value, obligations associated with the retirement of tangible, long-lived assets that result from the acquisition, construction or development and/or normal operation of the asset. The associated retirement costs are capitalized as part of the related long-lived asset and depreciated over the useful life of the asset. Asset retirement obligations relate primarily to the decommissioning of our utility steam generating facilities and reclamation at BNI Coal, and are included in Other Liabilities on our consolidated balance sheet. Removal costs associated with certain distribution and transmission assets have not been recognized as these facilities have been determined to have indeterminate useful lives. Prior to the adoption of SFAS 143, utility decommissioning obligations were accrued through depreciation expense at depreciation rates approved by the MPUC. Conditional asset retirement obligations have been identified for treated wood poles and remaining polychlorinated biphenyl and asbestos-containing assets; however, removal costs have not been recognized due to indeterminate retirement settlement dates.
ASSET RETIREMENT OBLIGATION --------------------------------------------------------------------------------------------------------------------------- MILLIONS Obligation at December 31, 2004 $22.4 Accretion Expense 1.6 Additional Liabilities Incurred in 2005 1.3 --------------------------------------------------------------------------------------------------------------------------- Obligation at December 31, 2005 25.3 Accretion Expense 1.8 Additional Liabilities Incurred in 2006 0.1 --------------------------------------------------------------------------------------------------------------------------- Obligation at December 31, 2006 $27.2 --------------------------------------------------------------------------------------------------------------------------- |
ALLETE 2006 Form 10-K 70
NOTE 4. JOINTLY-OWNED ELECTRIC FACILITY
We own 80% of the 536-MW Boswell Energy Center Unit 4 (Boswell Unit 4). While we operate the plant, certain decisions about the operations of Boswell Unit 4 are subject to the oversight of a committee on which we and Wisconsin Public Power, Inc., the owner of the other 20% of Boswell Unit 4, have equal representation and voting rights. Each of us must provide our own financing and is obligated to pay our ownership share of operating costs. Our share of direct operating expenses of Boswell Unit 4 is included in operating expense on our consolidated statement of income. Our 80% share of the original cost of Boswell Unit 4, which is included in property, plant and equipment at December 31, 2006, was $314 million ($310 million at December 31, 2005). The corresponding accumulated depreciation balance was $168 million at December 31, 2006 ($162 million at December 31, 2005).
NOTE 5. REGULATORY MATTERS
ELECTRIC RATES. Entities within our Regulated Utility segment file for periodic rate revisions with the MPUC, the FERC or the PSCW. Minnesota Power's last retail rate filing with the MPUC was in 1994. SWL&P's current retail rates are based on a 2006 PSCW retail rate order, effective January 1, 2007. In 2006, 72% of our consolidated operating revenue was under regulatory authority (72% in 2005; 75% in 2004). The MPUC had regulatory authority over approximately 56% of our consolidated operating revenue in 2006 (56% in 2005; 60% in 2004).
DEFERRED REGULATORY CHARGES AND CREDITS. Our regulated utility operations are subject to the provisions of SFAS 71, "Accounting for the Effects of Certain Types of Regulation." We capitalize 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. Deferred regulatory charges and credits are included in Other Assets and Other Liabilities on our consolidated balance sheet.
DEFERRED REGULATORY CHARGES AND CREDITS
DECEMBER 31 2006 2005
------------------------------------------------------------------------------------------------------------------------
MILLIONS
Deferred Charges
Income Taxes $11.6 $ 12.0
Premium on Reacquired Debt 2.8 3.5
Future Benefit Obligations Under
Defined Benefit Pension and Other Postretirement Plans (See Note 16) 86.1 -
Other 3.1 1.7
------------------------------------------------------------------------------------------------------------------------
103.6 17.2
Deferred Credits - Income Taxes 33.8 31.8
------------------------------------------------------------------------------------------------------------------------
Net Deferred Regulatory Assets (Liabilities) $69.8 $(14.6)
------------------------------------------------------------------------------------------------------------------------
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NOTE 6. INVESTMENTS
AVAILABLE-FOR-SALE INVESTMENTS. We account for our available-for-sale portfolio in accordance with SFAS 115, "Accounting for Certain Investments in Debt and Equity Securities." Our available-for-sale securities portfolio consisted of securities in a grantor trust established to fund certain employee benefits included in Investments and various auction rate municipal bonds and variable rate municipal demand notes included as Short-Term Investments (see below). Available-for-sale securities are recorded at fair value with unrealized gains and losses included in accumulated other comprehensive income (loss), net of tax. Unrealized losses that are other than temporary are recognized in earnings. Our short-term investments classified as available-for-sale securities, however, are recorded at cost. Their cost approximates fair market value as they typically reset every 7 to 35 days. Despite the long-term nature of their stated contractual maturities, we have the ability to quickly liquidate these securities. As a result, we had no cumulative gross unrealized holding gains (losses) or gross realized gains (losses) from our short-term investments. All income generated from these short-term investments was recorded as interest income. We use the specific identification method as the basis for determining the cost of securities sold. Our policy is to review, on a quarterly basis, available-for-sale securities for other than temporary impairment by assessing such factors as the share price trends and the impact of overall market conditions. As a result of our periodic assessments, we did not record any impairment of available-for-sale securities in 2006, 2005 or 2004.
During the fourth quarter of 2004, we sold 3.3 million shares of ADESA stock received by our ESOP plan (see Note 17) as a result of the September 2004 spin-off of ADESA. In total, the ESOP received total proceeds of $65.9 million, resulting in a gain of $11.5 million, which we recognized during the fourth quarter of 2004. We accounted for the ADESA stock as available-for-sale.
71 ALLETE 2006 Form 10-K
NOTE 6. INVESTMENTS (CONTINUED)
AVAILABLE-FOR-SALE SECURITIES
-------------------------------------------------------------------------------------------------------------------------
MILLIONS
GROSS UNREALIZED
AT DECEMBER 31 COST GAIN (LOSS) FAIR VALUE
-------------------------------------------------------------------------------------------------------------------------
2006 $123.2 $7.0 $(0.1) $130.1
2005 $135.2 $4.4 $(0.1) $139.5
2004 $176.4 $3.1 $(0.1) $179.4
-------------------------------------------------------------------------------------------------------------------------
NET
UNREALIZED
GAIN (LOSS)
IN OTHER
YEAR ENDED SALES GROSS REALIZED COMPREHENSIVE
DECEMBER 31 PROCEEDS GAIN (LOSS) INCOME
-------------------------------------------------------------------------------------------------------------------------
2006 $12.4 - - $2.7
2005 $32.3 - - $1.3
2004 $65.9 $11.5 - $1.6
-------------------------------------------------------------------------------------------------------------------------
|
SHORT-TERM INVESTMENTS. At December 31, 2006, we held $104.5 million of short-term investments ($116.9 million at December 31, 2005) consisting of various auction rate municipal bonds and variable rate municipal demand notes.
INVESTMENTS. At December 31, 2006, our long-term investment portfolio included the real estate assets of ALLETE Properties, our investment in ATC, debt and equity securities consisting primarily of securities held to fund employee benefits, and our emerging technology portfolio.
INVESTMENTS DECEMBER 31 2006 2005 ------------------------------------------------------------------------------------------------------------------------- MILLIONS Real Estate Assets $ 89.8 $ 73.7 Debt and Equity Securities 36.4 34.8 Investment in ATC 53.7 - Emerging Technology Portfolio 9.2 9.2 ------------------------------------------------------------------------------------------------------------------------- Total Investments $189.1 $ 117.7 ------------------------------------------------------------------------------------------------------------------------- |
REAL ESTATE ASSETS 2006 2005
-------------------------------------------------------------------------------------------------------------------------
MILLIONS
Land Held for Sale Beginning Balance $48.0 $47.2
Additions during period: Capitalized Improvements 18.8 9.4
Purchases 1.4 -
Deductions during period: Cost of Real Estate Sold (10.2) (8.6)
-------------------------------------------------------------------------------------------------------------------------
Land Held for Sale Ending Balance 58.0 48.0
Long-Term Finance Receivables 18.3 7.4
Other <F1> 13.5 18.3
-------------------------------------------------------------------------------------------------------------------------
Total Real Estate Assets $89.8 $73.7
-------------------------------------------------------------------------------------------------------------------------
<F1> Consisted primarily of a shopping center.
|
Finance receivables, which are collateralized by land, have maturities ranging up to ten years, accrue interest at market-based rates and are net of an allowance for doubtful accounts of $0.2 million at December 31, 2006 ($0.6 million at December 31, 2005). Minority interest associated with real estate operations was $7.4 million at December 31, 2006 ($6.0 million at December 31, 2005).
INVESTMENT IN ATC. We have an equity ownership interest in ATC, a Wisconsin-based public utility that owns and maintains electric transmission assets in parts of Wisconsin, Michigan, Minnesota and Illinois. ATC provides transmission service under rates regulated by the FERC that are set in accordance with the FERC's policy of establishing the independent operation and ownership of, and investment in, transmission facilities. We account for our investment in ATC under the equity method of accounting, pursuant to EITF 03-16, "Accounting for Investments in Limited Liability Companies."
ALLETE 2006 Form 10-K 72
NOTE 6. INVESTMENTS (CONTINUED)
ALLETE'S INTEREST IN ATC FOR THE YEAR ENDED DECEMBER 31, 2006 ----------------------------------------------------------------------------------------------------- MILLIONS Equity in Earnings $3.0 Accumulated Equity in Undistributed Earnings $2.3 Equity Investment Balance $53.7 Equity Ownership 7% ----------------------------------------------------------------------------------------------------- |
EMERGING TECHNOLOGY PORTFOLIO. As part of our emerging technology portfolio, we have several minority investments in venture capital funds and direct investments in privately-held, start-up companies. We account for our investment in venture capital funds under the equity method and account for our direct investments in privately-held companies under the cost method because of our ownership percentage. The total carrying value of our emerging technology portfolio was $9.2 million at December 31, 2006, and December 31, 2005. Our policy is to review these investments quarterly for impairment by assessing such factors as continued commercial viability of products, cash flow and earnings. Any impairment would reduce the carrying value of the investment. Our basis in direct investments in privately-held companies included in the emerging technology portfolio was zero at both December 31, 2006, and December 31, 2005. We did not record any impairments in 2006. In 2005, we recorded $5.1 million ($3.3 million after tax) of impairments related to our direct investments in certain privately-held, start-up companies whose future business prospects had significantly diminished. Developments at these companies indicated that future commercial viability was unlikely, as was new financing necessary to continue development. In 2004, we recorded $6.5 million ($4.1 million after tax) of impairments.
FAIR VALUE OF FINANCIAL INSTRUMENTS. With the exception of the items listed below, the estimated fair value of all financial instruments approximates the carrying amount. The fair value for the items below were based on quoted market prices for the same or similar instruments.
FINANCIAL INSTRUMENTS
DECEMBER 31 CARRYING AMOUNT FAIR VALUE
-----------------------------------------------------------------------------------------------------
MILLIONS
Long-Term Debt
2006 $389.5 $387.6
2005 $390.5 $392.5
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CONCENTRATION OF CREDIT RISK. Financial instruments that subject us to concentrations of credit risk consist primarily of accounts receivable. Minnesota Power sells electricity to 12 Large Power Customers. Receivables from these customers totaled approximately $9 million at December 31, 2006 ($10 million at December 31, 2005). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, our taconite-producing Large Power Customers are on a weekly billing cycle, which allows us to closely manage collection of amounts due.
NOTE 7. SHORT-TERM AND LONG-TERM DEBT
SHORT-TERM DEBT. Total short-term debt outstanding at December 31, 2006, was $29.7 million ($2.7 million at December 31, 2005) and consisted of Long-Term Debt Due Within One Year.
As of December 31, 2006, we had bank lines of credit aggregating $170.0 million ($120.0 million at December 31, 2005), the majority of which expire in January 2012. These bank lines of credit made financing available through short-term bank loans and provided credit support for commercial paper. At December 31, 2006, $2.9 million ($1.1 million at December 31, 2005) was drawn on our lines of credit leaving a $167.1 million balance available for use ($118.9 million at December 31, 2005). The drawn amounts at December 31, 2006 and 2005, related to an $8.5 million revolving development loan with CypressCoquina Bank that we entered into in March 2005. The revolving development loan has an interest rate equal to the prime rate, with an initial term of 36 months. The term of the loan may be extended 24 months if certain conditions are met. The loan is guaranteed by Lehigh Acquisition Corporation. There was no commercial paper issued as of December 31, 2006, or December 31, 2005.
In January 2006, we renewed, increased and extended a committed, syndicated, unsecured revolving credit facility (Line) with LaSalle Bank National Association, as Agent, for $150 million ($100 million at December 31, 2005). The Line was subsequently extended for an additional year in December 2006 and currently matures in January 2012. At our request and subject to certain conditions, the Line may be increased to $200 million and extended for two additional 12-month periods. The Line may be used for general corporate purposes and working capital, and to provide liquidity in support of our commercial paper program. We may prepay amounts outstanding under the Line in whole or in part at our discretion without premium or penalty. Additionally, we may irrevocably terminate or reduce the size of the Line prior to maturity without premium or penalty. No funds were drawn under this Line at December 31, 2006.
73 ALLETE 2006 Form 10-K
NOTE 7. SHORT-TERM AND LONG-TERM DEBT (CONTINUED)
LONG-TERM DEBT. The aggregate amount of long-term debt maturing during 2007 is $29.7 million ($7.0 million in 2008; $10.2 million in 2009; $4.5 million in 2010; $0.9 million in 2011; and $337.2 million thereafter). Substantially all of our electric plant is subject to the lien of the mortgages collateralizing various first mortgage bonds.
In March 2006, we issued $50 million in principal amount of First Mortgage Bonds, 5.69% Series due March 1, 2036, in the private placement market. Proceeds were used to redeem $50 million in principal amount of First Mortgage Bonds, 7% Series due March 1, 2008.
In July 2006, the Collier County Industrial Development Authority (Authority or Issuer) issued $27.8 million of Industrial Development Variable Rate Demand Refunding Revenue Bonds Series 2006 due 2025 (Refunding Bonds) on behalf of ALLETE. The interest rate on these bonds was 3.94% at December 31, 2006. Pursuant to a financing agreement between the Authority and ALLETE dated as of July 1, 2006, ALLETE is obligated to make payments to the Issuer sufficient to pay all principal and interest on the Refunding Bonds. ALLETE's obligations under the financing agreement are supported by a direct pay letter of credit. Proceeds from the Refunding Bonds and internally generated funds were used to redeem $29.1 million of outstanding Collier County Industrial Development Refunding Revenue Bonds 6.5% Series 1996 due 2025 on August 9, 2006. As a result of an early redemption premium, we recognized a $0.6 million pre-tax charge to other expense in the third quarter of 2006.
On February 1, 2007, we issued $60 million in principal amount of First Mortgage Bonds, 5.99% Series due February 1, 2027, in the private placement market. Proceeds were used to retire $60 million in principal amount of First Mortgage Bonds, 7% Series on February 15, 2007.
LONG-TERM DEBT
DECEMBER 31 2006 2005
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MILLIONS
First Mortgage Bonds
6.68% Series Due 2007 $ 20.0 $ 20.0
7% Series Due 2007 <F1> 60.0 60.0
7% Series Due 2008 - 50.0
5.28% Series Due 2020 35.0 35.0
4.95% Pollution Control Series F Due 2022 111.0 111.0
5.69% Series Due 2036 50.0 -
Variable Demand Revenue Refunding Bonds
Series 1997 A, B, C and D Due 2007 - 2020 39.0 39.0
Industrial Development Revenue Bonds 6.5% Due 2025 6.0 35.1
Industrial Development Variable Rate Demand Refunding
Revenue Bonds Series 2006 Due 2025 27.8 -
Other Long-Term Debt, 2.0% - 8.5% Due 2007 - 2025 40.7 40.4
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Total Long-Term Debt 389.5 390.5
Less Due Within One Year 29.7 2.7
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Net Long-Term Debt $359.8 $387.8
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<F1> Retired on February 15, 2007.
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The 6.68% Series Due 2007 cannot be redeemed prior to November 15, 2007. The remaining debt may be redeemed in whole or in part at our option, according to the terms of the obligations.
FINANCIAL COVENANTS. Our lines of credit and letters of credit supporting certain long-term debt arrangements contain financial covenants. The most restrictive covenant requires ALLETE to maintain a quarterly ratio of its funded debt to total capital of less than or equal to .65 to 1.00. Failure to meet this covenant could give rise to an event of default, if not corrected after notice from the lender, in which event ALLETE may need to pursue alternative sources of funding. Some of ALLETE's debt arrangements contain "cross-default" provisions that would result in an event of default if there is a failure under other financing arrangements to meet payment terms or to observe other covenants that would result in an acceleration of payments due.
ALLETE 2006 Form 10-K 74
NOTE 8. COMMITMENTS, GUARANTEES AND CONTINGENCIES
OFF-BALANCE SHEET ARRANGEMENTS. SQUARE BUTTE POWER PURCHASE AGREEMENT. Minnesota Power has a power purchase agreement with Square Butte that extends through 2026 (Agreement). It provides a long-term supply of low-cost energy to customers in our electric service territory and enables Minnesota Power to meet power pool reserve requirements. Square Butte, a North Dakota cooperative corporation, owns a 455-MW coal-fired generating unit (Unit) near Center, North Dakota. The Unit is adjacent to a generating unit owned by Minnkota Power, a North Dakota cooperative corporation whose Class A members are also members of Square Butte. Minnkota Power serves as the operator of the Unit and also purchases power from Square Butte.
Minnesota Power was entitled to approximately 71% of the Unit's output under the Agreement prior to 2006. Beginning in 2006, Minnkota Power exercised its option to reduce Minnesota Power's entitlement by approximately 5% annually, to 66%. We received notices from Minnkota Power that they further reduced our output entitlement by approximately 5% annually to 60% on January 1, 2007, 55% on January 1, 2008, and 50% on January 1, 2009, and thereafter. Minnkota Power has no further option to reduce Minnesota Power's entitlement below 50%.
Minnesota Power is obligated to pay its pro rata share of Square Butte's costs based on Minnesota Power's entitlement to Unit output. Minnesota Power's payment obligation will be 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, 2006, Square Butte had total debt outstanding of $303.7 million. Total annual debt service for Square Butte is expected to be approximately $26 million in each of the years 2007 through 2011. Variable operating costs include the price of coal purchased from BNI Coal, our subsidiary, under a long-term contract.
Minnesota Power's cost of power purchased from Square Butte during 2006 was $57.9 million ($56.4 million in 2005; $56.1 million in 2004). This reflects Minnesota Power's pro rata share of total Square Butte costs, based on the 66% output entitlement in 2006 and the 71% output entitlement in 2005 and 2004. Included in this amount was Minnesota Power's pro rata share of interest expense of $12.6 million in 2006 ($13.6 million in 2005; $12.6 million in 2004). Minnesota Power's payments to Square Butte are approved as a purchased power expense for ratemaking purposes by both the MPUC and the FERC.
LEASING AGREEMENTS. BNI Coal is obligated to make lease payments for a dragline totaling $2.8 million annually for the lease term which expires in 2027. BNI Coal has the option at the end of the lease term to renew the lease at a fair market rental, to purchase the dragline at fair market value, or to surrender the dragline and pay a $3.0 million termination fee. We lease other properties and equipment under operating lease agreements with terms expiring through 2013. The aggregate amount of minimum lease payments for all operating leases is $8.2 million in 2007, $7.6 million in 2008, $7.0 million in 2009, $6.5 million in 2010, $6.0 million in 2011 and $51.2 million thereafter. Total rent expense was $6.8 million in 2006 ($6.2 million in 2005; $3.8 million in 2004).
COAL, RAIL AND SHIPPING CONTRACTS. We have three coal supply agreements with various expiration dates ranging from December 2008 to December 2009. We also have rail and shipping agreements for the transportation of all of our coal, with various expiration dates ranging from December 2007 to December 2011. Our minimum annual payment obligations under these coal, rail and shipping agreements are currently $37.8 million in 2007, $11.2 million in 2008, $5.8 million in 2009 and no specific commitments beyond 2009. Our minimum annual payment obligations will increase when annual nominations are made for coal deliveries in future years.
FUEL CLAUSE RECOVERY OF MISO DAY 2 COSTS. Minnesota Power filed a petition with the MPUC in February 2005 to amend its fuel clause to accommodate costs and revenue related to the MISO Day 2 energy market, the market through which Minnesota Power engages in wholesale energy transactions in MISO's day-ahead and real-time markets (MISO Day 2). In April 2005, the MPUC approved interim accounting treatment of MISO Day 2 costs to be accounted for on a net basis and recovered through the fuel clause, subject to refund with interest. This interim treatment has continued while the MPUC has addressed the cost recovery petitions from Xcel Energy Inc., Otter Tail Power Company, Alliant Energy Corporation and Minnesota Power.
In December 2005, the MPUC issued an order which denied recovery through the fuel clause of uplift charges, congestion revenue and expenses, and administrative costs related to Minnesota Power's MISO Day 2 market activities. This denial created a refund obligation. Minnesota Power requested rehearing of the order in a filing made with the MPUC in January 2006. The other three utilities affected by the order also filed for rehearing, as did the DOC and MISO. In February 2006, the MPUC granted rehearing of the MISO Day 2 docket and suspended the refund obligation for charges recovered through the fuel clause denied in the December 2005 order. The MPUC also ordered review of MISO Day 2 costs to determine which costs should be recovered on a current basis through the fuel clause and which costs are more appropriately deferred for potential recovery through base rates. The Company worked with other Minnesota utilities, the DOC and other stakeholders to review MISO Day 2 costs and to prepare a joint report and recommendations. The joint report and recommendations were filed with the MPUC in June 2006. A technical conference on the report was held with the MPUC on October 31, 2006. At a hearing November 9, 2006, the MPUC approved current recovery of nearly all MISO Day 2 charges.
75 ALLETE 2006 Form 10-K
NOTE 8. COMMITMENTS, GUARANTEES AND CONTINGENCIES (CONTINUED)
On December 20, 2006, the MPUC issued an order allowing Minnesota Power and the other utilities involved in the MISO Day 2 proceeding to continue recovering MISO Day 2 charges through the Minnesota retail fuel clause except for MISO Day 2 administrative charges. On January 8, 2007, this order was challenged by the Minnesota OAG, which has sought reconsideration. The rehearing has been opposed by Minnesota Power and the other utilities, as well as MISO. The reconsideration request is currently pending before the MPUC. The MPUC has until March 9, 2007, to act on the Minnesota OAG's request. The order, if upheld, grants deferred accounting treatment for three MISO Day 2 charge types that were determined to be administrative charges. Under the order, Minnesota Power would refund through customer bills approximately $2 million of administrative charges previously collected through the fuel clause between April 1, 2005, and December 31, 2006, and record these administrative charges as a regulatory asset. Minnesota Power would be permitted to continue accumulating MISO Day 2 administrative charges after December 31, 2006, as a regulatory asset until it files its next rate case, at which time recovery for such charges will be determined. This order would remove the subject to refund requirement of the two interim orders, and include extensive fuel clause reporting requirements that would be reviewed in Minnesota Power's monthly and annual fuel clause filings with the MPUC. There would be no impact on earnings as a result of this ruling. The Company is unable to predict the outcome of this matter.
EMERGING TECHNOLOGY PORTFOLIO. We have investments in emerging technologies through minority investments in venture capital funds structured as limited liability companies, and direct investments in privately-held, start-up companies. We have committed to make additional investments in certain emerging technology venture capital funds. The total future commitment was $2.5 million at December 31, 2006 ($3.1 million at December 31, 2005), and will be invested in 2007. We do not have plans to make any additional investments beyond this commitment.
INVESTMENT IN ATC. In December 2005, we entered into an agreement with Wisconsin Public Service Corporation and WPS Investments, LLC that provides for our Wisconsin subsidiary, Rainy River Energy Corporation - Wisconsin, to invest $60 million in ATC. In May 2006, the PSCW reviewed and approved the request that allows us to invest in ATC. During 2006, we invested $51.4 million in ATC. We plan to invest an additional $8.6 million in ATC in early 2007 to reach our $60 million investment commitment and estimated 8% ownership interest. As of December 31, 2006, our equity investment balance in ATC was $53.7 million, representing approximately a 7% ownership interest. (See Note 6.)
ENVIRONMENTAL MATTERS. Our businesses are subject to regulation of environmental matters by various federal, state and local authorities. Due to future stricter environmental requirements through legislation and/or rulemaking, we anticipate that potential expenditures for environmental matters will be material and will require significant capital investments. We review environmental matters on a quarterly basis. Accruals for environmental matters are recorded when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated, based on current law and existing technologies. These accruals are adjusted periodically as assessment and remediation efforts progress or as additional technical or legal information becomes available. Accruals for environmental liabilities are included in the balance sheet at undiscounted amounts and exclude claims for recoveries from insurance or other third parties. Costs related to environmental contamination treatment and cleanup are charged to expense unless recoverable in rates from customers.
SWL&P MANUFACTURED GAS PLANT. In May 2001, SWL&P received notice from the WDNR that the city of Superior had found soil contamination on property adjoining a former Manufactured Gas Plant (MGP) site owned and operated by SWL&P from 1889 to 1904. The WDNR requested SWL&P to initiate an environmental investigation. The WDNR also issued SWL&P a Responsible Party letter in February 2002. In February 2003, SWL&P submitted a Phase II environmental site investigation report to the WDNR. This report identified some MGP-like chemicals that were found in the soil near the former plant site. The investigation continued through the fall of 2006. It is anticipated that the final report for this portion of the investigation will be completed during the first quarter of 2007. Although it is not possible to quantify the total potential clean-up costs until the investigation is completed, a $0.5 million liability was recorded in December 2003 based on initial studies to address the known areas of contamination. The Company has recorded a corresponding amount as a regulatory asset. The PSCW has approved SWL&P's deferral of these MGP environmental investigation and potential clean-up costs for future recovery in rates, subject to a regulatory prudency review. In May 2005, the PSCW approved the collection through rates of $150,000 of site investigation costs that had been incurred at the time SWL&P filed its 2006 rate request. In December 2006, the PSCW approved the recovery of an additional $186,000 of site investigation costs that were incurred through 2005. ALLETE maintains pollution liability insurance coverage that includes coverage for SWL&P. A claim has been filed with respect to this matter. The insurance carrier has issued a reservation of rights letter and the Company continues to work with the insurer to determine the availability of insurance coverage.
ALLETE 2006 Form 10-K 76
NOTE 8. COMMITMENTS, GUARANTEES AND CONTINGENCIES (CONTINUED)
EPA CLEAN AIR INTERSTATE RULE AND CLEAN AIR MERCURY RULE. In March 2005, the EPA announced the final Clean Air Interstate Rule (CAIR) that reduces and permanently caps emissions of SO2 and NOX in the eastern United States. The CAIR includes Minnesota as one of the 28 states it considers an "eastern" state. The EPA also announced the final Clean Air Mercury Rule (CAMR) that reduces and permanently caps electric utility mercury emissions nationwide. The CAIR and the CAMR regulations have been challenged in the federal court system, which may delay implementation or modify provisions. Minnesota Power is participating in a legal challenge to the CAIR, but is not participating in a challenge to the CAMR. However, if the CAMR and the CAIR do go into effect, Minnesota Power expects to be required to: (1) make emissions reductions; (2) purchase mercury, SO2 and NOX allowances through the EPA's cap-and-trade system; or (3) use a combination of both.
Minnesota Power petitioned the EPA to review their CAIR determinations affecting Minnesota. In July 2005, Minnesota Power also filed a Petition for Review with the U.S. Court of Appeals for the District of Columbia Circuit (Court of Appeals). In November 2005, the EPA agreed to reconsider certain aspects of the CAIR, including the Minnesota Power petition addressing modeling used to determine Minnesota's inclusion in the CAIR region and our claims about inequities in the SO2 allowance methodology. In March 2006, the EPA announced that it would not make any changes to the CAIR as a result of the petitions for reconsideration. Petitions for Review, including Minnesota Power's, remain pending at the Court of Appeals. If the Petitions for Review filed with the Court of Appeals are successful, we expect to incur lower compliance costs, consistent with the rules applicable to those states considered "western" states under the CAIR. Resolution of the CAIR Petition for Review with the Court of Appeals is anticipated in 2008.
COMMUNITY DEVELOPMENT DISTRICT OBLIGATIONS. TOWN CENTER. In March 2005, the Town Center District issued $26.4 million of tax-exempt, 6% Capital Improvement Revenue Bonds, Series 2005, which are payable over 31 years (by May 1, 2036). The bond proceeds (less capitalized interest, a debt service reserve fund and cost of issuance) were used to pay for the construction of a portion of the major infrastructure improvements at Town Center. The bonds are payable from and secured by the revenue derived from assessments imposed, levied and collected by the Town Center District. The assessments represent an allocation of the costs of the improvements, including bond financing costs, to the lands within the Town Center District benefiting from the improvements. The assessments were billed to Town Center landowners beginning in November 2006. To the extent that we still own land at the time of the assessment, in accordance with EITF 91-10, we recognize the cost of our portion of these assessments, based upon our ownership of benefited property. At December 31, 2006, we owned approximately 73% of the assessable land in the Town Center District.
PALM COAST PARK. In May 2006, the Palm Coast Park District issued $31.8 million of tax-exempt, 5.7% Special Assessment Bonds, Series 2006, which are payable over 31 years (by May 1, 2037). The bond proceeds (less capitalized interest, a debt service reserve fund and cost of issuance) are being used to pay for the construction of the major infrastructure improvements at Palm Coast Park and to mitigate traffic and environmental impacts. The bonds are payable from and secured by the revenue derived from assessments imposed, levied and collected by the Palm Coast Park District. The assessments represent an allocation of the costs of the improvements, including bond financing costs, to the lands within the Palm Coast Park District benefiting from the improvements. The assessments will be billed to Palm Coast Park landowners beginning in November 2007. To the extent that we still own land at the time of the assessment, in accordance with EITF 91-10, we will recognize the cost of our portion of these assessments, based upon our ownership of benefited property. At December 31, 2006, we owned 97% of the assessable land in the Palm Coast Park District.
OTHER. We are involved in litigation arising in the normal course of business. Also in the normal course of business, we are involved in tax, regulatory and other governmental audits, inspections, investigations and other proceedings that involve state and federal taxes, safety, compliance with regulations, rate base and cost of service issues, among other things. While the resolution of such matters could have a material effect on earnings and cash flows in the year of resolution, none of these matters are expected to materially change our present liquidity position, or have a material adverse effect on our financial condition.
77 ALLETE 2006 Form 10-K
NOTE 9. COMMON STOCK AND EARNINGS PER SHARE
Our Articles of Incorporation and mortgages contain provisions that, under certain circumstances, would restrict the payment of common stock dividends. As of December 31, 2006, no retained earnings were restricted as a result of these provisions.
REVERSE COMMON STOCK SPLIT. On September 20, 2004, our one-for-three reverse common stock split became effective. All common share and per share amounts have been adjusted for all periods to reflect the one-for-three reverse stock split.
SUMMARY OF COMMON STOCK SHARES EQUITY
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THOUSANDS MILLIONS
Balance at December 31, 2003 29,099 $859.2
2004 Employee Stock Purchase Plan 14 1.0
Invest Direct <F1> 247 18.1
ADESA IPO (See Note 13) - 70.1
Spin-Off of ADESA (See Note 13) - (600.2)
Receipt of ADESA Stock by ESOP - 27.8
Reacquired (70) (5.8)
Options and Stock Awards 361 29.9
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Balance at December 31, 2004 29,651 400.1
2005 Employee Stock Purchase Plan 13 0.5
Invest Direct <F1> 238 10.5
Options and Stock Awards 241 10.0
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Balance at December 31, 2005 30,143 421.1
2006 Employee Stock Purchase Plan 12 0.5
Invest Direct <F1> 218 10.0
Options and Stock Awards 63 7.1
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Balance at December 31, 2006 30,436 $438.7
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<F1> Invest Direct is ALLETE's direct stock purchase and dividend reinvestment plan.
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SHAREHOLDER RIGHTS PLAN. In 1996, we adopted a rights plan that provides for a dividend distribution of one preferred share purchase right (Right) to be attached to each share of common stock. In July 2006, we amended the rights plan to extend the expiration of the Rights to July 11, 2009. The amendment also provides that the Company may not consolidate, merge, or sell a majority of its assets or earning power if doing so would be counter to the intended benefits of the Rights or would result in the distribution of Rights to the shareholders of the other parties to the transaction. Finally, the amendment provides for the creation of a committee of independent directors to annually review the terms and conditions of the amended rights plan (Rights Plan), as well as to consider whether termination or modification of the Rights Plan would be in the best interests of the shareholders and to make a recommendation based on such review to the Board of Directors.
The Rights, which are currently not exercisable or transferable apart from our common stock, entitle the holder to purchase one-and-a-half one-hundredths (three two-hundredths) of a share of ALLETE's Junior Serial Preferred Stock A, without par value. The purchase price, as defined in the Rights Plan, remains at $90. These Rights would become exercisable if a person or group acquires beneficial ownership of 15% or more of our common stock or announces a tender offer which would increase the person's or group's beneficial ownership interest to 15% or more of our common stock, subject to certain exceptions. If the 15% threshold is met, each Right entitles the holder (other than the acquiring person or group) to receive, upon payment of the purchase price, the number of shares of common stock (or, in certain circumstances, cash, property or other securities of ours) having a market value equal to twice the exercise price of the Right. If we are acquired in a merger or business combination, or more than 50% of our assets or earning power are sold, each exercisable Right entitles the holder to receive, upon payment of the purchase price, the number of shares of common stock of the acquiring or surviving company having a value equal to twice 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 our common stock.
The Rights are nonvoting and may be redeemed by us at a price of $0.005 per Right at any time they are not exercisable. One million shares of Junior Serial Preferred Stock A have been authorized and are reserved for issuance under the Rights Plan.
ALLETE 2006 Form 10-K 78
NOTE 9. COMMON STOCK AND EARNINGS PER SHARE (CONTINUED)
EARNINGS PER SHARE. The difference between basic and diluted earnings per share arises from outstanding stock options and performance share awards granted under our Executive and Director Long-Term Incentive Compensation Plans. For 2006 and 2005, no options to purchase shares of common stock were excluded from the computation of diluted earnings per share because they were anti-dilutive due to the option exercise prices being greater than the average market price of the common shares during the period (0.1 shares were excluded for 2004).
RECONCILIATION OF BASIC AND DILUTED
EARNINGS PER SHARE DILUTIVE
FOR THE YEAR ENDED DECEMBER 31 BASIC SECURITIES DILUTED
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MILLIONS EXCEPT PER SHARE AMOUNTS
2006
Income from Continuing Operations $77.3 - $77.3
Common Shares 27.8 0.1 27.9
Per Share from Continuing Operations $2.78 - $2.77
2005
Income from Continuing Operations $17.6 - $17.6
Common Shares 27.3 0.1 27.4
Per Share from Continuing Operations $0.65 - $0.64
2004
Income from Continuing Operations
Before Change in Accounting Principle $38.5 - $38.5
Common Shares 28.3 0.1 28.4
Per Share from Continuing Operations $1.37 - $1.35
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NOTE 10. KENDALL COUNTY CHARGE
On April 1, 2005, Rainy River Energy, a wholly-owned subsidiary of ALLETE, completed the assignment of its power purchase agreement with LSP-Kendall Energy, LLC, the owner of an energy generation facility located in Kendall County, Illinois, to Constellation Energy Commodities. Rainy River Energy paid Constellation Energy Commodities $73 million in cash to assume the power purchase agreement that remains in effect through mid-September 2017. The federal tax benefits of the payment were realized through a $24.3 million capital loss carryback refund in the third quarter of 2006. In addition, consent, advisory and closing costs of $4.9 million were incurred to complete the transaction. As a result of this transaction, ALLETE incurred a charge to operating expenses totaling $77.9 million ($50.4 million after tax, or $1.84 per diluted share) in the second quarter of 2005.
79 ALLETE 2006 Form 10-K
NOTE 11. OTHER INCOME (EXPENSE)
FOR THE YEAR ENDED DECEMBER 31 2006 2005 2004 --------------------------------------------------------------------------------------------------------------------------- MILLIONS Loss on Emerging Technology Investments $(0.9) $(6.1) $ (8.6) Income from Investment in ATC (See Note 6) 3.0 - - Debt Prepayment Premium and Unamortized Debt Issuance Costs (0.6) - (18.5) Gain on ESOP's Sale of ADESA Stock (See Note 17) - - 11.5 Investments and Other Income 13.4 7.2 3.4 --------------------------------------------------------------------------------------------------------------------------- Total Other Income (Expense) $14.9 $ 1.1 $(12.2) --------------------------------------------------------------------------------------------------------------------------- |
In August 2006, we redeemed $29.1 million of outstanding Collier County Industrial Development Refunding Revenue Bonds 6.5% Series 1996 due 2025 with proceeds from the issuance of $27.8 million of Collier County Industrial Development Variable Rate Demand Refunding Revenue Bonds Series 2006 due 2025 and internally generated funds. As a result of an early redemption premium, we recognized an expense of $0.6 million in the third quarter of 2006.
In July 2004, we repaid $125 million in principal amount of 7.80% Senior Notes due 2008. Proceeds from the sale of our water assets and proceeds received from ADESA were used to repay this debt. As a result of the redemption, we recognized an expense of $18.5 million in the third quarter of 2004 comprised of an early redemption premium and the write-off of unamortized debt issuance costs.
NOTE 12. INCOME TAX EXPENSE
INCOME TAX EXPENSE
YEAR ENDED DECEMBER 31 2006 2005 2004
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MILLIONS
Current Tax Expense
Federal $ 8.9 <F1> $ 27.2 <F2> $11.2
State 9.6 6.5 <F2> 6.3
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Total Current Tax Expense 18.5 33.7 17.5
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Deferred Tax Expense (Benefit)
Federal 28.0 <F1> (26.4) <F2> 1.6
State 2.0 (9.5) (2.3)
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Total Deferred Tax Expense (Benefit) 30.0 (35.9) (0.7)
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Change in Valuation Allowance (1.1) 3.0 0.9
Deferred Tax Credits (1.1) (1.3) (1.3)
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Income Tax Expense (Benefit) for Continuing Operations 46.3 (0.5) 16.4
Income Tax Expense (Benefit) for Discontinued Operations (0.6) 3.4 57.6
Change in Accounting Principle - - (5.5)
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Total Income Tax Expense $45.7 $2.9 $68.5
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<F1> Included a current federal tax benefit of $24.3 million and a deferred federal tax expense of $24.3 million related to
the refund from the Kendall County capital loss carryback. (See Note 10.)
<F2> Included a current federal tax benefit of $1.3 million, current state tax benefit of $0.4 million and deferred federal
tax benefit of $25.8 million related to the Kendall County charge. (See Note 10.)
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ALLETE 2006 Form 10-K 80
NOTE 12. INCOME TAX EXPENSE (CONTINUED)
RECONCILIATION OF TAXES FROM FEDERAL STATUTORY
RATE TO TOTAL INCOME TAX EXPENSE FOR CONTINUING OPERATIONS
YEAR ENDED DECEMBER 31 2006 2005 2004
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MILLIONS
Income from Continuing Operations
Before Minority Interest and Income Taxes $128.2 $19.8 $57.0
Statutory Federal Income Tax Rate 35% 35% 35%
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Income Taxes Computed at 35% Statutory Federal Rate 44.9 6.9 20.0
Increase (Decrease) in Tax Due to:
Amortization of Deferred Investment Tax Credits (1.1) (1.3) (1.3)
State Income Taxes - Net of Federal Income Tax Benefit 6.5 1.1 3.6
Depletion (1.1) (1.0) (0.6)
Employee Benefits 0.1 (0.5) (0.4)
Domestic Manufacturing Deduction (0.6) (0.4) -
Regulatory Differences for Utility Plant (0.7) (0.6) (0.6)
Positive Resolution of Audit Issues - (3.7) -
Sale of ADESA Stock by ESOP - - (4.1)
Other (1.7) (1.0) (0.2)
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Total Income Tax Expense (Benefit) for Continuing Operations $ 46.3 $(0.5) $16.4
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The effective tax rate on income from continuing operations before minority interest was a 36.1% expense for 2006; (2.5% benefit for 2005; 28.8% expense for 2004). The 2006 effective rate was impacted by investment tax credits, deductions for Medicare health subsidies, depletion and the expected use of state capital loss carryforwards, of which a $1.1 million benefit was included in the state tax provision. The 2005 effective rate was impacted by three major items--a $2.5 million deferred tax adjustment to reflect comprehensive state tax planning initiatives, a $3.7 million current tax adjustment to reflect the receipt of a positive audit report and an increase in taxes due to the inability to recognize certain state benefits for capital loss carryforwards.
DEFERRED TAX ASSETS AND LIABILITIES
DECEMBER 31 2006 2005
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MILLIONS
Deferred Tax Assets
Employee Benefits and Compensation <F1> $ 95.5 $ 58.0
Property Related 32.8 31.0
Kendall County Capital Loss 4.3 30.5
Investment Tax Credits 12.1 12.9
Excess of Tax Value Over Book Value <F2> 4.7 5.6
Other 8.9 9.0
---------------------------------------------------------------------------------------------------------------------------
Gross Deferred Tax Assets 158.3 147.0
Deferred Tax Asset Valuation Allowance (3.6) (4.1)
---------------------------------------------------------------------------------------------------------------------------
Total Deferred Tax Assets 154.7 142.9
---------------------------------------------------------------------------------------------------------------------------
Deferred Tax Liabilities
Property Related 204.7 210.8
Regulatory Asset for Benefit Obligations 34.8 -
Investment Tax Credits 17.2 18.3
Employee Benefits and Compensation 13.2 12.6
Fuel Clause Adjustment 6.0 5.4
Other 9.3 3.2
---------------------------------------------------------------------------------------------------------------------------
Total Deferred Tax Liabilities 285.2 250.3
---------------------------------------------------------------------------------------------------------------------------
Accumulated Deferred Income Taxes $130.5 $107.4
---------------------------------------------------------------------------------------------------------------------------
Recorded as:
Current Deferred Tax Assets $ 0.3 $ 31.0
Long-Term Deferred Tax Liabilities 130.8 138.4
---------------------------------------------------------------------------------------------------------------------------
Net Deferred Tax Liabilities $130.5 $107.4
---------------------------------------------------------------------------------------------------------------------------
<F1> Included Unfunded Employee Benefits
<F2> Included impairments related to the emerging technology portfolio.
|
81 ALLETE 2006 Form 10-K
NOTE 13. DISCONTINUED OPERATIONS
ENVENTIS TELECOM. On December 30, 2005, we sold all the stock of our telecommunications subsidiary, Enventis Telecom, to Hickory Tech Corporation of Mankato, Minnesota, for $35.5 million. The transaction resulted in an after-tax loss of $3.6 million, which was included in our 2005 loss from discontinued operations. Net cash proceeds realized from the sale were approximately $29 million after transaction costs, repayment of debt and payment of income taxes. In accordance with SFAS 144, "Accounting for the Impairment or Disposal of Long-Lived Assets," we have reported our telecommunications business in discontinued operations for all periods presented.
AUTOMOTIVE SERVICES. On September 20, 2004, the spin-off of Automotive Services was completed by distributing to ALLETE shareholders all of ALLETE's shares of ADESA common stock. One share of ADESA common stock was distributed for each outstanding share of ALLETE common stock held at the close of business on September 13, 2004, the record date. The distribution was made from ALLETE's retained earnings to the extent of ADESA's undistributed earnings ($363.4 million), with the remainder made from common stock ($600.2 million).
In June 2004, ADESA issued 6.3 million shares of common stock through an IPO priced at $24.00 per share, which netted proceeds of $136.0 million after transaction costs, issued $125 million of senior notes and borrowed $275 million under a new $525 million credit facility. With these funds, ADESA repaid previously existing debt and all intercompany debt outstanding to ALLETE. The IPO represented 6.6% of ADESA's 94.9 million shares then outstanding. As a result of the IPO, ALLETE recorded a $70.1 million increase to Common Stock with no gain recognized pursuant to SEC Staff Accounting Bulletin Topic 5H, "Accounting for Sales of Stock by a Subsidiary." We accounted for the 6.6% public ownership of ADESA as a minority interest and continued to own and consolidate the remaining portion of ADESA until the spin-off was completed on September 20, 2004.
In accordance with SFAS 144, "Accounting for the Impairment or Disposal of Long-Lived Assets," we have reported our Automotive Services business in Discontinued Operations.
WATER SERVICES. During 2003, we sold, under condemnation or imminent threat of condemnation, substantially all of our water assets in Florida for a total sales price of approximately $445 million. Income from discontinued operations for 2003 included a $71.6 million after-tax gain on the sale of substantially all our Water Services businesses. The gain was net of all selling, transaction and employee termination benefit expenses, as well as impairments on certain remaining assets.
In June 2004, we essentially concluded our strategy to exit our Water Services businesses when we completed the sale of our North Carolina water assets and the sale of the remaining 72 water and wastewater systems in Florida. Aqua Utilities Florida, Inc. (Aqua Utilities) purchased our North Carolina water assets for $48 million and assumed approximately $28 million in debt. Aqua Utilities also purchased 63 of our water and wastewater systems in Florida for $14 million. Seminole County purchased the remaining 9 Florida systems for a total of $4 million. The FPSC approved the Seminole County transaction in September 2004. On December 20, 2005, the FPSC ordered a $1.7 million reduction to plant investment, which the Company reserved for in 2005, and approved the transfer of the remaining 63 water and wastewater systems from Florida Water to Aqua Utilities. On March 15, 2006, the Company paid Aqua Utilities the adjustment refund amount of $1.7 million. Gains in 2004 from the sale of our North Carolina assets and the remaining systems in Florida were offset by an adjustment to gains reported in 2003, resulting in an overall net loss of $0.5 million in 2004. The adjustment to gains reported in 2003 resulted primarily from an arbitration award in December 2004 relating to a gain-sharing provision on a system sold in 2003; $5.1 million was recorded in 2004.
In February 2005, we completed the exit from our Water Services businesses with the sale of our wastewater assets in Georgia for an immaterial gain. In 2005, we also incurred administrative and other expenses to support Florida Water transfer proceedings and recorded the $1.7 million rate-base settlement charge related to the sale of 63 of Florida Water systems to Aqua Utilities mentioned above.
The net cash proceeds from the sale of all water assets in 2003 and 2004, after transaction costs, retirement of most Florida Water debt and payment of income taxes, were approximately $300 million. These net proceeds were used to retire debt at ALLETE.
In accordance with SFAS 144, "Accounting for the Impairment or Disposal of Long-Lived Assets," we suspended depreciating our Water Services assets when they were classified as held-for-sale in 2001. If we had not suspended depreciation, depreciation expense at our Water Services businesses would have been $2.6 million in 2004.
Financial results for 2006 reflected additional legal and administrative expenses incurred by the Company to exit the Water Services businesses.
ALLETE 2006 Form 10-K 82
NOTE 13. DISCONTINUED OPERATIONS (CONTINUED)
DISCONTINUED OPERATIONS
SUMMARY INCOME STATEMENT
FOR THE YEAR ENDED DECEMBER 31 2006 2005 2004
-------------------------------------------------------------------------------------------------------------------------
MILLIONS
Operating Revenue
Automotive Services - - $681.7
Water Services - - 18.5
Enventis Telecom - $50.7 47.3
-------------------------------------------------------------------------------------------------------------------------
Total Operating Revenue - $50.7 $747.5
-------------------------------------------------------------------------------------------------------------------------
Pre-Tax Income (Loss) from Operations
Automotive Services - - $132.5
Water Services - - (1.7)
Enventis Telecom - $ 3.0 1.0
-------------------------------------------------------------------------------------------------------------------------
- 3.0 131.8
-------------------------------------------------------------------------------------------------------------------------
Income Tax Expense (Benefit)
Automotive Services - - 54.0
Water Services - - (0.9)
Enventis Telecom - 1.2 0.4
-------------------------------------------------------------------------------------------------------------------------
- 1.2 53.5
-------------------------------------------------------------------------------------------------------------------------
Total Income from Operations - 1.8 78.3
-------------------------------------------------------------------------------------------------------------------------
Loss on Disposal
Automotive Services - - (6.7)
Water Services $(1.5) (4.5) 6.2
Enventis Telecom - 0.6 -
-------------------------------------------------------------------------------------------------------------------------
(1.5) (3.9) (0.5)
-------------------------------------------------------------------------------------------------------------------------
Income Tax Expense (Benefit)
Automotive Services - - (2.6)
Water Services (0.6) (2.0) 6.7
Enventis Telecom - 4.2 -
-------------------------------------------------------------------------------------------------------------------------
(0.6) 2.2 4.1
-------------------------------------------------------------------------------------------------------------------------
Net Loss on Disposal (0.9) (6.1) (4.6)
-------------------------------------------------------------------------------------------------------------------------
Income (Loss) from Discontinued Operations $(0.9) $(4.3) $ 73.7
-------------------------------------------------------------------------------------------------------------------------
|
DISCONTINUED OPERATIONS
SUMMARY BALANCE SHEET INFORMATION
DECEMBER 31 2005
-------------------------------------------------------------------------------------------------------------------------
MILLIONS
Assets of Discontinued Operations
Other Current Assets $0.4
Property, Plant and Equipment $2.2
Liabilities of Discontinued Operations
Current Liabilities $13.0
-------------------------------------------------------------------------------------------------------------------------
|
83 ALLETE 2006 Form 10-K
NOTE 14. OTHER COMPREHENSIVE INCOME (LOSS)
OTHER COMPREHENSIVE INCOME (LOSS) PRE-TAX TAX EXPENSE NET-OF-TAX
YEAR ENDED DECEMBER 31 AMOUNT (BENEFIT) AMOUNT
-------------------------------------------------------------------------------------------------------------------------
MILLIONS
2006
Unrealized Gain on Securities During the Year $ 2.5 $0.6 $1.9
Additional Pension Liability 11.0 4.6 6.4
-------------------------------------------------------------------------------------------------------------------------
Other Comprehensive Income $13.5 $5.2 $8.3
-------------------------------------------------------------------------------------------------------------------------
2005
Unrealized Gain on Securities During the Year $ 1.3 $ 0.7 $ 0.6
Additional Pension Liability (3.4) (1.4) (2.0)
-------------------------------------------------------------------------------------------------------------------------
Other Comprehensive Loss $(2.1) $(0.7) $(1.4)
-------------------------------------------------------------------------------------------------------------------------
2004
Unrealized Gain on Securities
Gain During the Year $ 13.1 $ 0.9 $ 12.2
Less: Gain Included in Net Income 11.5 - 11.5
-------------------------------------------------------------------------------------------------------------------------
Net Unrealized Gain on Securities 1.6 0.9 0.7
Foreign Currency Translation Adjustments (23.5) - (23.5)
Additional Pension Liability (5.7) (2.6) (3.1)
-------------------------------------------------------------------------------------------------------------------------
Other Comprehensive Loss $(27.6) $(1.7) $(25.9)
-------------------------------------------------------------------------------------------------------------------------
|
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) DECEMBER 31 2006 2005 ------------------------------------------------------------------------------------------------------------------------- MILLIONS Unrealized Gain on Securities $ 4.0 $ 2.1 Defined Benefit Pension and Other Postretirement Plans (12.8) - Additional Pension Liability - (14.9) ------------------------------------------------------------------------------------------------------------------------- Total Accumulated Other Comprehensive Loss $ (8.8) $(12.8) ------------------------------------------------------------------------------------------------------------------------- |
NOTE 15. CHANGE IN ACCOUNTING PRINCIPLE
In the third quarter of 2004 we adopted EITF 03-16, "Accounting for Investments in Limited Liability Companies," which requires the use of the equity method of accounting for investments in all limited liability companies, including investments we have in venture capital funds within our emerging technology portfolio. We had previously accounted for these investments under the cost method of accounting. EITF 03-16 is effective for reporting periods beginning after June 15, 2004. Pursuant to EITF 03-16, the effect of adoption is reported as the cumulative effect of a change in accounting principle. The cumulative effect of this change on prior years was a loss of $13.3 million ($7.8 million after-tax), which was recorded as a change in accounting principle and reflected in income for the year ended December 31, 2004. During 2006, $0.2 million of current losses after-tax under the equity method were recognized ($0 in 2005; $1.6 million loss in 2004).
ALLETE 2006 Form 10-K 84
NOTE 16. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS
We have noncontributory defined benefit pension plans covering eligible employees. The plans provide defined benefits based on years of service and final average pay. We also have defined contribution pension plans covering substantially all employees; employer contributions are made through our employee stock ownership plan (see Note 17), except for BNI Coal, which made cash contributions of $0.7 million in 2006 ($0.7 million in 2005; $0.6 million in 2004). In July 2006, we made an $8.3 million contribution to ALLETE's defined benefit plan.
On August 9, 2006, ALLETE's Board of Directors approved amendments to the Minnesota Power and Affiliated Companies Retirement Plan A (Retirement Plan A) and the Minnesota Power and Affiliated Companies Retirement Savings and Stock Ownership Plan (RSOP). Retirement Plan A was amended to suspend further crediting service pursuant to the plan, effective as of September 30, 2006, and to close Retirement Plan A to new participants. Participants will continue to accrue benefits under the plan for future pay increases. In conjunction with this change, the Board of Directors took action to increase benefits employees will receive under the RSOP. The modification of Retirement Plan A required us to re-measure our pension expense as of August 9, 2006. As a result of the re-measurement, Retirement Plan A pension expense for 2006 was reduced by $0.2 million.
We have postretirement health care and life insurance plans covering eligible employees. The postretirement health plans are contributory with participant contributions adjusted annually. Postretirement health and life benefits are funded through a combination of Voluntary Employee Benefit Association trusts (VEBAs), established under section 501(c)(9) of the Internal Revenue Code, and an irrevocable grantor trust. Contributions deductible for income tax purposes are made directly to the VEBAs; nondeductible contributions are made to the irrevocable grantor trust. Amounts are transferred from the irrevocable grantor trust to the VEBAs when they become deductible for income tax purposes. In December 2006, after the measurement date, $3.6 million was transferred from the grantor trust to the VEBAs ($11.4 million in 2005).
In September 2006, the FASB issued SFAS 158, "Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans" (SFAS 158). SFAS 158 requires that employers recognize on a prospective basis the funded status of their defined benefit pension and other postretirement plans on their consolidated balance sheet and recognize as a component of other comprehensive income, net of tax, the gains or losses and prior service costs or credits that arise during the period but that are not recognized as components of net periodic benefit cost. SFAS 158 also requires additional disclosures in the notes to financial statements. SFAS 158 is effective for fiscal years ending after December 15, 2006.
INCREMENTAL EFFECT OF APPLYING SFAS 158 SFAS 158 ON INDIVIDUAL LINE ITEMS IN THE BALANCE SHEET PRE- ADOPTION POST- YEAR ENDED DECEMBER 31, 2006 SFAS 158 ADJUSTMENTS SFAS 158 --------------------------------------------------------------------------------------------------------------------------- MILLIONS Prepayments and Other Current Assets $25.9 $(2.1) $23.8 Other Assets $48.9 $86.1 $135.0 Total Assets $1,449.4 $84.0 $1,533.4 Other Current Liabilities $24.3 - $24.3 Deferred Income Tax Liabilities $133.5 $(2.7) $130.8 Other Liabilities $135.4 $90.7 $226.1 Total Liabilities $779.6 $88.0 $867.6 Accumulated Other Comprehensive Loss - Net of Tax $(4.5) $(4.3) $(8.8) Total Shareholders' Equity $670.1 $(4.3) $665.8 --------------------------------------------------------------------------------------------------------------------------- |
Approximately 84% of the defined benefit pension and 71% of the postretirement health and life benefit costs recognized annually by our regulated companies are recovered through rates filed with our regulatory jurisdictions. It is expected that these costs will continue to be recovered in future rates in accordance with the requirements of SFAS 71. As a result, these amounts that are required to otherwise be recognized in accumulated other comprehensive income under the provisions of SFAS 158 have been recognized as a long-term regulatory asset on our consolidated balance sheet. The remaining 16% of the defined benefit pension and 29% of the postretirement health and life benefit costs relate to costs associated with our nonregulated operations and, accordingly, have been recognized as a charge to accumulated other comprehensive income at December 31, 2006.
85 ALLETE 2006 Form 10-K
NOTE 16. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (CONTINUED)
We use a September 30 measurement date for the pension and postretirement health and life plans. Pursuant to SFAS 158, we are required to change our measurement date to December 31 during the year ending December 31, 2008.
PENSION OBLIGATION AND FUNDED STATUS
AT SEPTEMBER 30 2006 2005
---------------------------------------------------------------------------------------------------------------------
MILLIONS
Change in Benefit Obligation
Obligation, Beginning of Year $412.4 $380.0
Service Cost 9.1 8.7
Interest Cost 22.2 21.3
Actuarial Loss (Gain) (12.2) 16.6
Benefits Paid (19.8) (18.9)
Other 6.0 4.7
---------------------------------------------------------------------------------------------------------------------
Obligation, End of Year 417.7 412.4
---------------------------------------------------------------------------------------------------------------------
Change in Plan Assets
Fair Value, Beginning of Year 337.1 310.1
Actual Return on Assets 32.5 40.6
Employer Contribution 8.9 0.6
Benefits Paid (19.8) (18.9)
Other 6.0 4.7
---------------------------------------------------------------------------------------------------------------------
Fair Value, End of Year 364.7 337.1
---------------------------------------------------------------------------------------------------------------------
Funded Status $(53.0) (75.3)
------
Amounts
Net Loss 90.6
Prior Service Cost 4.5
Transition Obligation (0.1)
---------------------------------------------------------------------------------------------------------------------
Net Assets Recognized $ 19.7
---------------------------------------------------------------------------------------------------------------------
Amounts Recognized in Consolidated Balance Sheet Consist of:
Prepaid Pension Cost $33.8
Accrued Benefit Liability (42.3)
Intangible Assets 2.3
Accumulated Other Comprehensive Income 25.9
---------------------------------------------------------------------------------------------------------------------
Net Assets Recognized $19.7
---------------------------------------------------------------------------------------------------------------------
|
The pension costs reported on our consolidated balance sheet as regulatory long-term assets and accumulated other comprehensive income consist of the following:
PENSION COSTS
YEAR ENDED DECEMBER 31 2006
---------------------------------------------------------------------------------------------------------------------
MILLIONS
Net Loss $69.9
Prior Service Cost 3.9
Transition Obligation (0.1)
---------------------------------------------------------------------------------------------------------------------
$73.7
---------------------------------------------------------------------------------------------------------------------
|
ALLETE 2006 Form 10-K 86
NOTE 16. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (CONTINUED)
COMPONENTS OF NET PERIODIC PENSION EXPENSE (INCOME)
YEAR ENDED DECEMBER 31 2006 2005 2004
---------------------------------------------------------------------------------------------------------------------------
MILLIONS
Service Cost $ 9.1 $ 8.7 $ 8.4
Interest Cost 22.2 21.3 20.7
Expected Return on Assets (28.6) (28.2) (27.4)
Amortized Amounts
Loss 4.6 3.1 1.4
Prior Service Cost 0.6 0.6 0.8
Transition Obligation - 0.2 0.3
---------------------------------------------------------------------------------------------------------------------------
Net Pension Expense $ 7.9 $ 5.7 $ 4.2
---------------------------------------------------------------------------------------------------------------------------
|
INFORMATION FOR PENSION PLANS WITH AN ACCUMULATED BENEFIT OBLIGATION IN EXCESS OF PLAN ASSETS AT SEPTEMBER 30 2006 2005 --------------------------------------------------------------------------------------------------------------------------- MILLIONS Projected Benefit Obligation $180.4 $177.5 Accumulated Benefit Obligation $160.6 $157.7 Fair Value of Plan Assets $130.9 $116.3 --------------------------------------------------------------------------------------------------------------------------- |
ADDITIONAL PENSION INFORMATION
YEAR ENDED DECEMBER 31 2006 2005 2004
---------------------------------------------------------------------------------------------------------------------------
MILLIONS
Increase (Decrease) in Additional Pension Liability
Included in Other Comprehensive Income $11.0 $(3.4) $(5.7)
---------------------------------------------------------------------------------------------------------------------------
|
The accumulated benefit obligation for all defined benefit pension plans was $376.1 million and $369.5 million at September 30, 2006 and 2005, respectively.
POSTRETIREMENT HEALTH AND LIFE OBLIGATION AND FUNDED STATUS
AT SEPTEMBER 30 2006 2005
---------------------------------------------------------------------------------------------------------------------------
MILLIONS
Change in Benefit Obligation
Obligation, Beginning of Year $136.9 $117.2
Service Cost 4.4 4.0
Interest Cost 7.4 6.6
Actuarial Loss (Gain) (4.7) 13.1
Participation Contributions 1.4 1.3
Benefits Paid (6.4) (5.3)
Amendments (0.1) -
---------------------------------------------------------------------------------------------------------------------------
Obligation, End of Year 138.9 136.9
---------------------------------------------------------------------------------------------------------------------------
Change in Plan Assets
Fair Value, Beginning of Year 60.9 54.1
Actual Return on Assets 5.8 7.1
Employer Contribution 17.2 3.6
Participation Contributions 1.4 1.4
Benefits Paid (6.4) (5.3)
---------------------------------------------------------------------------------------------------------------------------
Fair Value, End of Year 78.9 60.9
---------------------------------------------------------------------------------------------------------------------------
Funded Status $(60.0) (76.0)
------
Amounts
Net Loss 25.8
Transition Obligation 17.4
---------------------------------------------------------------------------------------------------------------------------
Net Liabilities Recognized $(32.8)
---------------------------------------------------------------------------------------------------------------------------
|
87 ALLETE 2006 Form 10-K
NOTE 16. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (CONTINUED)
Under SFAS 106, "Employers' Accounting for Postretirement Benefits Other Than Pensions," only assets in the VEBAs are treated as plan assets in the previous table for the purpose of determining funded status. In addition to the postretirement health and life assets reported in the previous table, we had $25.6 million in an irrevocable grantor trust at December 31, 2006 ($22.6 million at December 31, 2005). We consolidate the irrevocable grantor trust and it is included in Investments on our consolidated balance sheet.
The postretirement health and life costs reported on our consolidated balance sheet as regulatory long-term assets and accumulated other comprehensive income consist of the following:
POSTRETIREMENT HEALTH AND LIFE COSTS
YEAR ENDED DECEMBER 31 2006
---------------------------------------------------------------------------------------------------------------------------
MILLIONS
Net Loss $19.2
Prior Service Cost (0.1)
Transition Obligation 15.0
---------------------------------------------------------------------------------------------------------------------------
$34.1
---------------------------------------------------------------------------------------------------------------------------
|
COMPONENTS OF NET PERIODIC POSTRETIREMENT HEALTH AND LIFE EXPENSE
YEAR ENDED DECEMBER 31 2006 2005 2004
---------------------------------------------------------------------------------------------------------------------------
MILLIONS
Service Cost $ 4.4 $4.0 $3.9
Interest Cost 7.4 6.7 6.6
Expected Return on Assets (5.6) (4.8) (4.6)
Amortized Amounts
Loss 1.7 0.7 0.4
Transition Obligation 2.4 2.4 2.4
---------------------------------------------------------------------------------------------------------------------------
Net Expense $10.3 $9.0 $8.7
---------------------------------------------------------------------------------------------------------------------------
|
POSTRETIREMENT
ESTIMATED FUTURE BENEFIT PAYMENTS PENSION HEALTH AND LIFE
---------------------------------------------------------------------------------------------------------------------------
MILLIONS
2007 $20 $5
2008 $21 $5
2009 $22 $6
2010 $22 $7
2011 $23 $7
Years 2012 - 2016 $138 $45
---------------------------------------------------------------------------------------------------------------------------
|
The pension and postretirement health and life costs recorded in other long-term assets and accumulated other comprehensive income expected to be recognized as a component of net pension and postretirement benefit costs for the year ending December 31, 2007, are as follows:
POSTRETIREMENT
PENSION HEALTH AND LIFE
---------------------------------------------------------------------------------------------------------------------------
MILLIONS
Net Loss (Gain) $3.4 $0.9
Prior Service Costs $0.7 -
Transition Obligations $(0.1) $2.5
---------------------------------------------------------------------------------------------------------------------------
|
ALLETE 2006 Form 10-K 88
NOTE 16. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (CONTINUED)
WEIGHTED-AVERAGE ASSUMPTIONS
USED TO DETERMINE BENEFIT OBLIGATION
AT SEPTEMBER 30 2006 2005
---------------------------------------------------------------------------------------------------------------------------
Discount Rate 5.75% 5.50%
Rate of Compensation Increase 3.5 - 4.5% 3.5 - 4.5%
Health Care Trend Rates
Trend Rate 10% 10%
Ultimate Trend Rate 5% 5%
Year Ultimate Trend Rate Effective 2011 2010
---------------------------------------------------------------------------------------------------------------------------
|
WEIGHTED-AVERAGE ASSUMPTIONS
USED TO DETERMINE NET PERIODIC BENEFIT COSTS
YEAR ENDED DECEMBER 31 2006 2005 2004
---------------------------------------------------------------------------------------------------------------------------
Discount Rate 5.50% 5.75% 6.00%
Expected Long-Term Return on Plan Assets
Pension 9.0% 9.0% 9.0%
Postretirement Health and Life 5.0 - 9.0% 5.0 - 9.0% 7.2 - 9.0%
Rate of Compensation Increase 3.5 - 4.5% 3.5 - 4.5% 3.5 - 4.5%
---------------------------------------------------------------------------------------------------------------------------
|
In establishing the expected long-term return on plan assets, we consider the diversification and allocation of plan assets, the actual long-term historical performance for the type of securities invested in, the actual long-term historical performance of plan assets and the impact of current economic conditions, if any, on long-term historical returns.
Currently for plan valuation purposes, the discount rate is determined considering high-quality long-term corporate bond rates at the valuation date. The discount rate is compared to the Citigroup Pension Discount Curve adjusted for ALLETE's specific cash flows.
SENSITIVITY OF A ONE-PERCENTAGE-POINT ONE PERCENT ONE PERCENT CHANGE IN HEALTH CARE TREND RATES INCREASE DECREASE --------------------------------------------------------------------------------------------------------------------------- MILLIONS Effect on Total of Postretirement Health and Life Service and Interest Cost $1.9 $(1.5) Effect on Postretirement Health and Life Obligation $17.5 $(14.3) --------------------------------------------------------------------------------------------------------------------------- |
POSTRETIREMENT
PENSION HEALTH AND LIFE <F1>
PLAN ASSET ALLOCATIONS 2006 2005 2006 2005
---------------------------------------------------------------------------------------------------------------------------
Equity Securities 65.1% 64.9% 68.9% 68.6%
Debt Securities 29.6 29.6 30.6 30.5
Real Estate 0.8 1.3 - -
Venture Capital 4.2 2.9 - -
Cash 0.3 1.3 0.5 0.9
---------------------------------------------------------------------------------------------------------------------------
100.0% 100.0% 100.0% 100.0%
---------------------------------------------------------------------------------------------------------------------------
<F1> Included VEBAs and irrevocable grantor trust.
|
Pension plan equity securities did not include ALLETE common stock at September 30, 2006, or September 30, 2005.
To achieve strong returns within managed risk, we diversify our asset portfolio to approximate the target allocations in the table below. Equity securities are diversified among domestic companies with large, mid and small market capitalizations, as well as investments in international companies. In addition, all debt securities must have a Standard & Poor's credit rating of A or higher.
89 ALLETE 2006 Form 10-K
NOTE 16. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (CONTINUED)
POSTRETIREMENT
PLAN ASSET TARGET ALLOCATIONS PENSION HEALTH AND LIFE <F1>
---------------------------------------------------------------------------------------------------------------------------
Equity Securities 60% 69%
Debt Securities 24 30
Real Estate 9 -
Venture Capital 6 -
Cash 1 1
---------------------------------------------------------------------------------------------------------------------------
100% 100%
---------------------------------------------------------------------------------------------------------------------------
<F1> Included VEBAs and irrevocable grantor trust.
|
We expect to contribute approximately $6 million to our postretirement health and life plans in 2007. We are not required to make any contributions to our defined benefit pension plans in 2007.
In May 2004, the FASB issued FSP 106-2, "Accounting and Disclosure Requirements Related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003 (Act)," which provides accounting and disclosure guidance for employers that sponsor postretirement health care plans that provide prescription drug benefits. FSP 106-2 requires that the accumulated postretirement benefit obligation and postretirement benefit cost reflect the impact of the Act upon adoption. We provide postretirement health benefits that include prescription drug benefits and have concluded that our prescription drug benefits will qualify us for the federal subsidy to be provided for under the Act. We adopted FSP 106-2 in the third quarter of 2004. The deduction for Medicare health subsidies reduced our after-tax postretirement medical expense by $2.4 million for 2006 ($3.5 million in 2005; $1.6 million for 2004).
In 2005, we determined that our postretirement health care plans meet the requirements of the Centers for Medicare and Medicaid Services' (CMS) regulations, and enrolled with the CMS to begin recovering the subsidy. We expect to receive the first subsidy payment in mid-2007 for 2006 credits.
NOTE 17. EMPLOYEE STOCK AND INCENTIVE PLANS
EMPLOYEE STOCK OWNERSHIP PLAN. We sponsor a leveraged employee stock ownership plan (ESOP) within the Retirement Savings and Stock Ownership Plan (RSOP) that covers certain eligible employees. In 1989, the ESOP used the proceeds from a $16.5 million third-party loan, guaranteed by us, to purchase 0.6 million shares (0.4 million shares adjusted for stock splits) of our common stock on the open market. This loan was fully repaid in 2004, and all shares originally purchased with loan proceeds have been allocated to participants. In 1990, the ESOP issued a $75 million note (term not to exceed 25 years at 10.25%) to us as consideration for 2.8 million shares (1.9 million shares adjusted for stock splits) of our newly issued common stock. The note was refinanced in 2006 at 6%. The Company makes annual contributions to the ESOP equal to the ESOP's debt service less available dividends received by the ESOP. The majority of dividends received by the ESOP are used to pay debt service, with the balance distributed to participants. The ESOP shares were initially pledged as collateral for its debt. As the debt is repaid, shares are released from collateral and allocated to participants based on the proportion of debt service paid in the year. As shares are released from collateral, the Company reports compensation expense equal to the current market price of the shares less dividends on allocated shares. Dividends on allocated ESOP shares are recorded as a reduction of retained earnings; available dividends on unallocated ESOP shares are recorded as a reduction of debt and accrued interest. ESOP compensation expense was $4.6 million in 2006 ($5.5 million in 2005; $5.0 million in 2004).
As a result of the September 2004 spin-off of ADESA, the ESOP received 3.3 million shares of ADESA common stock related to unearned ESOP shares that had not been allocated to participants. The ESOP was required to sell the ADESA common stock and use the proceeds to purchase ALLETE common stock on the open market. At December 31, 2004, the ESOP had sold all of these ADESA shares. The 3.3 million ADESA shares sold by the ESOP in 2004 resulted in total proceeds of $65.9 million and an after-tax gain of $11.5 million, which we recognized in the fourth quarter of 2004. (See Note 11.) Under the direction of an independent trustee, the ESOP used the proceeds to purchase shares of ALLETE common stock in late 2004 and early 2005, which were recorded using the treasury method as Unearned ESOP Shares within Shareholders' Equity as presented on our consolidated balance sheet.
SUMMARY OF ALLETE COMMON STOCK PURCHASES SHARES AMOUNT
-----------------------------------------------------------------------------------------------------------------------
MILLIONS EXCEPT SHARES
2004 October 80,600 $ 2.7
November 669,578 23.5
December 262,600 9.4
2005 January 544,797 21.4
February 214,928 8.9
-----------------------------------------------------------------------------------------------------------------------
1,772,503 $65.9
-----------------------------------------------------------------------------------------------------------------------
|
ALLETE 2006 Form 10-K 90
NOTE 17. EMPLOYEE STOCK AND INCENTIVE PLANS (CONTINUED)
In September 2005, the ESOP's independent trustee directed the sale of approximately 1.4 million shares of ADESA common stock that remained invested in the RSOP participants' ADESA common stock funds at September 1, 2005. Proceeds from the sale of the ADESA common stock were $30.4 million, of which the majority was used to purchase ALLETE common stock as required by the terms of the RSOP. The process was completed on October 26, 2005. Proceeds totaling $28.5 million were used to purchase a total of 644,450 shares of ALLETE common stock (289,900 shares in September 2005; 354,550 shares in October 2005).
Pursuant to AICPA Statement of Position 93-6, "Employers' Accounting for Employee Stock Ownership Plans," unallocated ALLETE common stock currently held and purchased by the ESOP will be treated as unearned ESOP shares and not considered as outstanding for earnings per share computations. ESOP shares are included in earnings per share computations after they are allocated to participants.
YEAR ENDED DECEMBER 31 2006 2005 2004
---------------------------------------------------------------------------------------------------------------------------
MILLIONS
ESOP Shares
Allocated 1.7 1.9 1.4
Unallocated 2.5 2.6 2.0
---------------------------------------------------------------------------------------------------------------------------
Total 4.2 4.5 3.4
---------------------------------------------------------------------------------------------------------------------------
Fair Value of Unallocated Shares $115.2 $115.0 $72.7
---------------------------------------------------------------------------------------------------------------------------
|
STOCK-BASED COMPENSATION. Effective January 1, 2006, we adopted the fair value recognition provisions of SFAS 123R, "Share-Based Payment," using the modified prospective transition method. Under this method, we recognize compensation expense for all share-based payments granted after January 1, 2006, and those granted prior to but not yet vested as of January 1, 2006. Under the fair value recognition provisions of SFAS 123R, we recognize stock-based compensation net of an estimated forfeiture rate and only recognize compensation expense for those shares expected to vest over the required service period of the award. Prior to our adoption of SFAS 123R, we accounted for share-based payments under Accounting Principles Board Opinion No. 25, "Accounting for Stock Issued to Employees" and related interpretations.
STOCK INCENTIVE PLAN. Under our Executive Long-Term Incentive Compensation Plan (Executive Plan), share-based awards may be issued to key employees via a broad range of methods, including non-qualified and incentive stock options, performance shares, performance units, restricted stock, stock appreciation rights and other awards. There are 3.2 million shares of common stock reserved for issuance under the Executive Plan, with 1.5 million of these shares available for issuance as of December 31, 2006.
We had a Director Long-Term Stock Incentive Plan (Director Plan) which expired on January 1, 2006. No grants have been made since 2003 under the Director Plan. Approximately 9,000 options were outstanding under the Director Plan at December 31, 2006.
We currently have the following types of share-based awards outstanding:
NON-QUALIFIED STOCK OPTIONS. The options allow for the purchase of shares of common stock at a price equal to the market value of our common stock at the date of grant. Options become exercisable beginning one year after the grant date, with one-third vesting each year over three years. Options may be exercised up to ten years following the date of grant. In the case of qualified retirement, death or disability, options vest immediately and the period over which the options can be exercised is three years. Employees have up to three months to exercise vested options upon voluntary termination or involuntary termination without cause. All options are cancelled upon termination for cause. All options vest immediately upon retirement, death, disability or a change of control, as defined in the award agreement. We determine the fair value of options using the Black-Scholes option-pricing model. The estimated fair value of options, including the effect of estimated forfeitures, is recognized as expense on the straight-line basis over the options' vesting periods, or the accelerated vesting period if the employee is retirement eligible.
The following assumptions were used in determining the fair value of stock options granted during 2006, under the Black-Scholes option-pricing model:
2006
--------------------------------------------------------------------------------
Risk-Free Interest Rate 4.5%
Expected Life 5 Years
Expected Volatility 20%
Dividend Growth Rate 5%
--------------------------------------------------------------------------------
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91 ALLETE 2006 Form 10-K
NOTE 17. EMPLOYEE STOCK AND INCENTIVE PLANS (CONTINUED)
The risk-free interest rate for periods within the contractual life of the option is based on the U.S. Treasury yield curve in effect at the grant date. Expected volatility is estimated based on the historic volatility of our stock and the stock of our peer group companies. We utilize historical option exercise and employee pre-vesting termination data to estimate the option life. The dividend growth rate is based upon historic growth rates in our dividends.
PERFORMANCE SHARES. Under these awards, the number of shares earned is contingent upon attaining specific performance targets over a three-year performance period. In the case of qualified retirement, death or disability during a performance period, a pro-rata portion of the award will be earned at the conclusion of the performance period based on the performance goals achieved. In the case of termination of employment for any reason other than qualified retirement, death or disability, no award will be earned. If there is a change in control, a pro-rata portion of the award will be paid based on the greater of actual performance up to the date of the change in control or target performance. The fair value of these awards is equal to the grant date fair value which is estimated based upon the assumed share-based payment three years from the date of grant. Compensation cost is recognized over the three-year performance period based on our estimate of the number of shares which will be earned by the award recipients.
EMPLOYEE STOCK PURCHASE PLAN (ESPP). Under our ESPP, eligible employees may purchase ALLETE common stock at a 5% discount from the market price. Because the discount is not greater than 5%, we are not required by SFAS 123R to apply fair value accounting to these awards.
RSOP. Shares held in our RSOP are excluded from SFAS 123R and are accounted for in accordance with the American Institute of Certified Public Accountants' Statement of Position No. 93-6, "Employers' Accounting for Employee Stock Ownership Plans."
The following share-based compensation expense amounts were recognized in our consolidated statement of income for the periods presented since our adoption of SFAS 123R.
SHARE-BASED COMPENSATION EXPENSE FOR THE YEAR ENDED DECEMBER 31 2006 ----------------------------------------------------------------------------------------------------------------------- MILLIONS Stock Options $0.8 Performance Shares 1.0 ----------------------------------------------------------------------------------------------------------------------- Total Share-Based Compensation Expense $1.8 ----------------------------------------------------------------------------------------------------------------------- Income Tax Benefit $0.7 ----------------------------------------------------------------------------------------------------------------------- |
There were no capitalized stock-based compensation costs at December 31, 2006.
As of December 31, 2006, the total unrecognized compensation cost for performance share awards not yet recognized in our statements of income was $1.3 million. This amount is expected to be recognized over a weighted-average period of 1.31 years.
The following table presents the pro forma effect of stock-based compensation had we applied the provisions of SFAS 123 for the years ended December 31, 2005 and 2004.
PRO FORMA EFFECT OF SFAS 123
ACCOUNTING FOR STOCK-BASED COMPENSATION 2005 2004
-----------------------------------------------------------------------------------------------------------------------
MILLIONS EXCEPT PER SHARE AMOUNTS
Net Income
As Reported $13.3 $104.4
Less: Employee Stock Compensation Expense
Determined Under SFAS 123 - Net of Tax 1.5 1.3
Plus: Employee Stock Compensation Expense
Included in Net Income - Net of Tax 1.5 1.0
-----------------------------------------------------------------------------------------------------------------------
Pro Forma Net Income $13.3 $104.1
-----------------------------------------------------------------------------------------------------------------------
Basic Earnings Per Share
As Reported $0.49 $3.69
Pro Forma $0.49 $3.68
Diluted Earnings Per Share
As Reported $0.48 $3.67
Pro Forma $0.48 $3.66
-----------------------------------------------------------------------------------------------------------------------
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ALLETE 2006 Form 10-K 92
NOTE 17. EMPLOYEE STOCK AND INCENTIVE PLANS (CONTINUED)
In the previous table, the pro forma expense determined under SFAS 123 for employee stock options granted was calculated using the Black-Scholes option-pricing model with the following assumptions:
2005 2004
-----------------------------------------------------------------------------------------------------------------------
Risk-Free Interest Rate 3.7% 3.3%
Expected Life 5 Years 5 Years
Expected Volatility 20.0% 28.1%
Dividend Growth Rate 5% 2%
-----------------------------------------------------------------------------------------------------------------------
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The following table presents information regarding our outstanding stock options for the year ended December 31, 2006.
WEIGHTED-AVERAGE
WEIGHTED-AVERAGE AGGREGATE REMAINING
NUMBER OF EXERCISE INTRINSIC CONTRACTUAL
OPTIONS PRICE VALUE TERM
--------------------------------------------------------------------------------------------------------------------------
MILLIONS
Outstanding at December 31, 2005 357,827 $34.29 $3.5 7.4 years
Granted 115,653 $44.15
Exercised (28,896) $26.47
Forfeited (6,233) $38.25
--------------------------------------------------------------------------------------------------------------------------
Outstanding at December 31, 2006 438,351 $37.35 $4.0 7.2 years
--------------------------------------------------------------------------------------------------------------------------
Exercisable at December 31, 2006 238,640 $33.18 $3.2 6.2 years
--------------------------------------------------------------------------------------------------------------------------
Fair Value of Options
Granted During the Year $7.28
--------------------------------------------------------------------------------------------------------------------------
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The weighted-average grant-date fair value of options was $6.48 for 2006. The intrinsic value of a stock award is the amount by which the fair value of the underlying stock exceeds the exercise price of the award. The total intrinsic value of options exercised was $0.6 million during 2006.
At December 31, 2006, options outstanding consisted of less than 0.1 million with exercise prices ranging from $15.88 to $19.21, 0.1 million with exercise prices ranging from $23.79 to $27.40 and 0.3 million with exercise prices ranging from $35.78 to $41.35. The options with exercise prices ranging from $23.79 to $27.40 have an average remaining contractual life of 4.8 years, with 0.1 million exercisable on December 31, 2006, at a weighted average price of $25.32. The options with exercise prices ranging from $35.78 to $41.35 have an average remaining contractual life of 7.7 years, with 0.2 million exercisable on December 31, 2006, at a weighted average price of $39.29.
2005
--------------------------
WEIGHTED
AVERAGE
EXERCISE
STOCK OPTION ACTIVITY OPTIONS PRICE
--------------------------------------------------------------------------------------------------------------------------
Outstanding, Beginning of Year 437,965 $28.94
Granted 119,077 $41.35
Exercised (199,215) $26.74
Forfeited - -
--------------------------------------------------------------------------------------------------------------------------
Outstanding, End of Year 357,827 $34.29
--------------------------------------------------------------------------------------------------------------------------
Exercisable, End of Year 178,332 $28.35
Fair Value of Options Granted During the Year $6.51
--------------------------------------------------------------------------------------------------------------------------
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93 ALLETE 2006 Form 10-K
NOTE 17. EMPLOYEE STOCK AND INCENTIVE PLANS (CONTINUED)
2004
--------------------------
WEIGHTED
AVERAGE
EXERCISE
STOCK OPTION ACTIVITY <F1> OPTIONS PRICE
--------------------------------------------------------------------------------------------------------------------------
Outstanding, Beginning of Period 760,026 $64.47
Granted 39,759 $97.65
Exercised (295,359) $67.14
Forfeited (7,396) $63.06
--------------------------------------------------------------------------------------------------------------------------
Outstanding, End of Period 497,030 $69.85
--------------------------------------------------------------------------------------------------------------------------
Exercisable, End of Period - -
Fair Value of Options Granted During the Period $20.01
--------------------------------------------------------------------------------------------------------------------------
<F1> All amounts above are prior to the ADESA spin-off and the historical option and weighted average exercise prices
have been adjusted for the one-for-three reverse stock split on September 20, 2004. The 2004 amounts are up to the
September 20, 2004, spin-off of ADESA.
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2004
--------------------------
WEIGHTED
AVERAGE
EXERCISE
STOCK OPTION ACTIVITY <F1> OPTIONS PRICE
--------------------------------------------------------------------------------------------------------------------------
Outstanding as of September 20, 2004, after spin-off 478,054 $28.56
Granted - -
Exercised (40,089) $24.40
Forfeited - -
--------------------------------------------------------------------------------------------------------------------------
Outstanding, End of Year 437,965 $28.94
--------------------------------------------------------------------------------------------------------------------------
Exercisable, End of Year 287,711 $26.57
--------------------------------------------------------------------------------------------------------------------------
<F1> Amounts subsequent to the ADESA spin-off.
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The employee stock options outstanding at the date of the ADESA spin-off were converted to reflect the spin-off and one-for-three reverse stock split. This conversion was done to preserve the noncompensatory nature of the options under FASB Interpretation No. 44, "Accounting for Certain Transactions Involving Stock Compensation."
In February 2007, we granted stock options to purchase 0.1 million shares of common stock (exercise price of $48.65 per share).
PERFORMANCE SHARES. The following table presents information regarding our nonvested performance shares for the year ended December 31, 2006.
WEIGHTED-AVERAGE
NUMBER OF GRANT DATE
SHARES FAIR VALUE
--------------------------------------------------------------------------------------------------------------------------
Nonvested at December 31, 2005 97,884 $38.63
Granted 26,967 $43.87
Awarded (49,076) $37.76
Forfeited (4,771) $41.53
--------------------------------------------------------------------------------------------------------------------------
Nonvested at December 31, 2006 71,004 $41.03
--------------------------------------------------------------------------------------------------------------------------
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Less than 0.1 million performance share grants were awarded in February 2006 for performance periods ending in 2008. The ultimate issuance is contingent upon the attainment of certain future performance goals of ALLETE during the performance periods. The grant date fair value of the performance share awards was $1.0 million.
Less than 0.1 million performance share grants were awarded in February 2005 for the performance periods ending in 2007. The grant date fair value of the share awards was $1.0 million. Performance share grants related to the 2006 period will be issued in early 2007.
EMPLOYEE STOCK PURCHASE PLAN. We have an Employee Stock Purchase Plan that permits eligible employees to buy up to $23,750 per year of our common stock at 95% of the market price. At December 31, 2006, 0.5 million shares had been issued under the plan and 0.1 million shares were held in reserve for future issuance.
ALLETE 2006 Form 10-K 94
NOTE 18. 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 the second quarter of 2005 included a $50.4 million, or $1.84 per share, charge related to the assignment of the Kendall County purchase power agreement. (See Note 10.) Financial results for the fourth quarter of 2005 included a $2.5 million, or $0.09 per share, deferred tax benefit due to comprehensive state tax planning initiatives and a $3.7 million, or $0.13 per share, current tax benefit due to a positive resolution of income tax audit issues.
QUARTER ENDED MAR. 31 JUN. 30 SEPT. 30 DEC. 31
--------------------------------------------------------------------------------------------------------------------------
MILLIONS EXCEPT EARNINGS PER SHARE
2006
Operating Revenue $192.5 $178.3 $199.1 $197.2
--------------------------------------------------------------------------------------------------------------------------
Operating Income from Continuing Operations $36.4 $26.3 $38.7 $39.3
--------------------------------------------------------------------------------------------------------------------------
Income (Loss) Continuing Operations $18.8 $13.6 $21.9 $23.0
Discontinued Operations - (0.4) (0.1) (0.4)
--------------------------------------------------------------------------------------------------------------------------
Net Income $18.8 $13.2 $21.8 $22.6
--------------------------------------------------------------------------------------------------------------------------
Earnings (Loss) Per Share of Common Stock
Basic Continuing Operations $0.68 $0.50 $0.78 $0.82
Discontinued Operations - (0.02) - (0.01)
--------------------------------------------------------------------------------------------------------------------------
$0.68 $0.48 $0.78 $0.81
--------------------------------------------------------------------------------------------------------------------------
Diluted Continuing Operations $0.68 $0.49 $0.78 $0.82
Discontinued Operations - (0.02) - (0.01)
--------------------------------------------------------------------------------------------------------------------------
$0.68 $0.47 $0.78 $0.81
--------------------------------------------------------------------------------------------------------------------------
2005
Operating Revenue $193.3 $174.4 $177.4 $192.3
--------------------------------------------------------------------------------------------------------------------------
Operating Income (Loss) from Continuing Operations $41.1 $(56.0) $32.7 $27.3
--------------------------------------------------------------------------------------------------------------------------
Income (Loss) Continuing Operations $17.4 $(39.8) $15.8 $24.2
Discontinued Operations - (0.5) (0.6) (3.2)
--------------------------------------------------------------------------------------------------------------------------
Net Income (Loss) $17.4 $(40.3) $15.2 $21.0
--------------------------------------------------------------------------------------------------------------------------
Earnings (Loss) Per Share of Common Stock
Basic Continuing Operations $0.64 $(1.46) $0.58 $0.89
Discontinued Operations - (0.02) (0.02) (0.12)
--------------------------------------------------------------------------------------------------------------------------
$0.64 $(1.48) $0.56 $0.77
--------------------------------------------------------------------------------------------------------------------------
Diluted Continuing Operations $0.64 $(1.46) $0.58 $0.88
Discontinued Operations - (0.02) (0.02) (0.12)
--------------------------------------------------------------------------------------------------------------------------
$0.64 $(1.48) $0.56 $0.76
--------------------------------------------------------------------------------------------------------------------------
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95 ALLETE 2006 Form 10-K
SCHEDULE II
ALLETE
VALUATION AND QUALIFYING ACCOUNTS AND RESERVES
BALANCE AT ADDITIONS DEDUCTIONS BALANCE AT
BEGINNING CHARGED OTHER FROM END OF
FOR THE YEAR ENDED DECEMBER 31 OF YEAR TO INCOME CHANGES RESERVES <F1> PERIOD
--------------------------------------------------------------------------------------------------------------------------
MILLIONS
Reserve Deducted from Related Assets
Reserve For Uncollectible Accounts
2006 Trade Accounts Receivable $1.0 $0.7 - $0.6 $1.1
Finance Receivables - Long-Term 0.6 - - 0.4 0.2
2005 Trade Accounts Receivable 1.0 1.1 - 1.1 1.0
Finance Receivables - Long-Term 0.7 - - 0.1 0.6
2004 Trade Accounts Receivable 1.1 0.9 - 1.0 1.0
Finance Receivables - Long-Term 1.2 - - 0.5 0.7
Deferred Asset Valuation Allowance
2006 Deferred Tax Assets 4.1 (1.1) $0.6 - 3.6
2005 Deferred Tax Assets 1.1 3.8 - 0.8 4.1
2004 Deferred Tax Assets 0.2 0.9 - - 1.1
--------------------------------------------------------------------------------------------------------------------------
<F1> Included uncollectible accounts written off.
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ALLETE 2006 Form 10-K 96
EXHIBIT INDEX
EXHIBIT NUMBER
4(a)3 - Twenty-Sixth Supplemental Indenture, dated as of October 1,
2006, between ALLETE and The Bank of New York and Douglas J.
MacInnes, as Trustees.
10(d)3 - Second Amendment to Fourth Amended and Restated Committed
Facility Letter dated December 14, 2006, by and among ALLETE
and LaSalle Bank National Association, as Agent.
10(h)4 - January 2007 Amendment to the ALLETE Executive Annual
Incentive Plan.
10(h)7 - Form of ALLETE Executive Annual Incentive Plan Awards
Effective 2007.
10(i)4 - December 2006 Amendments to the ALLETE and Affiliated
Companies Supplemental Executive Retirement Plan.
10(m)6 - Form of ALLETE Executive Long-Term Incentive Compensation Plan
Nonqualified Stock Option Grant Effective 2007.
10(m)7 - Form of ALLETE Executive Long-Term Incentive Compensation Plan
Performance Share Grant Effective 2007.
10(m)8 - Form of ALLETE Executive Long-Term Incentive Compensation Plan
Long-Term Cash Incentive Award Effective 2007.
10(m)9 - Form of ALLETE Executive Long-Term Incentive Compensation Plan
Stock Grant Effective 2007.
10(n)4 - January 2007 Amendment to the ALLETE Director Stock Plan.
10(n)6 - ALLETE Non-Management Director Compensation Summary Effective
February 15, 2007.
12 - Computation of Ratios of Earnings to Fixed Charges.
21 - Subsidiaries of the Registrant.
23(a) - Consent of Independent Registered Public Accounting Firm.
23(b) - Consent of General Counsel.
31(a) - Rule 13a-14(a)/15d-14(a) Certification by the Chief Executive
Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of
2002.
31(b) - Rule 13a-14(a)/15d-14(a) Certification by the Chief Financial
Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of
2002.
32 - Section 1350 Certification of Annual Report by the Chief
Executive Officer and Chief Financial Officer Pursuant to
Section 906 of the Sarbanes-Oxley Act of 2002.
99 - ALLETE News Release dated February 16, 2007, announcing 2006
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earnings. (THIS EXHIBIT HAS BEEN FURNISHED AND SHALL NOT BE DEEMED "FILED" FOR PURPOSES OF SECTION 18 OF THE SECURITIES EXCHANGE ACT OF 1934, NOR SHALL IT BE DEEMED INCORPORATED BY REFERENCE IN ANY FILING UNDER THE SECURITIES ACT OF 1933, EXCEPT AS SHALL BE EXPRESSLY SET FORTH BY SPECIFIC REFERENCE IN SUCH FILING.)
ALLETE 2006 Form 10-K
EXHIBIT 4(a)3
ALLETE 2006 FORM 10-K
ALLETE, INC.
(formerly Minnesota Power & Light Company
and formerly Minnesota Power, Inc.)
TO
THE BANK OF NEW YORK
(formerly Irving Trust Company)
AND
DOUGLAS J. MACINNES
(successor to Richard H. West, J. A. Austin, E.J. McCabe, D.W. May, J.A. Vaughan and W.T. Cunningham)
As Trustees under ALLETE, Inc.'s Mortgage and Deed of Trust dated as of September 1, 1945
Twenty-sixth Supplemental Indenture Providing among other things for First Mortgage Bonds, 5.99% Series due February 1, 2027
(Thirty-second Series)
TWENTY-SIXTH SUPPLEMENTAL INDENTURE
THIS INDENTURE, dated as of October 1, 2006, by and between ALLETE, INC.
(formerly Minnesota Power & Light Company and formerly Minnesota Power, Inc.), a
corporation of the State of Minnesota, whose post office address is 30 West
Superior Street, Duluth, Minnesota 55802 (hereinafter sometimes called the
"Company"), and THE BANK OF NEW YORK (formerly Irving Trust Company), a
corporation of the State of New York, whose post office address is 101 Barclay
Street, New York, New York 10286 (hereinafter sometimes called the "Corporate
Trustee"), and DOUGLAS J. MACINNES (successor to Richard H. West, J. A. Austin,
E. J. McCabe, D. W. May, J. A. Vaughan and W. T. Cunningham), whose post office
address is 1784 W. McGalliard Avenue, Hamilton, New Jersey 08610 (said Douglas
J. MacInnes being hereinafter sometimes called the "Co-Trustee" and the
Corporate Trustee and the Co-Trustee being hereinafter together sometimes called
the "Trustees"), as Trustees under the Mortgage and Deed of Trust, dated as of
September 1, 1945, between the Company and Irving Trust Company and Richard H.
West, as Trustees, securing bonds issued and to be issued as provided therein
(hereinafter sometimes called the "Mortgage"), reference to which mortgage is
hereby made, this indenture (hereinafter sometimes called the "Twenty-sixth
Supplemental Indenture") being supplemental thereto:
WHEREAS, the Mortgage was filed and recorded in various official records in the State of Minnesota; and
WHEREAS, an instrument, dated as of October 16, 1957, was executed and delivered under which J. A. Austin succeeded Richard H. West as Co-Trustee under the Mortgage, and such instrument was filed and recorded in various official records in the State of Minnesota; and
WHEREAS, an instrument, dated as of April 4, 1967, was executed and delivered under which E. J. McCabe in turn succeeded J. A. Austin as Co-Trustee under the Mortgage, and such instrument was filed and recorded in various official records in the State of Minnesota; and
WHEREAS, under the Sixth Supplemental Indenture, dated as of August 1, 1975, to which reference is hereinafter made, D. W. May in turn succeeded E. J. McCabe as Co-Trustee under the Mortgage; and
WHEREAS, an instrument, dated as of June 25, 1984, was executed and delivered under which J. A. Vaughan in turn succeeded D. W. May as Co-Trustee under the Mortgage, and such instrument was filed and recorded in various official records in the State of Minnesota; and
WHEREAS, an instrument, dated as of July 27, 1988, was executed and delivered under which W. T. Cunningham in turn succeeded J. A. Vaughan as Co-Trustee under the Mortgage, and such instrument was filed and recorded in various official records in the State of Minnesota; and
WHEREAS, on May 12, 1998, the Company filed Amended and Restated Articles of Incorporation with the Secretary of State of the State of Minnesota changing its name from Minnesota Power & Light Company to Minnesota Power, Inc. effective May 27, 1998; and
WHEREAS, an instrument, dated as of April 15, 1999, was executed and delivered under which Douglas J. MacInnes in turn succeeded W. T. Cunningham as Co-Trustee under the Mortgage, and such instrument was filed and recorded in various official records in the State of Minnesota; and
WHEREAS, on May 8, 2001, the Company filed Amended and Restated Articles of Incorporation with the Secretary of State of the State of Minnesota changing its name from Minnesota Power, Inc. to ALLETE, Inc.; and
WHEREAS, by the Mortgage the Company covenanted, among other things, that it would execute and deliver such supplemental indenture or indentures and such further instruments and do such further acts as might be necessary or proper to carry out more effectually the purposes of the Mortgage and to make subject to the lien of the Mortgage any property thereafter acquired and intended to be subject to the lien thereof; and
WHEREAS, for said purposes, among others, the Company executed and delivered the following indentures supplemental to the Mortgage:
DESIGNATION DATED AS OF
----------- -----------
First Supplemental Indenture...........................March 1, 1949
Second Supplemental Indenture..........................July 1, 1951
Third Supplemental Indenture...........................March 1, 1957
Fourth Supplemental Indenture..........................January 1, 1968
Fifth Supplemental Indenture...........................April 1, 1971
Sixth Supplemental Indenture...........................August 1, 1975
Seventh Supplemental Indenture.........................September 1, 1976
Eighth Supplemental Indenture..........................September 1, 1977
Ninth Supplemental Indenture...........................April 1, 1978
Tenth Supplemental Indenture...........................August 1, 1978
Eleventh Supplemental Indenture........................December 1, 1982
Twelfth Supplemental Indenture.........................April 1, 1987
Thirteenth Supplemental Indenture......................March 1, 1992
Fourteenth Supplemental Indenture......................June 1, 1992
Fifteenth Supplemental Indenture.......................July 1, 1992
Sixteenth Supplemental Indenture.......................July 1, 1992
Seventeenth Supplemental Indenture.....................February 1, 1993
Eighteenth Supplemental Indenture......................July 1, 1993
Nineteenth Supplemental Indenture......................February 1, 1997
Twentieth Supplemental Indenture.......................November 1, 1997
Twenty-first Supplemental Indenture....................October 1, 2000
Twenty-second Supplemental Indenture...................July 1, 2003
Twenty-third Supplemental Indenture....................August 1, 2004
Twenty-fourth Supplemental Indenture...................March 1, 2005
Twenty-fifth Supplemental Indenture....................December 1, 2005
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which supplemental indentures were filed and recorded in various official records in the State of Minnesota; and
WHEREAS, the Company has heretofore issued, in accordance with the provisions of the Mortgage, as heretofore supplemented, the following series of First Mortgage Bonds:
SERIES PRINCIPAL PRINCIPAL
------ AMOUNT AMOUNT
ISSUED OUTSTANDING
--------- -----------
3-1/8% Series due 1975....................... $26,000,000 None
3-1/8% Series due 1979....................... 4,000,000 None
3-5/8% Series due 1981....................... 10,000,000 None
4-3/4% Series due 1987....................... 12,000,000 None
6-1/2% Series due 1998....................... 18,000,000 None
8-1/8% Series due 2001....................... 23,000,000 None
10-1/2% Series due 2005...................... 35,000,000 None
8.70% Series due 2006........................ 35,000,000 None
8.35% Series due 2007........................ 50,000,000 None
9-1/4% Series due 2008....................... 50,000,000 None
Pollution Control Series A................... 111,000,000 None
Industrial Development Series A.............. 2,500,000 None
Industrial Development Series B.............. 1,800,000 None
Industrial Development Series C.............. 1,150,000 None
Pollution Control Series B................... 13,500,000 None
Pollution Control Series C................... 2,000,000 None
Pollution Control Series D................... 3,600,000 None
7-3/4% Series due 1994....................... 55,000,000 None
7-3/8% Series due March 1, 1997.............. 60,000,000 None
7-3/4% Series due June 1, 2007............... 55,000,000 None
7-1/2% Series due August 1, 2007 ............ 35,000,000 None
Pollution Control Series E................... 111,000,000 None
7% Series due March 1, 2008.................. 50,000,000 None
6-1/4% Series due July 1, 2003............... 25,000,000 None
7% Series due February 15, 2007.............. 60,000,000 60,000,000
6.68% Series due November 15, 2007........... 20,000,000 20,000,000
Floating Rate Series due October 20, 2003.... 250,000,000 None
Collateral Series A.......................... 255,000,000 None
Pollution Control Series F................... 111,000,000 111,000,000
5.28% Series due August 1, 2020.............. 35,000,000 35,000,000
5.69% Series due March 1, 2036............... 50,000,000 50,000,000
|
which bonds are also hereinafter sometimes called bonds of the First through Thirty-first Series, respectively; and
WHEREAS, Section 8 of the Mortgage provides that the form of each series of bonds (other than the First Series) issued thereunder and of coupons to be attached to coupon bonds of such series shall be established by Resolution of the Board of Directors of the Company and that the
form of such series, as established by said Board of Directors, shall specify the descriptive title of the bonds and various other terms thereof, and may also contain such provisions not inconsistent with the provisions of the Mortgage as the Board of Directors may, in its discretion, cause to be inserted therein expressing or referring to the terms and conditions upon which such bonds are to be issued and/or secured under the Mortgage; and
WHEREAS, Section 120 of the Mortgage provides, among other things, that any power, privilege or right expressly or impliedly reserved to or in any way conferred upon the Company by any provision of the Mortgage, whether such power, privilege or right is in any way restricted or is unrestricted, may (to the extent permitted by law) be in whole or in part waived or surrendered or subjected to any restriction if at the time unrestricted or to additional restriction if already restricted, and the Company may enter into any further covenants, limitations or restrictions for the benefit of any one or more series of bonds issued thereunder, or the Company may cure any ambiguity contained therein, or in any supplemental indenture, or may establish the terms and provisions of any series of bonds (other than said First Series) by an instrument in writing executed and acknowledged by the Company in such manner as would be necessary to entitle a conveyance of real estate to record in all of the states in which any property at the time subject to the lien of the Mortgage shall be situated; and
WHEREAS, the Company now desires to create a new series of bonds and (pursuant to the provisions of Section 120 of the Mortgage) to add to its covenants and agreements contained in the Mortgage, as heretofore supplemented, certain other covenants and agreements to be observed by it and to alter and amend in certain respects the covenants and provisions contained in the Mortgage, as heretofore supplemented; and
WHEREAS, the execution and delivery by the Company of this Twenty-sixth Supplemental Indenture, and the terms of the bonds of the Thirty-second Series, hereinafter referred to, have been duly authorized by the Board of Directors of the Company by appropriate resolutions of said Board of Directors;
NOW, THEREFORE, THIS INDENTURE WITNESSETH:
That the Company, in consideration of the premises and of One Dollar to it duly paid by the Trustees at or before the ensealing and delivery of these presents, the receipt whereof is hereby acknowledged, and in further evidence of assurance of the estate, title and rights of the Trustees and in order further to secure the payment of both the principal of and interest and premium, if any, on the bonds from time to time issued under the Mortgage, as heretofore supplemented, according to their tenor and effect and the performance of all the provisions of the Mortgage (including any instruments supplemental thereto and any modification made as in the Mortgage provided) and of said bonds, hereby grants, bargains, sells, releases, conveys, assigns, transfers, mortgages, pledges, sets over and confirms (subject, however, to Excepted Encumbrances) unto THE BANK OF NEW YORK and DOUGLAS J. MACINNES, as Trustees under the Mortgage, and to their successor or successors in said trust, and to said Trustees and their successors and assigns forever, all property, real, personal and mixed, of the kind or nature specifically mentioned in the Mortgage, as heretofore supplemented, or of any other kind or nature acquired by the Company after the date of the execution and delivery of the Mortgage, as heretofore supplemented (except any herein or in the Mortgage, as heretofore supplemented,
expressly excepted), now owned or, subject to the provisions of subsection (I) of Section 87 of the Mortgage, hereafter acquired by the Company (by purchase, consolidation, merger, donation, construction, erection or in any other way) and wheresoever situated, including (without in anywise limiting or impairing by the enumeration of the same the scope and intent of the foregoing or of any general description contained in this Twenty-sixth Supplemental Indenture) all lands, power sites, flowage rights, water rights, water locations, water appropriations, ditches, flumes, reservoirs, reservoir sites, canals, raceways, dams, dam sites, aqueducts, and all other rights or means for appropriating, conveying, storing and supplying water; all rights of way and roads; all plants for the generation of electricity by steam, water and/or other power; all power houses, gas plants, street lighting systems, standards and other equipment incidental thereto, telephone, radio and television systems, air-conditioning systems and equipment incidental thereto, water works, water systems, steam heat and hot water plants, substations, lines, service and supply systems, bridges, culverts, tracks, ice or refrigeration plants and equipment, offices, buildings and other structures and the equipment thereof; all machinery, engines, boilers, dynamos, electric, gas and other machines, regulators, meters, transformers, generators, motors, electrical, gas and mechanical appliances, conduits, cables, water, steam heat, gas or other pipes, gas mains and pipes, service pipes, fittings, valves and connections, pole and transmission lines, wires, cables, tools, implements, apparatus, furniture and chattels; all municipal and other franchises, consents or permits; all lines for the transmission and distribution of electric current, gas, steam heat or water for any purpose including towers, poles, wires, cables, pipes, conduits, ducts and all apparatus for use in connection therewith; all real estate, lands, easements, servitudes, licenses, permits, franchises, privileges, rights of way and other rights in or relating to real estate or the occupancy of the same and (except as herein or in the Mortgage, as heretofore supplemented, expressly excepted) all the right, title and interest of the Company in and to all other property of any kind or nature appertaining to and/or used and/or occupied and/or enjoyed in connection with any property hereinbefore or in the Mortgage, as heretofore supplemented, described.
TOGETHER WITH all and singular the tenements, hereditaments, prescriptions, servitudes and appurtenances belonging or in anywise appertaining to the aforesaid property or any part thereof, with the reversion and reversions, remainder and remainders and (subject to the provisions of Section 57 of the Mortgage) the tolls, rents, revenues, issues, earnings, income, product and profits thereof, and all the estate, right, title and interest and claim whatsoever, at law as well as in equity, which the Company now has or may hereafter acquire in and to the aforesaid property and franchises and every part and parcel thereof.
IT IS HEREBY AGREED by the Company that, subject to the provisions of subsection (I) of Section 87 of the Mortgage, all the property, rights, and franchises acquired by the Company (by purchase, consolidation, merger, donation, construction, erection or in any other way) after the date hereof, except any herein or in the Mortgage, as heretofore supplemented, expressly excepted, shall be and are as fully granted and conveyed hereby and by the Mortgage and as fully embraced within the lien hereof and the lien of the Mortgage as if such property, rights and franchises were now owned by the Company and were specifically described herein or in the Mortgage and conveyed hereby or thereby.
PROVIDED that the following are not and are not intended to be now or hereafter granted, bargained, sold, released, conveyed, assigned, transferred, mortgaged, hypothecated, affected,
pledged, set over or confirmed hereunder and are hereby expressly excepted from the lien and operation of this Twenty-sixth Supplemental Indenture and from the lien and operation of the Mortgage, namely: (1) cash, shares of stock, bonds, notes and other obligations and other securities not hereafter specifically pledged, paid, deposited, delivered or held under the Mortgage or covenanted so to be; (2) merchandise, equipment, apparatus, materials or supplies held for the purpose of sale or other disposition in the usual course of business; fuel, oil and similar materials and supplies consumable in the operation of any of the properties of the Company; all aircraft, rolling stock, trolley coaches, buses, motor coaches, automobiles and other vehicles and materials and supplies held for the purpose of repairing or replacing (in whole or part) any of the same; all timber, minerals, mineral rights and royalties; (3) bills, notes and accounts receivable, judgments, demands and choses in action, and all contracts, leases and operating agreements not specifically pledged under the Mortgage or covenanted so to be; the Company's contractual rights or other interest in or with respect to tires not owned by the Company; (4) the last day of the term of any lease or leasehold which may hereafter become subject to the lien of the Mortgage; (5) electric energy, gas, steam, ice, and other materials or products generated, manufactured, produced or purchased by the Company for sale, distribution or use in the ordinary course of its business; and (6) the Company's franchise to be a corporation; provided, however, that the property and rights expressly excepted from the lien and operation of this Twenty-sixth Supplemental Indenture and from the lien and operation of the Mortgage in the above subdivisions (2) and (3) shall (to the extent permitted by law) cease to be so excepted in the event and as of the date that either or both of the Trustees or a receiver or trustee shall enter upon and take possession of the Mortgaged and Pledged Property in the manner provided in Article XIII of the Mortgage by reason of the occurrence of a Default as defined in Section 65 thereof.
TO HAVE AND TO HOLD all such properties, real, personal and mixed, granted, bargained, sold, released, conveyed, assigned, transferred, mortgaged, pledged, set over or confirmed by the Company as aforesaid, or intended so to be, unto the Trustees and their successors and assigns forever.
IN TRUST NEVERTHELESS, for the same purposes and upon the same terms, trusts and conditions and subject to and with the same provisos and covenants as are set forth in the Mortgage, as supplemented, this Twenty-sixth Supplemental Indenture being supplemental thereto.
AND IT IS HEREBY COVENANTED by the Company that all the terms, conditions, provisos, covenants and provisions contained in the Mortgage, as heretofore supplemented, shall affect and apply to the property hereinbefore described and conveyed and to the estate, rights, obligations and duties of the Company and Trustees and the beneficiaries of the trust with respect to said property, and to the Trustees and their successors in the trust in the same manner and with the same effect as if said property had been owned by the Company at the time of the execution of the Mortgage, and had been specifically and at length described in and conveyed to said Trustees by the Mortgage as a part of the property therein stated to be conveyed.
The Company further covenants and agrees to and with the Trustees and their successors in said trust under the Mortgage as follows:
ARTICLE I
THIRTY-SECOND SERIES OF BONDS
SECTION 1. There shall be a series of bonds designated "5.99% Series due February 1, 2027" (herein sometimes referred to as the "Thirty-second Series"), each of which shall also bear the descriptive title "First Mortgage Bond", and the form thereof, which shall be established by Resolution of the Board of Directors of the Company, shall contain suitable provisions with respect to the matters hereinafter in this Section specified. Bonds of the Thirty-second Series shall be dated as in Section 10 of the Mortgage provided, mature on February 1, 2027, be issued as fully registered bonds in denominations of One Thousand Dollars and, at the option of the Company, in any multiple or multiples of One Thousand Dollars (the exercise of such option to be evidenced by the execution and delivery thereof) and bear interest from February 1, 2007 at the rate of 5.99% per annum, payable semi-annually on February 1 and August 1 of each year, commencing August 1, 2007, the principal of and interest on each said bond to be payable at the office or agency of the Company in the Borough of Manhattan, The City of New York, in such coin or currency of the United States of America as at the time of payment is legal tender for public and private debts.
(I) OPTIONAL PREPAYMENT. The Company may, at its option, upon notice as provided below, prepay at any time all, or from time to time any part of, the bonds of the Thirty-second Series at 100% of the principal amount so prepaid, and the Make-Whole Amount determined for the Settlement Date specified by the Company in such notice with respect to such principal amount. The Company will give each registered owner of Bonds of the Thirty-second Series written notice (by first class mail or such other method as may be agreed upon by the Company and such registered owner) of each optional prepayment under this subsection (I) mailed or otherwise given not less than 30 days and not more than 60 days prior to the date fixed for such prepayment, to each such registered owner at his, her or its last address appearing on the registry books. Each such notice shall specify the Settlement Date (which shall be a Business Day), the aggregate principal amount of the bonds of the Thirty-second Series to be prepaid on such date, the principal amount of each bond held by such registered owner to be prepaid (determined in accordance with subsection (II) of this section), and the interest to be paid on the Settlement Date with respect to such principal amount being prepaid, and shall be accompanied by a certificate signed by a Senior Financial Officer as to the estimated Make-Whole Amount due in connection with such prepayment (calculated as if the date of such notice were the date of the prepayment), setting forth the details of such computation. Two Business Days prior to such Settlement Date, the Company shall send to each registered owner of bonds of the Thirty-second Series (by first class mail or by such other method as may be agreed upon by the Company and such registered owner) a certificate signed by a Senior Financial Officer specifying the calculation of such Make-Whole Amount as of the specified Settlement Date. As promptly as practicable after the giving of the notice and the sending of the certificates provided in this subsection, the Company shall provide a copy of each to the Corporate Trustee. The Trustees shall be under no duty to inquire into, may conclusively presume the correctness of, and shall be fully protected in relying upon the information set forth in any such notice or certificate. The bonds of the Thirty-second Series are not otherwise subject to voluntary or optional prepayment.
(II) ALLOCATION OF PARTIAL PREPAYMENTS. In the case of each partial prepayment of the bonds of the Thirty-second Series, the principal amount of the Bonds of the Thirty-second Series to be prepaid shall be allocated by the Company among all of the Bonds of the Thirty-second Series at the time outstanding in proportion, as nearly as practicable, to the respective unpaid principal amounts thereof not theretofore called for prepayment.
(III) MATURITY; SURRENDER, ETC. In the case of each notice of prepayment of bonds of the Thirty-second Series pursuant to this section, if cash sufficient to pay the principal amount to be prepaid on the Settlement Date (which shall be a Business Day), together with interest on such principal amount accrued to such date and the applicable Make-Whole Amount, if any, is not paid as agreed upon by the Company and each registered owner of the affected bonds, or, to the extent that there is no such agreement entered into with one or more such owners, deposited with the Corporate Trustee on or before the Settlement Date, then such notice of prepayment shall be of no effect. If such cash is so paid or deposited, such principal amount of the bonds of the Thirty-second Series shall be deemed paid for all purposes and interest on such principal amount shall cease to accrue. In case the Company pays any registered owner pursuant to an agreement with that registered owner, the Company shall notify the Corporate Trustee as promptly as practicable of such agreement and payment, and shall furnish the Corporate Trustee with a copy of such agreement; in case the Company deposits any cash with the Corporate Trustee, the Company shall provide therewith a list of the registered owners and the amount of such cash each registered owner is to receive. The Trustees shall be under no duty to inquire into, may conclusively presume the correctness of, and shall be fully protected in relying upon the information set forth in any such notice, list or agreement, and shall not be chargeable with knowledge of any of the contents of any such agreement. Any bond prepaid in full shall be surrendered to the Company or the Corporate Trustee for cancellation on or before the Settlement Date or, with respect to cash deposited with the Corporate Trustee, before payment of such cash by the Corporate Trustee; any bond prepaid in part shall be surrendered to the Company or the Corporate Trustee on or before the Settlement Date (unless otherwise agreed between the Company and the registered owner) or, with respect to cash deposited with Corporate Trustee before payment of such cash by the Corporate Trustee, for a substitute bond in the principal amount remaining unpaid.
(IV) MAKE-WHOLE AMOUNT.
"Make-Whole Amount" means, with respect to any bond of the Thirty-second Series, an amount equal to the excess, if any, of the Discounted Value of the Remaining Scheduled Payments with respect to the Called Principal of such bond of the Thirty-second Series over the amount of such Called Principal, provided that the Make-Whole Amount may in no event be less than zero. For the purposes of determining the Make-Whole Amount, the following terms have the following meanings:
"Business Day" means any day other than a Saturday, a Sunday or a day on which commercial banks in New York City are required or authorized to be closed.
"Called Principal" means, with respect to any bond of the Thirty-second
Series, the principal of such bond that is to be prepaid pursuant to subsection
(I) of this section.
"Discounted Value" means, with respect to the Called Principal of any bond of the Thirty-second Series, the amount obtained by discounting all Remaining Scheduled Payments with respect to such Called Principal from their respective scheduled due dates to the Settlement Date with respect to such Called Principal, in accordance with accepted financial practice and at a discount factor (applied on the same periodic basis as that on which interest on the bonds of the Thirty-second Series is payable) equal to the Reinvestment Yield with respect to such Called Principal.
"Reinvestment Yield" means, with respect to the Called Principal of any bond of the Thirty-second Series, 0.5% over the yield to maturity implied by (i) the yields reported as of 10:00 a.m. (New York City time) on the second Business Day preceding the Settlement Date with respect to such Called Principal, on the display designated as "Page PX1" (or such other display as may replace Page PX1 on Bloomberg Financial Markets ("Bloomberg") or, if Page PX1 (or its successor screen on Bloomberg) is unavailable, the Telerate Access Service screen which corresponds most closely to Page PX1 for the most recently issued actively traded U.S. Treasury securities having a maturity equal to the Remaining Average Life of such Called Principal as of such Settlement Date, or (ii) if such yields are not reported as of such time or the yields reported as of such time are not ascertainable (including by way of interpolation), the Treasury Constant Maturity Series Yields reported, for the latest day for which such yields have been so reported as of the second Business Day preceding the Settlement Date with respect to such Called Principal, in Federal Reserve Statistical Release H.15 (519) (or any comparable successor publication) for actively traded U.S. Treasury securities having a constant maturity equal to the Remaining Average Life of such Called Principal as of such Settlement Date. Such implied yield will be determined, if necessary, by (a) converting U.S. Treasury bill quotations to bond equivalent yields in accordance with accepted financial practice and (b) interpolating linearly between (1) the actively traded U.S. Treasury security with the maturity closest to and greater than such Remaining Average Life and (2) the actively traded U.S. Treasury security with the maturity closest to and less than such Remaining Average Life. The Reinvestment Yield shall be rounded to the number of decimal places as appears in the interest rate of the applicable bond of the Thirty-second Series.
"Remaining Average Life" means, with respect to any Called Principal, the number of years (calculated to the nearest one-twelfth year) obtained by dividing (i) such Called Principal into (ii) the sum of the products obtained by multiplying (a) the principal component of each Remaining Scheduled Payment with respect to such Called Principal by (b) the number of years (calculated to the nearest one-twelfth year) that will elapse between the Settlement Date with respect to such Called Principal and the scheduled due date of such Remaining Scheduled Payment.
"Remaining Scheduled Payments" means, with respect to the Called Principal of any Bond of the Thirty-second Series, all payments of such Called Principal and interest thereon that would be due after the Settlement Date with respect to such Called Principal if no payment of such Called Principal were made prior to its scheduled due date, provided that if such Settlement Date is not a date on which interest payments are due to be made under the terms of the Bonds of the Thirty-second Series, then the amount of the next succeeding scheduled interest payment will be reduced by the amount of interest accrued to such Settlement Date and required to be paid on such Settlement Date pursuant to subsection (I) of this section.
"Settlement Date" means, with respect to the Called Principal of any Bond of the Thirty-second Series, the date on which such Called Principal is to be prepaid pursuant to subsection (I) of this section.
"Senior Financial Officer" means the chief financial officer, principal accounting officer, treasurer or comptroller of the Company.
(V) At the option of the registered owner, any bonds of the Thirty-second Series, upon surrender thereof for cancellation at the office or agency of the Company in the Borough of Manhattan, The City of New York, together with a written instrument of transfer wherever required by the Company duly executed by the registered owner or by his duly authorized attorney, shall (subject to the provisions of Section 12 of the Mortgage) be exchangeable for a like aggregate principal amount of bonds of the same series of other authorized denominations.
Bonds of the Thirty-second Series shall be transferable (subject to the provisions of Section 12 of the Mortgage) at the office or agency of the Company in the Borough of Manhattan, The City of New York. The Company shall not be required to make transfers or exchanges of bonds of the Thirty-second Series for a period of ten (10) days next preceding any designation of bonds of said series to be prepaid, and the Company shall not be required to make transfers or exchanges of any bonds of said series designated in whole or in part for prepayment.
Upon any exchange or transfer of bonds of the Thirty-second Series, the Company may make a charge therefor sufficient to reimburse it for any tax or taxes or other governmental charge, as provided in Section 12 of the Mortgage, but the Company hereby waives any right to make a charge in addition thereto for any exchange or transfer of bonds of the Thirty-second Series.
After the delivery of this Twenty-sixth Supplemental Indenture and upon compliance with the applicable provisions of the Mortgage and receipt of consideration therefor by the Company, there shall be an initial issue of bonds of the Thirty-second Series for the aggregate principal amount of $60,000,000.
ARTICLE II
MISCELLANEOUS PROVISIONS
SECTION 1. Section 126 of the Mortgage, as heretofore amended, is hereby further amended by adding the words "and February 1, 2027," after the words "and March 1, 2036."
SECTION 2. Subject to the amendments provided for in this Twenty-sixth Supplemental Indenture, the terms defined in the Mortgage, as heretofore supplemented, shall, for all purposes of this Twenty-sixth Supplemental Indenture, have the meanings specified in the Mortgage, as heretofore supplemented.
SECTION 3. The holders of bonds of the Thirty-second Series consent that the Company may, but shall not be obligated to, fix a record date for the purpose of determining the holders of bonds of the Thirty-second Series entitled to consent to any amendment, supplement or waiver.
If a record date is fixed, those persons who were holders at such record date (or their duly designated proxies), and only those persons, shall be entitled to consent to such amendment, supplement or waiver or to revoke any consent previously given, whether or not such persons continue to be holders after such record date. No such consent shall be valid or effective for more than 90 days after such record date.
SECTION 4. The Trustees hereby accept the trusts herein declared, provided, created or supplemented and agree to perform the same upon the terms and conditions herein and in the Mortgage set forth and upon the following terms and conditions:
The Trustees shall not be responsible in any manner whatsoever for or in respect of the validity or sufficiency of this Twenty-sixth Supplemental Indenture or for or in respect of the recitals contained herein, all of which recitals are made by the Company solely. In general, each and every term and condition contained in Article XVII of the Mortgage shall apply to and form part of this Twenty-sixth Supplemental Indenture with the same force and effect as if the same were herein set forth in full with such omissions, variations and insertions, if any, as may be appropriate to make the same conform to the provisions of this Twenty-sixth Supplemental Indenture.
SECTION 5. Whenever in this Twenty-sixth Supplemental Indenture any party hereto is named or referred to, this shall, subject to the provisions of Articles XVI and XVII of the Mortgage, as heretofore supplemented, be deemed to include the successors or assigns of such party, and all the covenants and agreements in this Twenty-sixth Supplemental Indenture contained by or on behalf of the Company, or by or on behalf of the Trustees shall, subject as aforesaid, bind and inure to the benefit of the respective successors and assigns of such party whether so expressed or not.
SECTION 6. Nothing in this Twenty-sixth Supplemental Indenture, expressed or implied, is intended, or shall be construed, to confer upon, or give to, any person, firm or corporation, other than the parties hereto and the holders of the bonds and coupons Outstanding under the Mortgage, any right, remedy, or claim under or by reason of this Twenty-sixth Supplemental Indenture or any covenant, condition, stipulation, promise or agreement hereof, and all the covenants, conditions, stipulations, promises and agreements in this Twenty-sixth Supplemental Indenture contained by and on behalf of the Company shall be for the sole and exclusive benefit of the parties hereto, and of the holders of the bonds and of the coupons Outstanding under the Mortgage.
SECTION 7. This Twenty-sixth Supplemental Indenture shall be executed in several counterparts, each of which shall be an original and all of which shall constitute but one and the same instrument.
SECTION 8. The Company, the mortgagor named herein, by its execution hereof acknowledges receipt of a full, true and complete copy of this Twenty-sixth Supplemental Indenture.
IN WITNESS WHEREOF, ALLETE, Inc. has caused its corporate name to be hereunto affixed, and this instrument to be signed and sealed by its President or one of its Vice Presidents, and its corporate seal to be attested by its Secretary or one of its Assistant Secretaries for and in its behalf, all in the City of Duluth, Minnesota, and The Bank of New York has caused its corporate name to be hereunto affixed, and this instrument to be signed and sealed by one of its Vice Presidents or one of its Assistant Vice Presidents and its corporate seal to be attested by one of its Assistant Treasurers, one of its Vice Presidents or one of its Assistant Vice Presidents, and Douglas J. MacInnes has hereunto set his hand and affixed his seal, all in The City of New York, as of the day and year first above written.
ALLETE, INC.
By /s/ Mark A. Schober
---------------------------------------
Mark A. Schober
Senior Vice President & Chief Financial
Officer
Attest:
/s/ Deborah A. Amberg
--------------------------------------
Deborah A. Amberg
Senior Vice President, General Counsel
& Secretary
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Executed, sealed and delivered by
ALLETE, INC. in the presence of:
/s/ Kristie Lindstrom --------------------- /s/ Susan Romans --------------------- |
THE BANK OF NEW YORK,
as Trustee
By /s/ Mary K. LaGumina
---------------------------------------
Printed Name: Mary K. LaGumina
Title: Vice President
Attest:
/s/ Alexander Pabon
-------------------
Printed Name: Alexander Pabon
Title: Assistant Vice President
/s/ Douglas J. MacInnes L.S.
-----------------------------------------
DOUGLAS J. MACINNES
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Executed, sealed and delivered by
THE BANK OF NEW YORK and
DOUGLAS J. MACINNES in the presence of:
/s/ Franca Ferrera ------------------ /s/ Sean Johnson ------------------ |
STATE OF MINNESOTA )
) SS.:
COUNTY OF ST. LOUIS )
|
On this 18th day of January, 2007, before me, a Notary Public within and for said County, personally appeared Mark A. Schober and Deborah A. Amberg, to me personally known, who, being each by me duly sworn, did say that they are respectively the Senior Vice President and Chief Financial Officer and the Senior Vice President, General Counsel, and Secretary of ALLETE, INC. of the State of Minnesota, the corporation named in the foregoing instrument; that the seal affixed to the foregoing instrument is the corporate seal of said corporation; that said instrument was signed and sealed in behalf of said corporation by authority of its Board of Directors; and said Mark A. Schober and Deborah A. Amberg acknowledged said instrument to be the free act and deed of said corporation.
Personally came before me on this 18th day of January, 2007, Mark A. Schober, to me known to be the Senior Vice President and Chief Financial Officer, and Deborah A. Amberg, to me known to be the Senior Vice President, General Counsel, and Secretary of the above named ALLETE, INC., the corporation described in and which executed the foregoing instrument, and to me personally known to be the persons who as such officers executed the foregoing instrument in the name and behalf of said corporation, who, being by me duly sworn did depose and say and acknowledge that they are respectively the Senior Vice President and Chief Financial Officer and the Senior Vice President, General Counsel, and Secretary of said corporation; that the seal affixed to said instrument is the corporate seal of said corporation; and that they signed, sealed and delivered said instrument in the name and on behalf of said corporation by authority of its Board of Directors and stockholders, and said Mark A. Schober and Deborah A. Amberg then and there acknowledged said instrument to be the free act and deed of said corporation and that such corporation executed the same.
On the 18th day of January, 2007, before me personally came Mark A. Schober and Deborah A. Amberg, to me known, who, being by me duly sworn, did depose and say that they respectively reside at 202 W. Owatonna Street, Duluth, Minnesota, and 2738 Northridge Drive, Duluth, Minnesota; that they are respectively the Senior Vice President and Chief Financial Officer and the Senior Vice President, General Counsel, and Secretary of ALLETE, INC., one of the corporations described in and which executed the above instrument; that they know the seal of said corporation; that the seal affixed to said instrument is such corporate seal; that it was so affixed by order of the Board of Directors of said corporation, and that they signed their names thereto by like order.
GIVEN under my hand and notarial seal this 18th day of January, 2007.
[NOTARY PUBLIC SEAL] /s/ Jodi Nash
JODI M. NASH ------------------------------
NOTARY PUBLIC - MINNEOSTA NOTARY PUBLIC - MINNESOTA
My Commission Expires Jan 31, 2010 My Commission Expires 1/31/2010
|
STATE OF NEW YORK )
) SS:
COUNTY OF NEW YORK )
|
On this 7th day of December, 2006, before me, a Notary Public within and for said County, personally appeared Mary K. LaGumina and Alexander Pabon, to me personally known, who, being each by me duly sworn, did say that they are respectively a Vice President and an Assistant Vice President of THE BANK OF NEW YORK of the State of New York, the corporation named in the foregoing instrument; that the seal affixed to the foregoing instrument is the corporate seal of said corporation; that said instrument was signed and sealed in behalf of said corporation by authority of its Board of Directors; and said Mary K. LaGumina and Alexander Pabon acknowledged said instrument to be the free act and deed of said corporation.
Personally came before me on this 7th day of December, 2006, Mary K. LaGumina, to me known to be a Vice President, and Alexander Pabon, to me known to be an Assistant Vice President, of the above named THE BANK OF NEW YORK, the corporation described in and which executed the foregoing instrument, and to me personally known to be the persons who as such officers executed the foregoing instrument in the name and behalf of said corporation, who, being by me duly sworn did depose and say and acknowledge that they are respectively a Vice President and an Assistant Vice President of said corporation; that the seal affixed to said instrument is the corporate seal of said corporation; and that they signed, sealed and delivered said instrument in the name and on behalf of said corporation by authority of its Board of Directors, and said Mary K. LaGumina and Alexander Pabon then and there acknowledged said instrument to be the free act and deed of said corporation and that such corporation executed the same.
On the 7th day of December, 2006, before me personally came Mary K. LaGumina and Alexander Pabon, to me known, who, being by me duly sworn, did depose and say that they respectively reside at 17 The Quarter Deck, Port Washington, NY 11233, and 245 Seaman Avenue, Apt. 1-E, New York, NY 10034; that they are respectively a Vice President and an Assistant Vice President of THE BANK OF NEW YORK, one of the corporations described in and which executed the above instrument; that they know the seal of said corporation; that the seal affixed to said instrument is such corporate seal; that it was so affixed by order of the Board of Directors of said corporation, and that they signed their names thereto by like order.
GIVEN under my hand and notarial seal this 7th day of December, 2006.
CARLOS R. LUCIANO
Notary Public, State of New York /s/ Carlos R. Luciano
No. 41-4765897 --------------------------------
Qualified in Queens County Notary Public, State of New York
Commission Expires 4/30/2010
|
STATE OF NEW YORK )
) SS:
COUNTY OF NEW YORK )
|
On this 7th day of December, 2006, before me personally appeared DOUGLAS J. MACINNES, to me known to be the person described in and who executed the foregoing instrument, and acknowledged that he executed the same as his free act and deed.
Personally came before me this 7th day of December, 2006, the above named DOUGLAS J. MACINNES, to me known to be the person who executed the foregoing instrument, and acknowledged the same.
On the 7th day of December, 2006, before me personally came DOUGLAS J. MACINNES, to me known to be the person described in and who executed the foregoing instrument, and acknowledged that he executed the same.
GIVEN under my hand and notarial seal this 7th day of December, 2006.
CARLOS R. LUCIANO
Notary Public, State of New York /s/ Carlos R. Luciano
No. 41-4765897 --------------------------------
Qualified in Queens County Notary Public, State of New York
Commission Expires 4/30/2010
|
EXHIBIT 10(d)3
ALLETE 2006 FORM 10-K
SECOND AMENDMENT TO
FOURTH AMENDED AND RESTATED COMMITTED FACILITY LETTER
This Second Amendment to Fourth Amended and Restated Committed Facility Letter (this "AMENDMENT") is dated as of December 14, 2006, by and among ALLETE, INC., a Minnesota corporation (the "COMPANY"), the banks from time to time party to the Committed Facility Letter (as hereinafter defined) (each a "BANK" and collectively the "BANKS") and LASALLE BANK NATIONAL ASSOCIATION, in its capacity as agent for the Banks (in such capacity, the "AGENT").
WITNESSETH THAT:
WHEREAS, the Company, the Banks and the Agent are party to that certain Fourth Amended and Restated Committed Facility Letter dated as of January 11, 2006 (as amended by that certain First Amendment to Fourth Amended and Restated Committed Facility Letter dated as of June 9, 2006, together with all exhibits, schedules, attachments, appendices and further amendments thereof, the "COMMITTED FACILITY LETTER"); and
WHEREAS, the Company has requested that the Committed Facility Letter be amended as set forth herein and the Banks are agreeable to such request on the terms and subject to the conditions set forth herein;
NOW, THEREFORE, for good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged, the Company, the Banks and the Agent hereby agree as set forth below.
1. The Committed Facility Letter is amended as follows:
(a) The defined term "INITIAL MATURITY DATE" appearing in the second sentence of Section 1(f) ("MATURITY") is hereby amended by deleting the date "January 11, 2011" and substituting the date "January 11, 2012" therefor.
(b) The defined term "EXTENDED MATURITY DATE" appearing in the second paragraph of Section 1(f) is hereby amended by deleting the dates "January 11, 2012" and "January 11, 2013" appearing in clauses (i) and (ii) thereof and substituting therefor the dates "January 11, 2013" and "January 11, 2014", respectively.
(c) The definition of "APPLICABLE MARGIN" appearing in Section 8 is hereby amended by deleting said definition in its entirety and substituting the following new definition in lieu thereof:
"APPLICABLE MARGIN" means (i) with respect to Eurodollar Loans, (a) 0.180% per annum for any day Level I Status exists; (b) 0.270% per annum for any day Level II Status exists; (c) 0.350% per annum for any day Level III Status exists; (d) 0.425% per annum for any day Level IV Status exists;
(e) 0.525% per annum for any day Level V Status exists, and (f) 0.800% per annum for any day Level VI Status exists; and (ii) with respect to Prime Rate Loans, 0.000% per annum.
(d) The definition of "FUNDED DEBT" appearing in Section 8 is hereby amended by deleting clauses (d) and (e) thereof.
(e) The definition of "FACILITY FEE RATE" appearing in Section 8 is hereby amended by deleting said definition in its entirety and substituting the following new definition in lieu thereof:
"FACILITY FEE RATE" means a rate equal to (i) 0.070% per annum for any day Level I Status exists; (ii) 0.080% per annum for any day Level II Status exists; (iii) 0.100% per annum for any day Level III Status exists; (iv) 0.125% per annum for any day Level IV Status exists; (v) 0.175% per annum for any day Level V Status exists; and (vi) 0.200% per annum for any day Level VI Status exists.
(f) The definition of "REQUIRED BANKS" appearing in Section 8 is hereby amended by deleting said definition in its entirety and substituting the following new definition in lieu thereof:
"REQUIRED BANKS" means, at any time, Banks having more than 50.0% of the aggregate amount of the Commitments.
(g) The definition of "TOTAL CAPITAL" appearing in Section 8 is hereby amended by deleting said definition in its entirety and substituting the following new definition in lieu thereof:
"TOTAL CAPITAL" means, as of any date determination, the sum of Consolidated Net Worth and Funded Debt.
(h) Section 8 is further amended by adding the following new defined term in its appropriate alphabetic order:
"CONSOLIDATED NET WORTH" means, as of any date of determination, the sum of stockholders' equity (including preferred stock and QUIPs), PLUS additional paid-in capital, PLUS retained earnings (or MINUS accumulated deficits) plus preferred securities of the Company and its Subsidiaries, PROVIDED, however, that the computation of Consolidated Net Worth shall exclude Accumulated Other Comprehensive Income/Loss and unearned ESOP shares, all of the foregoing determined with respect to the Company and its Subsidiaries on a consolidated basis in accordance with GAAP consistently applied.
2. Except as expressly amended hereby, the Committed Facility Letter and all other documents executed in connection therewith shall remain in full force and effect in accordance with their respective terms. The Committed Facility Letter, as amended hereby, and all rights and powers created thereby and thereunder or under such other documents are in all respects ratified and confirmed. From and after the date hereof, the Committed Facility Letter shall be deemed to be amended and modified as herein provided and, except as so amended and modified, the Committed Facility Letter shall continue in full force and effect in accordance with its terms and the Committed Facility Letter and this Amendment shall be read, taken and construed as one and the same instrument. On and after the date hereof the term "AGREEMENT" as used in the Committed Facility Letter and all other references to the Committed Facility Letter in the Committed Facility Letter, the other documents executed in connection therewith and/or herewith or any other instrument, document or writing executed by the Company or any other person or furnished to the Agent and/or the Banks by the Company, or any other person in connection herewith or therewith, shall be deemed to be a reference to the Committed Facility Letter as hereby amended.
3. The effectiveness of this Amendment is subject to the satisfaction of the following conditions precedent:
(a) The Company and each Bank shall have executed and delivered this Amendment to Agent together with such other documents and instruments as Agent may reasonably require;
(b) The payment of the Extension Fee (as defined below) to the Agent for the benefit of the Banks;
(c) No Default or Event of Default shall have occurred and be continuing; and
(d) Agent shall have received a certificate of the Secretary of the Company showing the names and titles, and bearing the signatures of, the officers of the Company authorized to execute this Amendment.
4. On and as of the date hereof, the Company represents and warrants to the Agent and to the Banks that:
(a) The representations and warranties contained in this Amendment and the Committed Facility Letter are true and correct in all material respects, in each case as though made on and as of the date hereof, except to the extent such representations and warranties relate solely to an earlier date (and then shall have been true and correct as of such earlier date); and
(b) Both before and after giving effect to this Amendment, no Default or Event of Default has occurred and is continuing or would result from the execution and delivery of this Amendment; and
(c) The Company is, and will be, in full compliance with all of the material terms, conditions and all other provisions of this Amendment and the Credit Documents; and
(d) This Amendment has been duly authorized, executed and delivered on its behalf, and both the Committed Facility Letter, both before being amended and supplemented hereby and as amended and supplemented hereby, and this Amendment constitute its legal, valid and binding obligation enforceable against it in accordance with their terms, except to the extent that a remedy or default may be determined by a court of competent jurisdiction to constitute a penalty and except to the extent that enforceability may be limited by bankruptcy, insolvency, reorganization, moratorium or other similar laws relating to creditors' rights or by general principles of equity.
5. The Company agrees to reimburse the Agent and/or the Banks for reasonable fees and expenses incurred with respect to the preparation of this Amendment and all matters incidental thereto. Without limiting the foregoing, the Company shall pay to the Agent for the ratable benefit of the Banks, a non-refundable $37,500 extension fee (the "EXTENSION FEE"), which Extension Fee shall be due and payable and fully earned upon the execution and delivery by the Agent and the Banks of this Amendment.
6. This Amendment shall be construed in accordance with and governed by the internal laws of the State of Illinois, without regard to its conflicts of laws principles.
7. This Amendment may be signed in any number of counterparts, each of which shall be deemed an original, but all of which together shall constitute one and the same instrument. This Amendment may also be signed by facsimile, and any facsimile signature hereto shall for all purposes be deemed an original signature.
8. Except as otherwise specified herein, this Amendment embodies the entire agreement and understanding between the Company and the Banks with respect to the subject matter hereof and supersedes all prior agreements, consents and understandings relating to such subject matter.
9. This Amendment shall be binding upon and inure to the benefit of the Banks and their successors and assigns and the Company and its permitted successors and assigns.
[REMAINDER OF PAGE INTENTIONALLY LEFT BLANK]
IN WITNESS WHEREOF, the parties hereto have caused this Second Amendment to Fourth Amended and Restated Committed Facility Letter to be duly executed and delivered by their duly authorized officers as of the day and year first above written.
By: /s/ Mark A. Schober
------------------------------------
Name: Mark A. Schober
----------------------------------
Title: Sr. Vice President & CFO
---------------------------------
AGENT/BANKS: LASALLE BANK NATIONAL
----------- ASSOCIATION, in its individual capacity
as a Bank and as Agent
By: /s/ Meghan Schultz
-------------------------------------
Name: Meghan Schultz
-----------------------------------
Title: Assistant Vice President
----------------------------------
|
SIGNATURE PAGE
SECOND AMENDMENT TO FOURTH AMENDED AND RESTATED COMMITTED FACILITY LETTER
DECEMBER 14, 2006
U.S. BANK NATIONAL ASSOCIATION
By: /s/ Christine G. Dean ------------------------------------- Name: Christine G. Dean Title: Vice President |
WELLS FARGO BANK,
NATIONAL ASSOCIATION
By: /s/ Patrick McCue
-------------------------------------
Name: Patrick McCue
-----------------------------------
Title: Vice President
----------------------------------
|
JPMORGAN CHASE BANK, N.A.
By: /s/ Nancy R. Barwig
-------------------------------------
Name: Nancy R. Barwig
-----------------------------------
Title: Vice President
----------------------------------
|
THE BANK OF TOKYO -
MITSUBISHI, UFJ, LTD., CHICAGO
BRANCH
By: /s/ Matthew A. Ross ------------------------------------- Name: Matthew A. Ross Title: Vice President & Manager |
EXHIBIT 10(h)4
ALLETE 2006 Form 10-K
AMENDMENT TO THE AMENDED AND RESTATED
ALLETE EXECUTIVE ANNUAL INCENTIVE PLAN
The ALLETE Executive Annual Incentive Plan, dated effective January 1, 1999, as amended, is amended as follows:
1. Effective January 1, 2007, the following sentence will be added at the end of Section 7.1 in Article 7:
"A Participant's Award will be reduced by, and the Participant will
not receive, any amount that otherwise would be disallowed as a
deduction by the Company due to the limitations under Code Section
162(m), or any subsequent or similar Code provision that limits the
amount of compensation expense the Company may deduct."
ALLETE, INC.
By: /s/ Donald J. Shippar
---------------------------------------------
Donald J. Shippar
Chairman, President & Chief Executive Officer
ATTEST:
By: /s/ Deborah A. Amberg
--------------------------------------------------
Deborah A. Amberg
Senior Vice President, General Counsel & Secretary
|
EXHIBIT 10(h)7
ALLETE 2006 Form 10-K
ALLETE EXECUTIVE ANNUAL INCENTIVE PLAN
FORM OF AWARD
EFFECTIVE 2007
[ELIGIBLE EXECUTIVE EMPLOYEES - CORPORATE AND ENERGY]
Base Salary $
TIMES
Award Opportunity (percent of base salary) %
--------
EQUALS
Target Award $
|
-------------------------- ------------------------------- ---------------------
PAYOUT AS PERCENT OF
GOAL PERFORMANCE LEVEL TARGET AWARD AWARD AMOUNT
-------------------------- ------------------------------- ---------------------
Superior 200% $
-------------------------- ------------------------------- ---------------------
Target 100% $
-------------------------- ------------------------------- ---------------------
Threshold 37.5% $
-------------------------- ------------------------------- ---------------------
Below Threshold 0% $
-------------------------- ------------------------------- ---------------------
|
GOAL
WEIGHTING
FINANCIAL GOALS
Net Income from Continuing Operations 50%
Cash Flow from Operating Activities 25%
STRATEGIC NON-FINANCIAL GOALS 25%
------
100%
|
ALLETE EXECUTIVE ANNUAL INCENTIVE PLAN
FORM OF AWARD
EFFECTIVE 2007
[ELIGIBLE EXECUTIVE EMPLOYEES - REAL ESTATE]
|
Achievement Bonus Pool (0.0% - 0.xx% of Real Estate Land Sales) $
PLUS
Incentive Bonus Pool (0.0% - 0.xx% of Total Real Estate Income) $
EQUALS --------
Bonus Pool Opportunity $
TIMES
Strategic Non-financial Goals (0% - 120%) %
EQUALS
Annual Incentive Award $
--------
--------
|
EXHIBIT 10(i)4
ALLETE 2006 Form 10-K
AMENDMENT TO THE
ALLETE AND AFFILIATED COMPANIES
SUPPLEMENTAL EXECUTIVE RETIREMENT PLAN
The ALLETE and Affiliate Companies Supplemental Executive Retirement Plan, amended and restated effective January 1, 2004, is amended as follows:
1. Effective January 1, 2007, Section 4.10 is DELETED in its entirety and replaced with the following:
4.10 FORM OF PAYMENT - RETIREMENT BENEFITS
The normal, or default, form of the Retirement Benefits provided for in
Section 4.6 will be a 15-year monthly annuity (calculated using an 8%
interest rate or other rate as approved by the Committee). The
Participant may elect to receive the Retirement Benefits in the
optional form of a monthly life annuity (calculated using the factor
described in Section 4.6), such amount to be adjusted (i.e.,
cost-of-living adjustments) in the same manner as provided in Section
5.11 of Retirement Plan A; provided, however, that any Participant who
is also eligible for retirement benefits under the ALLETE and
Affiliated Companies Supplemental Executive Retirement Plan II (SERP
II) must receive Retirement Benefits under this Plan in the same form
as he or she receives retirement benefits under SERP II. For purposes
of clarification, if a Participant who is eligible for retirement
benefits under SERP II receives the normal form of retirement benefits
under SERP II, for any reason, any election by the Participant to
receive the optional form of Retirement Benefits under this Plan shall
be inoperable and the Participant shall receive the normal form of
Retirement Benefits under this Plan.
If the actuarial present value of the Retirement Benefits under Section 4.6 is less than $10,000, the benefit will be paid in a lump sum payment.
If a Participant has commenced receipt of Retirement Benefits under this Plan and is re-employed by the Company, Retirement Benefit payments under this Plan shall be suspended upon such re-employment until the Participant again becomes eligible to receive Retirement Benefit payments under the Plan.
ALLETE, INC.
By: /s/ Donald J. Shippar
---------------------------------------------
Donald J. Shippar
Chairman, President & Chief Executive Officer
ATTEST:
By: /s/ Deborah A. Amberg
--------------------------------------------------
Deborah A. Amberg
Senior Vice President, General Counsel & Secretary
|
EXHIBIT 10(m)6
ALLETE 2006 Form 10-K
ALLETE
EXECUTIVE LONG-TERM INCENTIVE COMPENSATION PLAN
NONQUALIFIED STOCK OPTION GRANT
EFFECTIVE 2007
[ELIGIBLE EXECUTIVE EMPLOYEES]
Name
SS#
In accordance with the terms of ALLETE's Executive Long-Term Incentive Compensation Plan (the "Plan"), as determined by and through the Executive Compensation Committee of ALLETE's Board of Directors, ALLETE hereby grants to you (the "Participant"), subject to the terms and conditions set forth in this Grant (including Annex A hereto and all documents incorporated herein by reference) the rights and options (the "Options") to purchase from ALLETE, shares of its common stock, without par value, as set forth below:
Number of Options Granted:
Number of Shares to which Options Pertain:
Date of Grant:
Option Price:
Vesting:
Expiration Date:
Exercise Period:
Further terms and conditions of the Grant are set forth in Annex A hereto, which is an integral part of this Grant. This Grant is made in accordance with the Plan, which was approved by ALLETE's shareholders at the 2005 Annual Meeting. All terms, provisions and conditions applicable to the Options set forth in the Plan and not set forth herein are incorporated by reference. To the extent any provision hereof is inconsistent with a provision of the Plan, the provisions of the Plan will govern.
These Options are not intended to qualify as incentive stock options under
Section 422 of the Internal Revenue Code of 1986, as amended.
IN WITNESS WHEREOF, ALLETE has caused this Grant to be executed by its Chairman, President and Chief Executive Officer as of the date and year first above written.
ALLETE
Attachment: Annex A
ANNEX A
TO
EXECUTIVE LONG-TERM INCENTIVE COMPENSATION PLAN
NONQUALIFIED STOCK OPTION GRANT
EFFECTIVE 2007
[ELIGIBLE EXECUTIVE EMPLOYEES]
1. FURTHER TERMS AND CONDITIONS OF OPTIONS. The Grant of Options evidenced by the Grant to which this is annexed is subject to the following additional terms and conditions:
(a) EXERCISE OF OPTIONS. Except as otherwise provided in subsection
(b) hereof, upon a Change in Control as set forth in the Plan or as the
Executive Compensation Committee (the "Committee") may determine, the
Participant must be in the employ of ALLETE or a Subsidiary thereof at the time
the Options are exercised. Subject to the foregoing and to subsection (b)
hereof, after vesting, the Options may be exercised in whole or in part from
time to time by written or electronic notice of exercise delivered to
Computershare, such notice to be received and effective not later than the
Expiration Date, specifying the number of Shares to be purchased. In the event
that the Expiration Date shall fall on a day that is not a regular business day
at ALLETE's executive offices in Duluth, Minnesota, such notice must be
delivered to Computershare no later than the last regular business day prior to
the Expiration Date.
(b) EXERCISE UPON DEATH, RETIREMENT, OR DISABILITY; FORFEITURE UPON TERMINATION OF EMPLOYMENT FOR CAUSE, DEMOTION, OR UNSATISFACTORY JOB PERFORMANCE.
(1) If the Participant retires pursuant to the terms of a tax- qualified retirement plan of ALLETE or a Subsidiary or upon such other retirement as may be approved by the Committee, the Options, to the extent not yet vested, shall vest in full and all Options covered by the Grant, to the extent not yet exercised, shall be exercisable by the Participant in full at any time during the three-year period immediately following his retirement, but in no event after the Expiration Date.
(2) In the event of the death of the Participant while in the employ of ALLETE or a Subsidiary, the Options, to the extent not yet vested, shall vest in full and all Options covered by the Grant, to the extent not yet exercised, shall be exercisable by the executors, administrators, legatees or distributees of his estate, as the case may be, in full at any time during the one-year period following his death, but in no event after the Expiration Date.
(3) In the event of the termination of the employment of the Participant due to Disability (as defined in Section 22(e)(3) of the Code), the Options, to the extent not yet vested, shall vest in full and all Options covered by the Grant, to the extent not yet exercised, shall be exercisable in full at any time during the one-year period following such termination of employment, but in no event after the Expiration Date.
(4) If the Participant's employment or service with the Company terminates for any reason other than for Cause (defined below). Participant shall have ninety (90) days from the date of termination of employment or service to exercise vested options and all unvested options will be forfeited as of the date of termination.
(5) If the Participant's employment with the Company or any Subsidiary is terminated for Cause, all outstanding unvested and vested Options shall be forfeited as of the date of such termination of employment or service. Cause is defined as (a) any conduct by the Participant that causes or threatens a loss to the Company; (b) any violation of any Company policy; (c) Participant's refusal or neglect to substantially perform his or her obligations and services; (d) violation of the Company's code of business conduct and ethics; or (e) Participant's arrest, conviction or admission of any crime involving injury to persons, misappropriation of money, or damage to property.
(6) If the Participant is demoted, or if ALLETE or a Business Unit determines in its sole discretion that the Participants job performance is unsatisfactory, ALLETE reserves the right to cancel any grants and unvested options.
(7) Notwithstanding the foregoing, the Committee may, in its discretion and at any time, provide that the Options may be exercisable during a period of up to 5 years following termination of employment but in no event after the Expiration Date.
2. RATIFICATION OF ACTIONS. By receiving the Grant or other benefit under the Plan, the Participant and each person claiming under or through him shall be conclusively deemed to have indicated the Participant's acceptance and ratification of, and consent to, any action taken under the Plan or the Grant by ALLETE, the Board or the Committee.
3. NOTICES. Any notice hereunder to ALLETE shall be addressed to its office, 30 West Superior Street, Duluth, Minnesota 55802, Attention: Manager - Executive Compensation and Employee Benefits, Human Resources, and any notice hereunder to the Participant shall be directed to the Participant's address as indicated by ALLETE's records, subject to the right of either party to designate at any time hereafter in writing some other address.
4. DEFINITIONS. Capitalized terms not otherwise defined herein shall have the meanings given them in the Plan.
5. GOVERNING LAW AND SEVERABILITY. To the extent not preempted by Federal law, the Grant will be governed by and construed in accordance with the laws of the State of Minnesota, without regard to conflicts of law provisions. In the event any provision of the Grant shall be held illegal or invalid for any reason, the illegality or invalidity shall not affect the remaining parts of the Grant, and the Grant shall be construed and enforced as if the illegal or invalid provision had not been included.
EXHIBIT 10(m)7
ALLETE 2006 Form 10-K
ALLETE
EXECUTIVE LONG-TERM INCENTIVE COMPENSATION PLAN
PERFORMANCE SHARE GRANT
EFFECTIVE 2007
[ELIGIBLE EXECUTIVE EMPLOYEES]
Name
SS #
In accordance with the terms of ALLETE's Executive Long-Term Incentive Compensation Plan (the "Plan"), as determined by and through the Executive Compensation Committee of ALLETE's Board of Directors, ALLETE hereby grants to you (the "Participant") Performance Shares, as set forth below, subject to the terms and conditions set forth in this Grant (including Annexes A and B hereto and all documents incorporated herein by reference):
Number of Performance Shares Granted:
Date of Grant:
Performance Period:
Performance Goals: See Annex B
This Grant is made in accordance with the Plan, which was approved by ALLETE's shareholders at the 2005 Annual Meeting.
Further terms and conditions of the Grant are set forth in Annex A hereto and Performance Goals are set forth in Annex B hereto, which are integral parts of this Grant.
All terms, provisions and conditions applicable to the Performance Shares set forth in the Plan and not set forth herein are incorporated by reference. To the extent any provision hereof is inconsistent with a provision of the Plan, the provisions of the Plan will govern.
IN WITNESS WHEREOF, ALLETE has caused this Grant to be executed by its Chairman, President and Chief Executive Officer as of the date and year first above written.
ALLETE
Attachments: Annex A and Annex B
ANNEX A
TO
ALLETE
EXECUTIVE LONG-TERM INCENTIVE COMPENSATION PLAN
PERFORMANCE SHARE GRANT
EFFECTIVE 2007
[ELIGIBLE EXECUTIVE EMPLOYEES]
1. FURTHER TERMS AND CONDITIONS OF PERFORMANCE SHARES. The Grant of Performance Shares evidenced by the Grant to which this is annexed is subject to the following additional terms and conditions:
(a) DIVIDEND EQUIVALENTS. The Participant shall receive Dividend Equivalents with respect to the number of Performance Shares subject to the Grant. Dividend Equivalents shall be calculated and credited to the Participant at the end of the Performance Period. The Dividend Equivalents shall be in the form of additional Performance Shares, which shall be added to the number of Performance Shares subject to the Grant, and which shall equal the number of Shares (including fractional Shares) that could be purchased on the dividend payment dates, based on the closing sale price as reported in the consolidated transaction reporting system on that date, with cash dividends that would have been paid on Performance Shares, if such Performance Shares were Shares.
(b) SATISFACTION OF GOALS. At the end of the Performance Period, the Executive Compensation Committee (the "Committee") shall determine the extent to which the Performance Goals have been met. The Participant will not be credited with any Performance Shares if the threshold level has not been met. Subject to the provisions of subsection (d) hereof and to provisions in the Plan for change in control, percentages of the Performance Share grant shall be credited to the Participant as follows: If the threshold level has been met, 50% of the Performance Shares (as increased by the Dividend Equivalents) shall be credited to the Participant. If the target level has been met, 100% of the Performance Shares (as increased by the Dividend Equivalents) shall be credited to the Participant. If the superior level has been met, 200% of the Performance Shares (as increased by the Dividend Equivalents) shall be credited to the Participant. Straight line interpolation will be used to determine earned awards based on achievement of goals between the threshold, target and superior levels.
(c) PAYMENT. Subject to the provisions of subsection (d) hereof and to provisions in the Plan for change in control, Performance Shares as determined by the Committee according to subsection (b) hereof shall be paid out 100% (as increased by the Dividend Equivalents) within two and one half months after the end of the Performance Period and after the Committee has determined the extent to which Performance Goals have been met. Payment shall be made, after withholding Performance Shares equal in value to the Participant's income tax obligation via a deposit of ALLETE common stock into an Invest Direct account. Performance Share awards shall not vest until paid.
(d) PAYMENT UPON DEATH, RETIREMENT OR DISABILITY; FORFEITURE OF UNVESTED SHARES UPON DEMOTION, UNSATISFACTORY JOB PERFORMANCE OR OTHER TERMINATION OF EMPLOYMENT.
(1) During a Performance Period (i) if the Participant retires pursuant to
the terms of a tax qualified retirement plan of ALLETE or a Subsidiary
or upon such other retirement as may be approved by the Committee,
(ii) in the event of the death of the Participant while in the employ
of ALLETE or a Subsidiary, or (iii) in the event of the termination of
the employment of the Participant due to Disability (as defined in
Section 22(e)(3) of the Code), the Participant (or the Participant's
beneficiary or estate) shall receive a payment of any Performance
Shares (as increased by the Dividend Equivalents) after the end of the
Performance Period, promptly after the Committee has determined the
extent to which Performance Goals have been met. The payment shall be
prorated based upon the number of whole calendar months within the
Performance Period which had elapsed as of the date of death,
retirement or termination due to Disability in relation to the number
of calendar months in the full Performance Period. A whole month is
counted in the calculation if the Participant was in the position as
of the 15th of the month.
(2) After the end of a Performance Period, but before any or all
Performance Shares have been paid, if as specified in subsection
(d)(1) above, a Participant retires, dies or Participant's employment
is terminated due to Disability, the Participant (or the Participant's
beneficiary or estate) shall be entitled to a full payout of all
Performance Shares (as increased by the Dividend Equivalents), which
shall be paid out at the next scheduled performance share payment
date.
(3) If prior to payment of all Performance Shares, the Participant is demoted, or ALLETE or a Business Unit determines, in its sole discretion, that the Participant's job performance is unsatisfactory, ALLETE reserves the right to cancel or amend the Participant's grant relating to any unpaid Performance Shares, with the result that some portion or all of the Participant's unpaid Performance Shares are forfeited.
(4) If the Participant's employment with ALLETE or any Subsidiary terminates for any reason other than death, Disability or retirement, as specified in subsection (d)(1) hereof, all Performance Shares and related Dividend Equivalents to the extent not yet paid shall, except as otherwise provided by the Committee, be forfeited on the date of such other termination of employment.
2. RATIFICATION OF ACTIONS. By receiving the Grant or other benefit under the Plan, the Participant and each person claiming under or through Participant shall be conclusively deemed to have indicated the Participant's acceptance and ratification of, and consent to, any action taken under the Plan or the Grant by ALLETE, the Board or the Committee.
3. NOTICES. Any notice hereunder to ALLETE shall be addressed to its office, 30 West Superior Street, Duluth, Minnesota 55802, Attention: Manager - Executive Compensation and Employee Benefits, Human Resources, and any notice hereunder to the Participant shall be
directed to the Participant's address as indicated by ALLETE's records, subject to the right of either party to designate at any time hereafter in writing some other address.
4. DEFINITIONS. Capitalized terms not otherwise defined herein shall have the meanings given them in the Plan.
5. GOVERNING LAW AND SEVERABILITY. To the extent not preempted by the Federal law, the Grant will be governed by and construed in accordance with the laws of the State of Minnesota, without regard to conflicts of law provisions. In the event any provision of the Grant shall be held illegal or invalid for any reason, the illegality or invalidity shall not affect the remaining parts of the Grant, and the Grant shall be construed and enforced as if the illegal or invalid provision had not been included.
ANNEX B
TO
ALLETE
EXECUTIVE LONG-TERM INCENTIVE COMPENSATION PLAN
PERFORMANCE SHARE GRANT
EFFECTIVE 2007
[ELIGIBLE EXECUTIVE EMPLOYEES]
Total Shareholder Return (TSR) computed over the three-year period.
If ALLETE's TSR ranking is 3rd or higher among a peer group of 16 companies (superior performance), 200% of the Performance Share grant will be awarded. If ALLETE's TSR performance ranks 7th among the peer group (target performance), 100% of the Grant will be awarded. If ALLETE's TSR performance ranks 10th (threshold performance), 50% of the Grant will be awarded. If TSR performance is below threshold, no Performance Shares will be awarded. Straight-line interpolation will be used to determine earned awards based on the TSR ranking between threshold, target and superior.
----------------------------- -------------------- ----------------------------
TSR RANK PERF. LEVEL PAYOUT %
----------------------------- -------------------- ----------------------------
1 [Graphic Omitted - 200.0%
----------------------------- -------------------- ----------------------------
2 Arrow Pointing Up] 200.0%
----------------------------- -------------------- ----------------------------
3 Superior 200.0%
----------------------------- -------------------- ----------------------------
4 [Graphic Omitted - 175.0%
----------------------------- -------------------- ----------------------------
5 Arrow Pointing Up] 150.0%
----------------------------- -------------------- ----------------------------
6 125.0%
----------------------------- -------------------- ----------------------------
7 Target 100.0%
----------------------------- -------------------- ----------------------------
8 [Graphic Omitted - 83.3%
----------------------------- -------------------- ----------------------------
9 Arrow Pointing Up] 66.7%
----------------------------- -------------------- ----------------------------
10 Threshold 50.0%
----------------------------- -------------------- ----------------------------
11 0%
----------------------------- -------------------- ----------------------------
12 0%
----------------------------- -------------------- ----------------------------
13 0%
----------------------------- -------------------- ----------------------------
14 0%
----------------------------- -------------------- ----------------------------
15 0%
----------------------------- -------------------- ----------------------------
16 0%
----------------------------- -------------------- ----------------------------
17 0%
----------------------------- -------------------- ----------------------------
|
EXHIBIT 10(m)8
ALLETE 2006 FORM 10-K
ALLETE EXECUTIVE LONG-TERM INCENTIVE COMPENSATION PLAN
FORM OF LONG-TERM CASH INCENTIVE AWARD
EFFECTIVE 2007
[ELIGIBLE EXECUTIVE EMPLOYEES]
Base Salary $
TIMES
Award Opportunity (percent of base salary) %
-------
EQUALS
Target Award Opportunity $
TIMES
Strategic Non-financial Goals (0% - 120%)
EQUALS
Cash Incentive Award $
-------
|
Vesting Period:
EXHIBIT 10(m)9
ALLETE 2006 FORM 10-K
ALLETE
EXECUTIVE LONG-TERM INCENTIVE COMPENSATION PLAN
STOCK GRANT
EFFECTIVE 2007
[ELIGIBLE EXECUTIVE EMPLOYEES]
Name
SS #
In accordance with the terms of ALLETE's Executive Long-Term Incentive Compensation Plan (the "Plan"), as determined by and through the Executive Compensation Committee of ALLETE's Board of Directors, ALLETE hereby grants to you (the "Participant") the right to receive ALLETE Common Stock, as set forth below, subject to the terms and conditions set forth in this Grant (including Annex A hereto and all documents incorporated herein by reference):
Number of Shares of ALLETE Common Stock:
Date of Grant:
Vesting Period:
This Grant is made in accordance with the Plan, which was approved by ALLETE's shareholders at the 2005 Annual Meeting.
Further terms and conditions of the Grant are set forth in Annex A hereto, which is an integral part of this Grant.
All terms, provisions and conditions set forth in the Plan and not set forth herein are incorporated by reference. To the extent any provision hereof is inconsistent with a provision of the Plan, the provisions of the Plan will govern.
IN WITNESS WHEREOF, ALLETE has caused this Grant to be executed by its Chairman, President and Chief Executive Officer as of the date and year first above written.
ALLETE
Attachment: Annex A
ANNEX A
TO
ALLETE
EXECUTIVE LONG-TERM INCENTIVE COMPENSATION PLAN
STOCK GRANT
EFFECTIVE 2007
[ELIGIBLE EXECUTIVE EMPLOYEES]
1. FURTHER TERMS AND CONDITIONS OF STOCK GRANT. The Grant of Shares evidenced by the Grant to which this is annexed is subject to the following additional terms and conditions:
(a) DIVIDEND EQUIVALENTS. The Participant shall not receive Dividend Equivalents with respect to the number of Shares subject to the Grant.
(b) PAYMENT. Subject to the provisions of subsection (c) hereof, payment shall be made within two and one half months after the end of the vesting period, after withholding Shares equal in value to the Participant's income tax obligation via a deposit of ALLETE common stock into an account in the ALLETE Invest Direct plan.
(c) PAYMENT UPON DEATH, RETIREMENT, DISABILITY, FORFEITURE OF UNVESTED SHARES UPON UNSATISFACTORY JOB PERFORMANCE, OR OTHER TERMINATION OF EMPLOYMENT.
(1) During the Vesting Period (i) if the Participant retires pursuant to the terms of a tax qualified retirement plan of ALLETE or a Subsidiary or upon such other retirement as may be approved by the Committee, (ii) in the event of the death of the Participant while in the employ of ALLETE or a Subsidiary, or (iii) in the event of the termination of the employment of the Participant due to Disability (as defined in Section 22(e)(3) of the Code), all unvested Shares of Stock shall vest and be paid within two and one half months after such event to the Participant (or the Participant's beneficiary or estate). The payment shall be prorated based upon the number of whole calendar months within the three year Vesting Period which had elapsed as of the date of death, retirement or termination due to Disability in relation to the number of calendar months in the three year Vesting Period. A whole month is counted in the calculation if the Participant was in the position as of the 15th of the month.
(2) If prior to payment of all Shares, the Participant is demoted, or ALLETE or a Business Unit determines, in its sole discretion, that the Participant's job performance is unsatisfactory, ALLETE reserves the right to cancel or amend the Participant's grant relating to any unpaid Shares, with the result that some portion or all of the Participant's unpaid Shares are forfeited.
(3) If the Participant's employment with ALLETE or any Subsidiary terminates for any reason other than death, Disability or retirement, as specified in subsection (c)(1) hereof, all Shares to the extent not yet vested shall, except as otherwise provided by the Committee, be forfeited on the date of such other termination of employment.
2. RATIFICATION OF ACTIONS. By receiving the Grant or other benefit under the Plan, the Participant and each person claiming under or through Participant shall be conclusively deemed to have indicated the Participant's acceptance and ratification of, and consent to, any action taken under the Plan or the Grant by ALLETE, the Board or the Committee.
3. NOTICES. Any notice hereunder to ALLETE shall be addressed to ALLETE, 30 West Superior Street, Duluth, Minnesota 55802, Attention: Manager - Executive Compensation and Employee Benefits, Human Resources, and any notice hereunder to the Participant shall be directed to the Participant's address as indicated by ALLETE's records, subject to the right of either party to designate at any time hereafter in writing some other address.
4. DEFINITIONS. Capitalized terms not otherwise defined herein shall have the meanings given them in the Plan.
5. GOVERNING LAW AND SEVERABILITY. To the extent not preempted by the Federal law, the Grant will be governed by and construed in accordance with the laws of the State of Minnesota, without regard to conflicts of law provisions. In the event any provision of the Grant shall be held illegal or invalid for any reason, the illegality or invalidity shall not affect the remaining parts of the Grant, and the Grant shall be construed and enforced as if the illegal or invalid provision had not been included.
EXHIBIT 10(n)4
ALLETE 2006 Form 10-K
AMENDMENT TO THE
ALLETE DIRECTOR STOCK PLAN
EFFECTIVE FEBRUARY 15, 2007
The ALLETE Director Stock Plan, dated May 9, 1995, as amended, is amended as follows:
1. Effective February 15, 2007, Section V.B. is DELETED and REPLACED with the following:
B. Each Director shall receive on the first business day in June following each annual meeting of shareholders, a Stock Payment equal in value to $60,000. To provide such Stock Payment to each Director, the Company shall cause shares of Common Stock to be purchased in the market and deposited to said Director's Dividend Reinvestment Plan Account on such date as a portion of the Annual Retainer payable to such Director for the Plan Year in which such date occurs. Any fraction of a Share shall be disregarded and the remaining amount shall be paid in cash. The cash portion of the Annual Retainer for such Plan Year shall be paid to Directors at such times and in such manner as may be determined by the Board of Directors. Directors joining the Board during the Plan Year after the first business day in June will receive their Stock Payment on the first business day following the effective date of their election or appointment to the Board.
ALLETE, INC.
By: /s/ Donald J. Shippar
---------------------------------------------
Donald J. Shippar
Chairman, President & Chief Executive Officer
ATTEST:
By: /s/ Deborah A. Amberg
--------------------------------------------------
Deborah A. Amberg
Senior Vice President, General Counsel & Secretary
|
EXHIBIT 10(n)6
ALLETE 2006 FORM 10-K
ALLETE, INC.
NON-MANAGEMENT DIRECTOR COMPENSATION
EFFECTIVE FEBRUARY 15, 2007
--------------------------------------------------------------------------------
-----------------------------------------------------------------------
BOARD RETAINERS <F1><F2>
Stock $60,000
Cash $30,000
-----------------------------------------------------------------------
COMMITTEE CASH RETAINERS <F1><F2>
Audit $9,000
Executive Compensation $7,500
Corporate Governance & Nominating $7,500
-----------------------------------------------------------------------
CHAIR CASH RETAINERS <F1><F2>
Audit $8,500
Executive Compensation $5,500
Corporate Governance & Nominating $4,500
-----------------------------------------------------------------------
-----------------------------------------------------------------------
LEAD DIRECTOR <F1><F2><F3>
Board Stock Retainer $60,000
Board Cash Retainer $30,000
Lead Director Cash Retainer $25,000
-----------------------------------------------------------------------
<F1> Cash retainers may be deferred under the Director Compensation Deferral
Plan.
<F2> Cash retainers may be elected to be received in ALLETE stock.
<F3> Lead Director is not eligible for other committee or chair retainers.
|
EXHIBIT 12
ALLETE
COMPUTATION OF RATIOS OF EARNINGS TO FIXED CHARGES (UNAUDITED)
FOR THE YEAR ENDED DECEMBER 31 2006 2005 2004 2003 2002
--------------------------------------------------------------------------------------------------------------------------
MILLIONS EXCEPT RATIOS
Income from Continuing Operations
Before Minority Interest and Income Taxes $128.2 $19.8 $ 57.0 $ 49.5 $ 37.9
Less: Minority Interest <F1> - - 2.1 2.6 1.0
Undistributed Income from Less than 50%
Owned Equity Investment 2.3 - - 2.9 4.7
--------------------------------------------------------------------------------------------------------------------------
125.9 19.8 54.9 44.0 32.2
--------------------------------------------------------------------------------------------------------------------------
Fixed Charges
Interest on Long-Term Debt 22.2 23.1 60.3 70.0 73.9
Capitalized Interest 0.6 0.3 0.7 1.2 0.8
Other Interest Charges 5.3 3.5 8.7 4.3 5.3
Interest Component of All Rentals 2.0 2.8 3.5 8.0 9.9
--------------------------------------------------------------------------------------------------------------------------
Total Fixed Charges 30.1 29.7 73.2 83.5 89.9
--------------------------------------------------------------------------------------------------------------------------
Earnings Before Income Taxes and Fixed Charges
(Excluding Capitalized Interest) $155.4 $49.2 $127.4 $126.3 $121.3
--------------------------------------------------------------------------------------------------------------------------
Ratio of Earnings to Fixed Charges 5.16 1.66 1.74 1.51 1.35
--------------------------------------------------------------------------------------------------------------------------
<F1> Pre-tax income of subsidiaries that have not incurred fixed charges.
|
97 ALLETE 2006 Form 10-K
EXHIBIT 21
ALLETE 2006 Form 10-K
SUBSIDIARIES OF THE REGISTRANT
(AS OF DECEMBER 31, 2006)
(REPORTED UNDER ITEM 601 OF REGULATION S-K)
STATE OR COUNTRY
NAME OF ORGANIZATION
-------------------------------------------------------------- ----------------
ALLETE, Inc. (D.B.A. ALLETE; MINNESOTA POWER; Minnesota
MINNESOTA POWER, INC.; MINNESOTA POWER & LIGHT COMPANY;
MPEX; MPEX A DIVISION OF MINNESOTA POWER)
ALLETE Automotive Services, LLC Minnesota
ALLETE Capital II Delaware
ALLETE Capital III Delaware
ALLETE Properties, LLC (D.B.A. ALLETE PROPERTIES) Minnesota
ALLETE Commercial, LLC Florida
Cape Coral Holdings, Inc. Florida
Cape Properties, Inc. Florida
Lehigh Acquisition Corporation Delaware
Florida Landmark Communities, Inc. Florida
Cliffside Properties, Inc. California
Enterprise Lehigh, Inc. Florida
Lehigh Corporation Florida
Lehigh Land & Investment, Inc. Florida
Mardem, LLC Florida
Palm Coast Holdings, Inc. Florida
Port Orange Holdings, LLC Florida
Interlachen Lakes Estates, Inc. Florida
SRC of Florida, Inc. Florida
Sundowner Properties, Inc. Pennsylvania
Palm Coast Forest, LLC Florida
Palm Coast Land, LLC Florida
Tomoka Holdings, LLC Florida
Winter Haven Citi Centre, LLC Florida
ALLETE Water Services, Inc. Minnesota
Florida Water Services Corporation Florida
Auto Replacement Property, LLC Indiana
Energy Replacement Property, LLC Minnesota
Georgia Water Services Corporation Georgia
Energy Land, Incorporated Wisconsin
Lakeview Financial Corporation I Minnesota
Lakeview Financial Corporation II Minnesota
Logistics Coal, LLC Minnesota
Minnesota Power Enterprises, Inc. Minnesota
BNI Coal, Ltd. North Dakota
MP Affiliate Resources, Inc. Minnesota
Rainy River Energy Corporation Minnesota
Rainy River Energy Corporation - Wisconsin Wisconsin
Synertec, Incorporated Minnesota
Upper Minnesota Properties, Inc. Minnesota
Upper Minnesota Properties - Development, Inc. Minnesota
Upper Minnesota Properties - Irving, Inc. Minnesota
Upper Minnesota Properties - Meadowlands, Inc. Minnesota
Meadowlands Affordable Housing Limited Partnership Minnesota
MP Investments, Inc. Delaware
RendField Land Company, Inc. Minnesota
Superior Water, Light and Power Company Wisconsin
|
EXHIBIT 23(a)
ALLETE 2006 Form 10-K
CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
We hereby consent to the incorporation by reference in the Registration Statements on Form S-3 (Nos. 333-02109, 333-41882, 333-57104) and Form S-8 (Nos. 333-16445, 333-16463, 333-82901, 333-91348, 333-105225, 333-124455) of ALLETE, Inc. of our report dated February 12, 2007, except as to Note 7 for which the date is February 15, 2007, relating to the consolidated financial statements, financial statement schedule, management's assessment of the effectiveness of internal control over financial reporting and the effectiveness of internal control over financial reporting, which appears in this Form 10-K.
PricewaterhouseCoopers LLP
Minneapolis, Minnesota
February 15, 2007
EXHIBIT 23(b)
ALLETE 2006 Form 10-K
CONSENT OF GENERAL COUNSEL
The statements of law and legal conclusions under "Item 1. Business" in ALLETE's Annual Report on Form 10-K for the year ended December 31, 2006, 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. 333-02109, 333-41882 and 333-57104 on Form S-3, and Registration Statement Nos. 333-16445, 333-16463, 333-82901, 333-91348, 333-105225 and 333-124455 on Form S-8.
Deborah A. Amberg
Deborah A. Amberg
Duluth, Minnesota
February 15, 2007
EXHIBIT 31(a)
ALLETE 2006 FORM 10-K
RULE 13a-14(a)/15d-14(a) CERTIFICATION BY THE CHIEF EXECUTIVE OFFICER
PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002
I, Donald J. Shippar, Chairman, President and Chief Executive Officer of ALLETE, Inc. (ALLETE), certify that:
1. I have reviewed this annual report on Form 10-K for the fiscal year ended December 31, 2006, of ALLETE;
2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
c. Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
d. Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
Date: February 15, 2007 Donald J. Shippar
-----------------------------------------------
Donald J. Shippar
Chairman, President and Chief Executive Officer
|
EXHIBIT 31(b)
ALLETE 2006 FORM 10-K
RULE 13a-14(a)/15d-14(a) CERTIFICATION BY THE CHIEF FINANCIAL OFFICER
PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002
I, Mark A. Schober, Senior Vice President and Chief Financial Officer of ALLETE, Inc. (ALLETE), certify that:
1. I have reviewed this annual report on Form 10-K for the fiscal year ended December 31, 2006, of ALLETE;
2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
c. Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
d. Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
Date: February 15, 2007 Mark A. Schober
-------------------------------------------------
Mark A. Schober
Senior Vice President and Chief Financial Officer
|
EXHIBIT 32
ALLETE 2006 FORM 10-K
SECTION 1350 CERTIFICATION OF ANNUAL REPORT
BY THE CHIEF EXECUTIVE OFFICER AND CHIEF FINANCIAL OFFICER
PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, 18 U.S.C. Section 1350, each of the undersigned officers of ALLETE, Inc. (ALLETE), does hereby certify that:
1. The Annual Report on Form 10-K of ALLETE for the fiscal year ended December 31, 2006, (Report) fully complies with the requirements of Section 13(a) of the Securities Exchange Act of 1934 (15 U.S.C. 78m); and
2. The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of ALLETE.
Date: February 15, 2007 Donald J. Shippar
-------------------------------------------------
Donald J. Shippar
Chairman, President and Chief Executive Officer
Date: February 15, 2007 Mark A. Schober
-------------------------------------------------
Mark A. Schober
Senior Vice President and Chief Financial Officer
|
This certification shall not be deemed "filed" for purposes of Section 18 of the Securities Exchange Act of 1934 or otherwise subject to liability pursuant to that section. Such certification shall not be deemed to be incorporated by reference into any filing under the Securities Act of 1933 or the Securities Exchange Act of 1934, except to the extent that ALLETE specifically incorporates it by reference.
A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to ALLETE and will be retained by ALLETE and furnished to the Securities and Exchange Commission or its staff upon request.
EXHIBIT 99
ALLETE 2006 Form 10-K
[ALLETE LOGO]
For Release: February 16, 2007
CONTACT: Eric Olson
218-723-3947
eolson@allete.com
INVESTOR Tim Thorp
CONTACT: 218-723-3953
tthorp@allete.com
NEWS
ALLETE REPORTS 2006 EARNINGS INCREASE OF 23%;
HIGHER EARNINGS PROJECTED IN 2007
|
ALLETE, Inc. (NYSE: ALE) today reported 2006 earnings from continuing operations of $2.77 per diluted share, compared with 64 cents in 2005. Excluding transactions in 2005 not representative of ongoing operations (described below), 2006 earnings from continuing operations increased 23 percent over the adjusted 2005 diluted earnings per share of $2.26.
ALLETE in 2006 recorded net income of $76.4 million on revenue of $767.1 million, compared to 2005 income of $13.3 million and revenue of $737.4 million. Financial results in 2005 were impacted by three one-time transactions: a $50.4 million after-tax charge for the assignment of the Kendall County power purchase agreement and two non-recurring tax benefits totaling $6.2 million.
Real estate income in 2006 increased 30 percent to $22.8 million, while ALLETE's energy businesses recorded $52.4 million for the year, a 10 percent increase over 2005 excluding the Kendall County charge.
"Increased earnings contributions from both our core real estate and energy businesses resulted in another year of strong earnings growth," said ALLETE Chairman, President and CEO Donald J. Shippar. "ALLETE Properties' performance was on track, with sales contracts closing on schedule. Earnings from our American Transmission Company (ATC) investment began ramping up and energy sales remain at high levels."
Initial returns from ALLETE's ATC investment, the absence of operating losses from Kendall County, and increased demand from Minnesota Power's industrial customers contributed to an earnings increase at ALLETE's energy business in 2006. At the end of 2006, ALLETE had an investment balance of $53.7 million in ATC, representing an ownership interest of approximately seven percent.
ALLETE's higher real estate earnings included recognition of deferred profit from past years' sales at the Town Center at Palm Coast development project, as well as 2006 sales at both the Town Center and Palm Coast Park projects. At the close of 2006, ALLETE Properties had about $114 million in future land sales under contract. ALLETE Properties' third major real estate development, Ormond Crossings, received development order approval late in 2006.
Income at ALLETE's "other" business segment rose by $5.4 million in 2006 compared to 2005 when excluding last year's tax benefits. Higher earnings on cash and short-term investments in 2006 and the absence of impairments in the emerging technology investment portfolio in 2006 versus 2005 contributed to the increase.
- more -
"Earnings growth is a priority for our corporation," Shippar said. "We're proud of the key milestones ALLETE achieved during the year that lay the groundwork for future success." These achievements include:
- Starting construction on an aggressive air emissions control plan with
current cost recovery
- Purchasing electricity from a new 50-megawatt wind facility in North
Dakota and signing an agreement to purchase power from a second
48-megawatt wind facility
- Signing a long-term 70-megawatt contract with PolyMet Mining
- Receiving development order approval for ALLETE Properties' Ormond
Crossings real estate project
- Closing the first sales contracts at ALLETE Properties' Palm Coast Park
development.
Shippar noted that the 13 percent dividend increase on ALLETE common stock announced on January 26th reflects the positive outlook for the company's future shared by the board of directors and management.
"We project that in 2007 ALLETE's earnings per share from continuing operations will be in the range of $2.95 to $3.05," Shippar said. "Our portfolio of valuable real estate and the growth prospects in our energy business give us great confidence for 2007 and beyond."
THE STATEMENTS CONTAINED IN THIS RELEASE AND STATEMENTS THAT ALLETE MAY MAKE ORALLY IN CONNECTION WITH THIS RELEASE THAT ARE NOT HISTORICAL FACTS, ARE FORWARD-LOOKING STATEMENTS. ACTUAL RESULTS MAY DIFFER MATERIALLY FROM THOSE PROJECTED IN THE FORWARD-LOOKING STATEMENTS. THESE FORWARD-LOOKING STATEMENTS INVOLVE RISKS AND UNCERTAINTIES AND INVESTORS ARE DIRECTED TO THE RISKS DISCUSSED IN DOCUMENTS FILED BY ALLETE WITH THE SECURITIES AND EXCHANGE COMMISSION.
###
ALLETE - 30 WEST SUPERIOR STREET, DULUTH, MINNESOTA 55802
WWW.ALLETE.COM
ALLETE, INC.
CONSOLIDATED STATEMENT OF INCOME
FOR THE PERIODS ENDED DECEMBER 31, 2006 AND 2005
Millions Except Per Share Amounts
QUARTER ENDED YEAR TO DATE
2006 2005 2006 2005
------------------------------------------------------------------------------------------------------------------------------------
OPERATING REVENUE $197.2 $192.3 $767.1 $737.4
------------------------------------------------------------------------------------------------------------------------------------
OPERATING EXPENSES
Fuel and Purchased Power 69.8 71.2 281.7 273.1
Operating and Maintenance 76.0 81.7 296.0 293.5
Kendall County Charge - - - 77.9
Depreciation 12.1 12.1 48.7 47.8
------------------------------------------------------------------------------------------------------------------------------------
Total Operating Expenses 157.9 165.0 626.4 692.3
------------------------------------------------------------------------------------------------------------------------------------
OPERATING INCOME FROM CONTINUING OPERATIONS 39.3 27.3 140.7 45.1
------------------------------------------------------------------------------------------------------------------------------------
OTHER INCOME (EXPENSE)
Interest Expense (7.3) (6.3) (27.4) (26.4)
Other 6.1 3.4 14.9 1.1
------------------------------------------------------------------------------------------------------------------------------------
Total Other Expense (1.2) (2.9) (12.5) (25.3)
------------------------------------------------------------------------------------------------------------------------------------
INCOME FROM CONTINUING OPERATIONS
BEFORE MINORITY INTEREST AND INCOME TAXES 38.1 24.4 128.2 19.8
MINORITY INTEREST 1.4 0.3 4.6 2.7
------------------------------------------------------------------------------------------------------------------------------------
INCOME FROM CONTINUING OPERATIONS
BEFORE INCOME TAXES 36.7 24.1 123.6 17.1
INCOME TAX EXPENSE (BENEFIT) 13.7 (0.1) 46.3 (0.5)
------------------------------------------------------------------------------------------------------------------------------------
INCOME FROM CONTINUING OPERATIONS 23.0 24.2 77.3 17.6
LOSS FROM DISCONTINUED OPERATIONS - NET OF TAX (0.4) (3.2) (0.9) (4.3)
------------------------------------------------------------------------------------------------------------------------------------
NET INCOME $ 22.6 $ 21.0 $ 76.4 $ 13.3
------------------------------------------------------------------------------------------------------------------------------------
AVERAGE SHARES OF COMMON STOCK
Basic 27.9 27.5 27.8 27.3
Diluted 28.0 27.6 27.9 27.4
------------------------------------------------------------------------------------------------------------------------------------
BASIC EARNINGS (LOSS) PER SHARE OF COMMON STOCK
Continuing Operations $0.82 $0.89 $2.78 $0.65
Discontinued Operations (0.01) (0.12) (0.03) (0.16)
------------------------------------------------------------------------------------------------------------------------------------
$0.81 $0.77 $2.75 $0.49
------------------------------------------------------------------------------------------------------------------------------------
DILUTED EARNINGS (LOSS) PER SHARE OF COMMON STOCK
Continuing Operations $0.82 $0.88 $2.77 $0.64
Discontinued Operations (0.01) (0.12) (0.03) (0.16)
------------------------------------------------------------------------------------------------------------------------------------
$0.81 $0.76 $2.74 $0.48
------------------------------------------------------------------------------------------------------------------------------------
DIVIDENDS PER SHARE OF COMMON STOCK $0.3625 $0.3150 $1.4500 $1.2450
------------------------------------------------------------------------------------------------------------------------------------
|
CONSOLIDATED BALANCE SHEET
FOR THE PERIODS ENDED DECEMBER 31, 2006 AND 2005
Millions
2006 2005
----------------------------------------------------------------------
ASSETS
Cash and Cash Equivalents $ 44.8 $ 89.6
Short-Term Investments 104.5 116.9
Other Current Assets 138.4 167.0
Property, Plant and Equipment 921.6 860.4
Investments 189.1 117.7
Discontinued Operations - 2.6
Other 135.0 44.6
----------------------------------------------------------------------
TOTAL ASSETS $1,533.4 $1,398.8
----------------------------------------------------------------------
LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities $ 143.5 $ 106.7
Long-Term Debt 359.8 387.8
Other Liabilities 364.3 288.5
Discontinued Operations - 13.0
Shareholders' Equity 665.8 602.8
----------------------------------------------------------------------
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $1,533.4 $1,398.8
----------------------------------------------------------------------
|
QUARTER ENDED YEAR TO DATE
DECEMBER 31, DECEMBER 31,
ALLETE, INC. 2006 2005 2006 2005
------------------------------------------------------------------------------------------------------------------------------------
INCOME (LOSS)
Millions
Regulated Utility <F1> $13.3 $14.4 $46.8 $45.7
Nonregulated Energy Operations <F1><F2> 0.8 (1.2) 3.7 (48.5)
ATC 1.3 - 1.9 -
Real Estate 7.1 3.8 22.8 17.5
Other 0.5 7.2 2.1 2.9
------------------------------------------------------------------------------------------------------------------------------------
Income from Continuing Operations 23.0 24.2 77.3 17.6
Loss from Discontinued Operations (0.4) (3.2) (0.9) (4.3)
------------------------------------------------------------------------------------------------------------------------------------
Net Income $22.6 $21.0 $76.4 $13.3
------------------------------------------------------------------------------------------------------------------------------------
DILUTED EARNINGS (LOSS) PER SHARE
Continuing Operations <F2> $0.82 $0.88 $2.77 $0.64
Discontinued Operations (0.01) (0.12) (0.03) (0.16)
------------------------------------------------------------------------------------------------------------------------------------
$0.81 $0.76 $2.74 $0.48
------------------------------------------------------------------------------------------------------------------------------------
<F1> In 2006, financial results for ALLETE's Taconite Harbor Energy Center are included in the Regulated Utility segment. In 2005,
Taconite Harbor is included in the Nonregulated Energy Operations segment.
<F2> In April 2005, ALLETE recorded a $50.4 million, or $1.84 per diluted share, charge related to the assignment of the Kendall
County power purchase agreement.
|
QUARTER ENDED YEAR TO DATE
DECEMBER 31, DECEMBER 31,
2006 2005 2006 2005
------------------------------------------------------------------------------------------------------------------------------------
STATISTICAL DATA
CORPORATE
Common Stock
High $47.84 $47.36 $49.30 $51.70
Low $42.55 $41.28 $42.55 $35.65
Close $46.54 $44.00 $46.54 $44.00
Book Value $21.90 $20.03 $21.90 $20.03
KILOWATTHOURS SOLD
Millions
Regulated Utility
Retail and Municipals
Residential 300.3 297.4 1,100.4 1,101.6
Commercial 329.3 339.9 1,335.2 1,326.8
Industrial 1,776.5 1,823.0 7,205.6 7,129.8
Municipals 226.5 220.0 910.5 877.3
Other 19.3 19.9 78.7 79.1
------------------------------------------------------------------------------------------------------------------------------------
Total Retail and Municipals 2,651.9 2,700.2 10,630.4 10,514.6
Other Power Suppliers 548.0 276.7 2,152.9 1,141.6
------------------------------------------------------------------------------------------------------------------------------------
Total Regulated Utility 3,199.9 2,976.9 12,783.3 11,656.2
Nonregulated Energy Operations 59.1 361.7 240.4 1,521.3
------------------------------------------------------------------------------------------------------------------------------------
Total Kilowatthours Sold 3,259.0 3,338.6 13,023.7 13,177.5
------------------------------------------------------------------------------------------------------------------------------------
REAL ESTATE
Town Center Development Project
Commercial Square Footage Sold 36,976 - 401,971 643,000
Residential Units 231 - 773 -
Palm Coast Park Development Project
Residential Units - - 200 -
Other Land
Acres Sold 24 44 732 1,102
Lots Sold - - - 7
------------------------------------------------------------------------------------------------------------------------------------
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ALLETE NEWS RELEASE PAGE 5 -------------------------------------------------------------------------------- NON-GAAP FINANCIAL MEASURES ALLETE prepares financial statements in accordance with accounting principles |
generally accepted in the United States (GAAP). Along with this information, ALLETE discloses and discusses certain non-GAAP financial information in its quarterly earnings releases, on investor conference calls, and during investor conferences and related events. Management believes that non-GAAP financial data supplements ALLETE's GAAP financial statements by providing investors with additional information which enhances the investors' overall understanding of ALLETE's financial performance and the comparability of its operating results from period to period. The presentation of this additional information is not meant to be considered in isolation or as a substitute for ALLETE's results of operations prepared and presented in accordance with GAAP.
Financial results for 2005 were significantly impacted by the following transactions:
- A $50.4 million after tax, or $1.84 per share, charge due to the assignment
of the Kendall County power purchase agreement to Constellation Energy
Commodities;
- A $3.7 million, or $0.13 per share, current tax benefit due to a positive
resolution of income tax audit issues; and
- A $2.5 million, or $0.09 per share, deferred tax benefit due to
comprehensive tax planning initiatives.
Since these transactions significantly impacted the financial results from continuing operations in 2005, ALLETE believes that for comparative purposes and a more accurate reflection of its ongoing operations, it is useful to present diluted earnings per share from continuing operations for each applicable period excluding the impact of these items. The table below reconciles actual reported diluted earnings per share from continuing operations to the adjusted results that exclude these transactions in the respective periods.
QUARTER ENDED YEAR TO DATE
DECEMBER 31, DECEMBER 31,
2006 2005 2006 2005
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DILUTED EARNINGS PER SHARE OF COMMON STOCK
Continuing Operations $0.82 $0.88 $2.77 $0.64
Add: Kendall County Charge - - - 1.84
Less: Positive Resolution of Tax Audit Issues - 0.13 - 0.13
Tax Planning Initiatives - 0.09 - 0.09
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$0.82 $0.66 $2.77 $2.26
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[THIS EXHIBIT HAS BEEN FURNISHED AND SHALL NOT BE DEEMED "FILED" FOR PURPOSES OF
SECTION 18 OF THE SECURITIES EXCHANGE ACT OF 1934, NOR SHALL IT BE DEEMED
INCORPORATED BY REFERENCE IN ANY FILING UNDER THE SECURITIES ACT OF 1933, EXCEPT
AS SHALL BE EXPRESSLY SET FORTH BY SPECIFIC REFERENCE IN SUCH FILING.]