Item 1. Business.
Minnesota Power is an operating public utility incorporated under the laws of the State of Minnesota in 1906. Its principal executive office is at 30 West Superior Street, Duluth, Minnesota, 55802; and its telephone number is (218) 722-2641. Minnesota Power has operations in four business segments: (1) electric operations, which include electric and gas services, and coal mining; (2) water services, which include water and wastewater services; (3) automotive services, which include auctions, a finance company and an auto transport company; and (4) investments, which include a securities portfolio, a 21 percent equity investment in a financial guaranty reinsurance company and real estate operations. As of December 31, 1996, the Company and its subsidiaries had approximately 6,500 employees.
Since 1983 Minnesota Power has been diversifying to reduce its reliance on electricity sales to Minnesota's taconite industry and to gain additional earnings growth potential. Acquisitions have been a primary means of diversification. During 1996 the Company purchased the remaining 20 percent minority interest in ADESA, the third largest automobile auction business in the United States, making ADESA a wholly owned subsidiary of the Company. Additionally, the Company acquired five auction businesses to complement and expand its automotive services segment. In April 1996 the Company acquired Palm Coast real estate in Florida adding significantly to its inventory of commercial and residential properties. Water services expanded during 1996 with the acquisition of ISI, a predictive maintenance business that serves the water industry. During 1997 the Company plans to complete the purchase of a small water utility in North Carolina and continues to consider other acquisitions that would complement its businesses, expand its services and contribute to earnings growth.
For a detailed discussion of results of operations and trends, see Management's Discussion and Analysis of Financial Condition and Results of Operations in the Minnesota Power 1996 Annual Report. For business segment information, see Note 1.
The information contained or incorporated by reference in this annual report on Form 10-K reflects a categorization of the Company's business which is different from the categorization used in the annual report on Form 10-K for 1995. Financial data from prior years has been reclassified in this annual report on Form 10-K to present comparable data in all periods.
Electric Operations
Electric operations generate, transmit, distribute and market electricity. In addition, electric operations include coal mining, engineering, construction and maintenance services, and economic development projects within the Company's service area.
- Minnesota Power provides electricity in a 26,000 square mile electric service territory located in northeastern Minnesota. As of December 31, 1996, Minnesota Power was supplying retail electric service to 121,000 customers in 153 cities, towns and communities, and outlying rural areas. The largest city served is Duluth with a population of 85,000 based on the 1990 census. Wholesale electric service for resale is supplied to 13 municipal distribution systems, one private utility and SWL&P.
MPEX is an expansion of the Company's inter-utility marketing group which has been a buyer and seller of capacity and energy for 25 years in the wholesale power market. It was formally established in early 1996 as a new division of Minnesota Power. The customers of MPEX are other power suppliers in the Midwest and Canada. MPEX contracts to provide hourly energy scheduling and power trading services.
- Superior Water, Light and Power Company sells electricity and natural gas, and provides water service in northwestern Wisconsin. As of December 31, 1996, SWL&P served 14,000 electric customers, 11,000 natural gas customers and 10,000 water customers.
- Minnesota Power Enterprises, Inc., a subsidiary of Minnesota Power, was created in 1996 to facilitate the development of the non-regulated services of electric operations. Subsidiaries of Minnesota Power Enterprises, Inc. include BNI Coal, Synertec, Rainy River, Upper Minnesota Properties, Inc. and Minnesota Power Services Group, Inc.
- BNI Coal owns and operates a lignite mine in North Dakota. Two electric generating cooperatives, Minnkota Power and Square Butte, presently consume virtually all of BNI Coal's production of lignite coal under coal supply agreements extending to 2027. Under an agreement with Square Butte, Minnesota Power purchases 71 percent of the output from the Square Butte unit which is capable of generating up to 470 MW. Minnkota Power has an option to extend its coal supply agreement to 2042. (See - Fuel and Note 17.)
- Synertec provides project development, planning, construction management and operating services to new and expanding businesses.
- Rainy River provides engineering, and operating and maintenance services to new and existing generating facilities.
- Upper Minnesota Properties, Inc. has invested in affordable housing projects located in the electric operations' service territory. The Company is also an active participant in a variety of economic development projects throughout the electric operations' service territory providing resources and expertise.
- Minnesota Power Services Group, Inc. includes the Electric Outlet, Inc., a retail store that sells life-style changing electric products, and also researches new products to be offered for sale or distribution.
Electric Sales
The two major industries in Minnesota Power's service territory are taconite production, and paper and wood products manufacturing. These two industries contributed about 43 percent of the Company's electric operating revenue in 1996 and 47 percent in 1995 and 1994.
Over the last five years, 80 percent of the domestic ore consumed by iron and steel plants in the United States has originated from plants within the Company's Minnesota electric service territory. Taconite, an iron-bearing rock of relatively low iron content which is abundantly available in Minnesota, is an important domestic source of raw material for the steel industry. Taconite processing plants use large quantities of electric power to grind the ore-bearing rock and agglomerate and pelletize the iron particles into taconite pellets. Annual taconite production in Minnesota was 46 million tons in 1996, 47 million tons in 1995 and 43 million tons in 1994. The Company estimates that 1997 Minnesota taconite production will be about 47 million tons. While taconite production is expected to continue at annual levels over 40 million tons, the long-term future of this cyclical industry is less certain. Production may decline gradually some time after the year 2005.
Large Power Customer Contracts
The Company has Large Power Customer contracts with five taconite producers, four paper and wood products manufacturers and two pipeline companies (Large Power Customers). Large Power Customer contracts require the Company to have a certain amount of capacity available at all times (Firm Power). Each contract requires 10 MW or more of power and payment of a minimum monthly demand charge that covers some of the fixed costs associated with having capacity available to serve the customer, including a return on common equity. Such contracts minimize the impact on earnings that otherwise would result from significant reductions in kilowatthour sales to such customers. These contracts, which are subject to MPUC approval, have a minimum four-year cancellation notice required for termination. 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.)
As of March 14, 1997, the minimum annual revenue the Company would collect under contracts with these Large Power Customers, assuming no electric energy use by these customers, is estimated to be $101.0, $88.3, $79.4, $69.2 and $61.0 million during the years 1997, 1998, 1999, 2000 and 2001, respectively. The Company believes revenue from these Large Power Customers will be substantially in excess of the minimum contract amounts.
Purchased Power
Minnesota Power has contracts to purchase capacity from various entities. In addition to the contracts listed below, the Company has entered into various smaller purchase power contracts for the purposes of meeting its capacity needs or brokering power.
Capacity Sales
Minnesota Power has contracts to sell capacity to nonaffiliated utility companies. In addition to the contracts listed below, the Company has entered into various smaller capacity sales contracts for the purposes of selling surplus capacity or brokering power.
Fuel The Company has experienced no difficulty in obtaining an adequate fuel supply. The Company purchases low-sulfur, sub-bituminous coal from the Powder River Basin coal field located in Montana and Wyoming to meet substantially all of its coal supply requirements. Coal consumption for electric generation at the Company's Minnesota coal-fired generating stations in 1996 was about 4.3 million tons. As of December 31, 1996, the Company had a coal inventory of about 425,000 tons. During 1996, the Company obtained its coal through both long- and short-term agreements. During 1996 the Company entered into two new coal supply agreements. A long-term agreement with Big Sky Coal Company enables the Company to purchase up to 2.5 million tons of coal on an annualized basis from the Big Sky Mine. Additionally, the Company entered into a three year agreement with Decker Coal Company to purchase up to 1.0 million tons of coal on an annualized basis from the Decker Mine. The Company also has a long-term agreement with Spring Creek Coal Company to purchase up to 4.0 million tons of coal on an annualized basis from the Spring Creek Mine. The Company will obtain coal in 1997 under these long-term agreements and the spot market. This mix of coal supply options allows the Company to reduce market risk and to take advantage of favorable spot market prices. The Company is exploring future coal supply options and believes that adequate supplies of low-sulfur, sub-bituminous coal will continue to be available.
Burlington Northern Santa Fe Railroad transports the coal by unit train from Montana or Wyoming to the Company's generating stations. The Company and Burlington Northern Santa Fe Railroad have two long-term coal freight-rate contracts that provide for coal deliveries through 2002 to Laskin and through 2003 to Boswell. The Company also has a contract with the Duluth Missabe & Iron Range Railway which is the final destination short-hauler to Laskin. This contract provides for deliveries through 2002. The delivered price of coal is subject to periodic adjustments in freight rates.
Year Ended December 31, Summary of Coal Delivered to Minnesota Power 1996 1995 1994 - ------------------------------------------------------------------------------- Average Price Per Ton $19.30 $19.19 $19.27 Average Price Per MBtu $1.06 $1.07 $1.08
The generating unit operated by Square Butte, which is capable of generating up to 470 MW, burns North Dakota lignite that is being supplied by BNI Coal, a wholly owned subsidiary of the Company, pursuant to the terms of a contract expiring in 2027. Square Butte's cost of lignite burned in 1996 was approximately 60 cents per MBtu. The lignite acreage that has been dedicated to Square Butte by BNI Coal is located on lands essentially all of which are under private control and presently leased by BNI Coal. This lignite supply is sufficient to provide the fuel for the anticipated useful life of the generating unit. Under the various agreements with Square Butte, the Company is unconditionally obligated to pay all costs not paid by Square Butte when due. These costs include the price of lignite purchased under a cost-plus contract from BNI Coal. (See Item 2.

Item 2. Properties - Electric Operations.)
Retail
In 1995 the MPUC initiated an investigation into structural and regulatory issues in the electric utility industry. To make certain that delivery of electric service continues to be efficient following any restructuring, the MPUC adopted 15 principles to guide a deliberate and orderly approach to developing reasonable restructuring alternatives that ensure the fairness of a competitive market and protect the public interest. In January 1996 the MPUC established a competition working group in which company representatives have participated in addressing issues related to wholesale and retail competition. Minnesota Power has implemented a key account management process and anticipates continuing negotiations with its large industrial and commercial customers to explore contractual options to lower energy costs. These customers continue to aggressively seek lower energy costs and consider alternative suppliers in anticipation of deregulated retail markets.
Legislation
In 1997 Congress and the Minnesota legislature are expected to continue to debate proposed legislation which, if enacted, would promote customer choice and a more competitive electric market. The Company is actively participating in the dialogue and debate on these issues in various forums, principally to advocate fairness and parity for all power and energy competitors in any deregulated markets that may be created by any new legislation. The Company cannot predict the timing or substance of any legislation which might ultimately be enacted. However, the Company continues taking steps to maintain its competitive position as a low-cost supplier and maintain its long-term contracts with large industrial customers. The Company is also advocating property tax reform before the Minnesota legislature in order to eliminate the taxation of personal property that results in an inequitable tax burden among current and potential competitors in local markets. Finally, SWL&P is participating in the electric restructuring investigation before the PSCW, which is advising the Wisconsin legislature on recommended restructuring in Wisconsin.
Franchises
Minnesota Power holds franchises to construct and maintain an electric distribution and transmission system in 86 cities and towns located within its electric service territory. SWL&P holds franchises in 15 cities and towns within its service territory. The remaining cities and towns served will not grant a franchise or do not require a franchise to operate within their boundaries.
Environmental Matters
The Company's electric operations are subject to regulation by various federal, state and local authorities in the areas of air quality, water quality, solid wastes, and other environmental matters. The Company considers its electric operations to be in substantial compliance with those environmental regulations currently applicable to its operations and believes all necessary permits to conduct such operations have been obtained. The Company does not currently anticipate that its potential capital expenditures for environmental matters will be material. However, because environmental laws and regulations are constantly evolving, the character, scope and ultimate costs of environmental compliance cannot be estimated.
Air
The Federal Clean Air Act Amendments of 1990 (Clean Air Act) require that specified fossil-fueled generating plants meet new sulfur dioxide and nitrogen oxide emission standards beginning January 1, 1995 (Phase I) and that virtually all generating plants meet more strict emission standards beginning January 1, 2000 (Phase II). None of Minnesota Power's generating facilities are covered by the Phase I requirements of the Clean Air Act. However, Phase II requirements apply to the Company's Boswell, Laskin and Hibbard plants, as well as Square Butte.
The Clean Air Act creates emission allowances for sulfur dioxide based on formulas relating to the permitted 1985 emissions rate and a baseline of average fossil fuel consumed in the years 1985, 1986 and 1987. Each allowance is an authorization to emit one ton of sulfur dioxide, and each utility must have sufficient allowances to cover its annual emissions. Minnesota Power's generating facilities in Minnesota burn mainly low-sulfur western coal and Square Butte, located in North Dakota, burns lignite coal. All of these facilities are equipped with pollution control equipment such as scrubbers, baghouses or electrostatic precipitators. Phase II sulfur dioxide emission requirements are currently being met by Boswell Unit 4. Some moderate reductions in emissions may be necessary for Boswell Units 1, 2 and 3, Laskin Units 1 and 2, and Square Butte to meet the Phase II sulfur dioxide emission requirements. The Company believes it is in a good position to comply with the sulfur dioxide standards without extensive modifications. Any required reductions at the Minnesota generating facilities are expected to be achieved through the use of lower sulfur coal. Square Butte anticipates meeting its sulfur dioxide requirements through increased use of existing scrubbers or by purchasing additional allowances.
The EPA, pursuant to the Clean Air Act, has established nitrogen oxide limitations for Phase II generating units. To meet Phase II nitrogen oxide limitations, the Company expects to install at its plants low-nitrogen oxide burner technology by the year 2000. The total cost of installing the low-nitrogen oxide burner technology and associated facilities for Boswell and Laskin is currently estimated to be $6 million. Options for complying with the nitrogen oxide limitations at Square Butte are being studied at this time and include operational changes, capital expenditures and seeking regulatory relief. The EPA decided not to promulgate nitrogen oxide limitations for the type of boilers at Hibbard.
The Company is participating in a voluntary program (Climate Challenge) with the U.S. Department of Energy to identify activities that the Company has taken and additional measures that the Company may undertake on a voluntary basis that will result in limitations, reductions or sequestrations of greenhouse gas emissions by the year 2000. The Company has agreed to participate in this voluntary program provided that such participation is consistent with the Company's integrated resource planning process, does not have a material adverse effect on the Company's competitive position with respect to rates and costs, and continues to be acceptable to the Company's regulators. The costs to Minnesota Power associated with Climate Challenge participation are minor, reflecting program facilitation and voluntary reporting costs.
Water
The Federal Water Pollution Control Act of 1972 (FWPCA), as amended by the Clean Water Act of 1977 and the Water Quality Act of 1987, established the National Pollutant Discharge Elimination System (NPDES) permit program. The FWPCA requires that NPDES permits be obtained from the EPA (or, when delegated, from individual state pollution control agencies) for any wastewater discharged into navigable waters. The Company has obtained all necessary NPDES permits, including NPDES storm water permits for applicable facilities, to conduct its electric operations.
Summary of National Pollutant Discharge Elimination System Permits - -------------------------------------------------------------------------------- Facility Issue Date Expiration Date - -------- ---------- ---------------
Laskin December 22, 1993 October 31, 1998 Boswell February 4, 1993 December 31, 1997 Hibbard September 29, 1994 June 30, 1999 Arrowhead DC Terminal June 17, 1996 March 31, 2001 General Office Building/ Lake Superior Plaza May 1, 1995 December 31, 1997 Square Butte July 1, 1995 June 30, 2000
The Company holds from the FERC licenses authorizing the ownership and operation of seven hydroelectric generating projects with a total generating capacity of 121 MW. In 1991 the Company submitted applications for new licenses for four of the projects. By orders issued in 1993, the FERC granted new licenses with terms of 30 years each, expiring December 31, 2023, for the Little Falls (4.7 MW), Sylvan (1.8 MW), and Prairie River (1.1 MW) projects.
On July 13, 1995, the FERC issued to the Company a 30-year license for the St. Louis River hydroelectric project (87.6 MW), with an effective date of July 1, 1995. The Company filed a request for rehearing of the FERC's order for the purpose of challenging certain terms and conditions of the license which, if accepted by the Company, would alter the Company's operation of the project. In 1996 the FERC issued a new license in response to the rehearing request and extended the license term from 30 to 40 years because of the anticipated impact of FERC's mandates to mitigate environmental consequences of the project. The FERC also directed the Company to negotiate with the Fond du Lac Band of Lake Superior Chippewa a reasonable annual charge for the use of tribal lands within the project. In June 1996 the Company filed in the U.S. Court of Appeals for the District of Columbia Circuit a petition for review of the 1996 license as issued by the FERC. Separate petitions for review were also filed in June 1996 in the same court by the U.S. Department of the Interior and the Fond du Lac Band of Lake Superior Chippewa, two intervenors in the licensing proceedings. The issues to be resolved concern the terms and conditions of the license which will govern the Company's operation and maintenance of the project. In July 1996 the court consolidated the three petitions for review. In October 1996 the Company filed with the court an unopposed motion for a procedural schedule pursuant to which the briefing of the issues would be completed in May 1997. The motion was granted by the court; however, the briefing schedule has been suspended while the Company and the Fond du Lac Band negotiate the reasonable fee for use of tribal lands as mandated by the new license. Both parties have informed the court that these negotiations may resolve other disputed issues, and they are obligated to report to the court periodically the status of these discussions.
An application to relicense the Pillager project (1.5 MW) was filed with the FERC on May 11, 1995. The FERC will perform an engineering, environmental and economic analysis of that application in order to determine whether to issue a new license for the project. The current license for the project expires on May 11, 1997. FERC scoping meetings to discuss any environmental and operational issues related to this project were held in October 1996 with the resource agencies and the public. The FERC staff sought input related to any water quality, fishery, terrestrial, cultural and recreation issues that the agencies and public have prior to preparing the environmental assessment for this project. To date, no substantive issues have been raised by the resource agencies or the public in the license process. In the event that the current license should expire prior to the issuance of a new license, the FERC is required to issue an annual license to the Company under the terms and conditions of the existing license until the new license is issued.
The two remaining hydroelectric projects, Blanchard (18 MW) and Winton (4 MW) have FERC licenses that expire in 2003. The Company is currently in the planning stages for the relicensing of these two facilities.
Solid Waste
The Resource Conservation and Recovery Act of 1976 regulates the management and disposal of solid wastes. As a result of this legislation, the EPA has promulgated various hazardous waste rules. The Company is required to notify the EPA of hazardous waste activity and routinely submits the necessary annual reports to the EPA.
In response to EPA Region V's request for utilities to participate in their Great Lakes Initiative by voluntarily removing remaining polychlorinated biphenyl (PCB) inventories, the Company is scheduling replacement of PCB-contaminated oil from substation equipment by 1998 and removal of PCB capacitors by 2004. The total cost is expected to be between $1.5 and $2 million of which $300,000 was expended through December 31, 1996. The Company expects to expend about $110,000 in 1997.
Mining Control and Reclamation
BNI Coal's mining operations are governed by the Federal Surface Mining Control and Reclamation Act of 1977. This Act, together with the rules and regulations adopted thereunder by the Department of the Interior, Office of Surface Mining Reclamation and Enforcement (OSM), governs the approval or disapproval of all mining permits on federally owned land and the actions of the OSM in approving or disapproving state regulatory programs regulating mining activities. The North Dakota Reclamation of Strip Mined Lands Act and rules and regulations enacted thereunder in 1969, as subsequently amended by the North Dakota Mining and Reclamation Act and rules and regulations enacted thereunder in 1977, govern the reclamation of surface mined lands and are generally as stringent or more stringent than the federal rules and regulations. Compliance is monitored by the North Dakota Public Service Commission. The federal and state laws and regulations require a wide range of procedures including water management, topsoil and subsoil segregation, stockpiling and revegetation, and the posting of performance bonds to assure compliance. In general, these laws and regulations require the reclaiming of mined lands to a level of usefulness equal to or greater than that available before active mining. The Company considers BNI Coal to be in substantial compliance with those environmental regulations currently applicable to its operations and believes all necessary permits to conduct such operations have been obtained.
Water Services
Water services include Florida Water, Heater and ISI, three wholly owned subsidiaries of the Company. Water services have been upgrading existing facilities, building new facilities, acquiring new systems and expanding unregulated services.
- Florida Water, formerly Southern States Utilities, Inc., owns and operates water and wastewater treatment facilities in Florida. Florida Water is the largest investor owned water supplier in Florida. As of December 31, 1996, Florida Water served 120,000 water customers and 54,000 wastewater treatment customers.
- Heater owns and operates three companies which provide water and wastewater treatment services in North Carolina and South Carolina. As of December 31, 1996, these companies served 22,000 water customers and 1,000 wastewater treatment customers.
During 1996 Heater made a strategic decision to exit the South Carolina water and wastewater utility business. In March 1996 Heater of Seabrook, Inc. (Seabrook), a wholly owned subsidiary of Heater, sold all of its water and wastewater utility assets to the Town of Seabrook Island, South Carolina for $5.9 million. This sale was negotiated in anticipation of an eminent domain action by the Town of Seabrook Island, South Carolina. In December 1996 Heater sold its Columbia, South Carolina area water systems to South Carolina Water and Sewer, L.L.C. One service area remains and the pending sale is anticipated to be finalized in 1997. (See South Carolina Public Service Commission.)
On December 31, 1996, Heater and the shareholders of LaGrange Waterworks Corporation (LaGrange), a water utility serving 5,300 customers near Fayetteville, North Carolina, requested the NCUC to approve the transfer of LaGrange to Heater in a stock transaction. The NCUC held hearings on February 19 and March 13, 1997. An order is expected in May 1997.
- Instrumentation Services, Inc. provides predictive maintenance services to water utility companies and other industrial operations in North Carolina, South Carolina, Florida, Georgia, Tennessee, Virginia and Texas. The Company acquired ISI in 1996.
Regulatory Issues
Florida Public Service Commission
The following summarizes current rate proceedings in Florida.
1995 Rate Case
Florida Water requested an $18.1 million rate increase in June 1995. On October 30, 1996, the FPSC issued its final order in the Florida Water rate case. The final order established water and wastewater rates for all customers of Florida Water regulated by the FPSC. The new rates, which became effective on September 20, 1996, resulted in an annualized increase in revenue of approximately $11.1 million. This increase included, and was not in addition to, the $7.9 million increase in annualized revenue granted as interim rates effective on January 23, 1996. The FPSC approved a new rate structure called "capband," which replaces uniform rates. The new structure combines the concept of a "cap" on monthly bills at a certain usage level for 85 of Florida Water's facilities that are more expensive to operate, with a "banding," or grouping, of rates paid by customers served by the 56 less expensive facilities. On November 1, 1996, Florida Water filed with the Florida First District Court of Appeals (Court of Appeals) an appeal of the FPSC's final order seeking judicial review of issues relating to the amount of investment in utility facilities recoverable in rates from current customers. Motions for reconsideration of the FPSC's final order were denied by the FPSC on March 19, 1997. The Company is unable to predict the outcome of this matter. Florida law provides that the new rates be implemented, subject to refund, while the order is under appeal.
1991 Rate Case Refund Order
Responding to a Florida Supreme Court decision addressing the issue of retroactive ratemaking with respect to another company, in March 1996 the FPSC voted to reconsider an October 1995 order (Refund Order) which would have required Florida Water to refund about $13 million, which includes interest, to customers who paid more since October 1993 under uniform rates than they would have paid under stand-alone rates. Under the Refund Order, the collection through a surcharge of the $13 million from customers who paid less under uniform rates would not be permitted. The Refund Order was in response to the Court of Appeals reversal in April 1995 of the 1993 FPSC order which imposed uniform rates for most of Florida Water's service areas in Florida. With "uniform rates," all customers in the uniform rate areas pay the same rates for water and wastewater services. Uniform rates are an alternative to "stand-alone" rates which are calculated based on the cost of serving each service area. The FPSC reconsidered the Refund Order, but upheld by a 3 to 2 vote its decision to order refunds without surcharges in August 1996. Florida Water filed an appeal of this decision with the Court of Appeals. A decision on the appeal is anticipated by early 1998. The Company continues to believe that it would be improper for the FPSC to order a refund to one group of customers without permitting recovery of a similar amount from the remaining customers since the Court of Appeals affirmed the Company's total revenue requirement for operations in Florida. No provision for refund has been recorded. The Company is unable to predict the outcome of this matter.
Florida Jurisdictional Issues
In June 1995 the FPSC issued an order assuming jurisdiction over Florida Water facilities statewide following an investigation of all of Florida Water's facilities. Several counties in Florida appealed this FPSC decision to the Court of Appeals. In December 1996 the Court of Appeals issued an opinion reversing the FPSC order. On December 26, 1996, the FPSC filed a motion for clarification and for rehearing with the Court of Appeals. The Court of Appeals denied this motion on January 22, 1997. On February 14, 1997, the FPSC issued an order which requires Florida Water to charge rates to customers in Hernando County based on a modified stand-alone rate structure. The imposition of this rate structure would reduce Florida Water revenue by $1.6 million on a prospective annual basis. On February 28, 1997, Florida Water filed a motion for reconsideration of this order. The Company anticipates that a ruling against the Company on this appeal may encourage other counties to exercise their right to regulate the rates for water and wastewater facilities located in their respective counties. In the event county regulation of water and wastewater rates prevails, the Company anticipates that the regulatory process will become significantly more complex and expensive.
South Carolina Public Service Commission
During 1994 and 1995 Heater was denied a rate increase from the SCPSC for requests filed for Seabrook and Upstate Heater Utilities, Inc. (Upstate). Heater filed appeals for both rate increases and began collecting the higher rates for water and wastewater services at Seabrook under a surety bond in February 1995. Rates under bond collected for Seabrook amounted to $359,350 at December 31, 1996. In August 1996 the South Carolina Supreme Court upheld Heater's appeal and remanded the case to the SCPSC. Heater continues to hold these rates under bond pending a final decision from the SCPSC. On February 21, 1997, the SCPSC issued an order granting Seabrook a $66,480 annual revenue increase. Heater filed a motion for reconsideration in March 1997.
The appeal for Upstate resulted in a remand from the South Carolina Court of Common Pleas (Court of Common Pleas) and a revised order issued by the SCPSC in September 1995. Heater filed another appeal with the Court of Common Pleas, and began collecting the higher rates for water service at Upstate under a surety bond in January 1996. Rates under bond collected for Upstate totaled $65,861 at December 31, 1996. If this appeal is denied, Heater must refund the difference between the amounts collected and the approved rates plus 12 percent interest. On February 3, 1997, the Court of Common Pleas issued an order vacating the September 1995 order and remanded the order to the SCPSC. A decision by the SCPSC is expected in April 1997.
Capital Expenditure Program
Capital expenditures for water services totaled $22 million during 1996. Expenditures were funded with the proceeds from long-term bonds issued by Florida Water and internally generated funds. Capital expenditures for the Company's water services are expected to be $21 million in 1997 to meet environmental standards, expand water and wastewater treatment facilities to accommodate customer growth, and for water conservation initiatives. Capital expenditures are expected to total approximately $85 million during the period 1998 through 2001.
Competition
Water services provide water and wastewater services at regulated rates within exclusive service territories granted by regulators.
Franchises
Florida Water provides water and wastewater treatment services in 22 counties regulated by the FPSC and holds franchises in three counties which have retained authority to regulate such operations. (See Regulatory Issues - Florida Public Service Commission.)
All of the water and wastewater services of Heater are under the jurisdiction of the SCPSC and the NCUC. These commissions grant franchises for Heater's service territory when the rates are authorized.
Environmental Matters
The Company's water services are subject to regulation by various federal, state and local authorities in the areas of water quality, solid wastes, and other environmental matters. The Company considers its water services to generally be in compliance with those environmental regulations currently applicable to its operations and have the permits necessary to conduct such operations. Except as noted below, the Company does not currently anticipate that its potential capital expenditures for environmental matters will be material. However, because environmental laws and regulations are constantly evolving, the character, scope and ultimate costs of environmental compliance cannot be estimated.
In 1993 the EPA notified Florida Water of alleged exceedences of effluent limitations in NPDES permit for Florida Water's facilities in the University Shores service area in Orange County, Florida. During 1993 and 1994, Florida Water periodically corresponded and met with the EPA concerning the alleged exceedences of the permit. In February 1994 the University Shores facility was modified such that effluent was no longer discharged to surface waters. In 1992 the EPA notified Florida Water of alleged exceedences of effluent limitations in the NPDES permit for Florida Water's Seaboard wastewater treatment facility. Between 1992 and 1994, Florida Water periodically corresponded and met with the EPA concerning alleged exceedences of the permit. In March 1994 the facility was taken out of service and the collection system was interconnected with the City of Tampa Utilities. In February 1997 Florida Water was notified by the United States Department of Justice (DOJ) that unless a settlement can be promptly achieved, the DOJ, at the request of the EPA, is prepared to bring a federal court action against Florida Water seeking civil penalties for alleged violations of effluent limitations in the NPDES permits occurring at the University Shores and Seaboard wastewater facilities from February 1992 through March 1994. For purposes of settlement discussions, the DOJ proposed a penalty totaling $3.25 million. Florida Water submitted a counter settlement offer of $141,000 to the DOJ on March 26, 1997. A meeting is scheduled on April 4, 1997, with the DOJ to discuss settlement options. If the DOJ pursues litigation, it is possible that the claim against Florida Water could substantially exceed $3.25 million. If a reasonable resolution is not reached, Florida Water intends to vigorously contest any action which is initiated by the DOJ. The Company is currently unable to predict the outcome of these matters.
In September 1993 the EPA issued an Administrative Order to Florida Water regarding operations of Florida Water's facilities in the Woodmere service area in Duval County, Florida (Woodmere facilities). The EPA required Florida Water to perform a Toxicity Reduction Evaluation (TRE) to determine the cause of the toxicity problems with the wastewater effluent. In March 1996 the EPA closed the Administrative Order and delegated enforcement authority to the Florida Department of Environmental Protection.
In 1996 water services invested approximately $10.2 million of a $22 million annual capital expenditure budget (or approximately 46 percent) in facilities necessary to comply with environmental requirements. In 1997 Florida Water expects that approximately $7.5 million of the $21 million annual capital expenditure budget (or approximately 36 percent) will be necessary to comply with environmental requirements.
Automotive Services
Automotive services include ADESA's auction facilities, AFC, which is a finance company, and an auto transport company. The Company acquired 80 percent of ADESA on July 1, 1995. On January 31, 1996, the Company provided additional capital in exchange for an additional 3 percent of ADESA. On August 21, 1996, the Company acquired the remaining 17 percent interest of ADESA from the ADESA management shareholders.
- ADESA is a wholly owned subsidiary of the Company and is the third largest automobile auction business in the United States. ADESA, headquartered in Indianapolis, Indiana, owns and operates 24 automobile auction facilities in the United States and Canada through which used cars and other vehicles are sold to franchised automobile dealers and licensed used car dealers. Sellers at ADESA's auctions include domestic and foreign auto manufacturers, car dealers, fleet/lease companies, banks and finance companies. ADESA opened new auto auctions in Manville, New Jersey; Jacksonville, Florida and Moncton, New Brunswick, Canada in 1996. ADESA also acquired auction businesses in Houston, San Antonio and Dallas, Texas; Portage, Wisconsin and Pittsburgh, Pennsylvania during 1996.
- Automotive Finance Corporation provides inventory financing for wholesale and retail automobile dealers who purchase vehicles from ADESA auctions, independent auctions as well as auction chains. AFC is headquartered in Indianapolis, Indiana, and has over 40 loan production offices which are located at most ADESA auctions, as well as several independently owned auto auctions. AFC expects to expand in 1997.
- ADESA Auto Transport, Inc., a wholly owned subsidiary of ADESA, is one of the nation's largest independent automobile transport carriers with about 90 transport vehicles. ADESA Auto Transport, Inc. offers customers pick up and delivery, four strategically located transportation hubs and an on-site transportation representative at every ADESA auction. It hauls vehicles for major customers including GE Capital, Nissan, Ford Motor Credit and General Motors Acceptance Corp. During 1996 over 100,000 cars were transported within the United States by ADESA.
Capital Expenditure Program
Capital expenditures for automobile auction site relocation, development and facility improvements were $41 million during 1996. Greenfield projects at Manville, New Jersey; Jacksonville, Florida; and Moncton, New Brunswick, Canada and relocation projects in Indianapolis, Indiana and Cincinnati, Ohio began operations in 1996. In February 1997 ADESA consolidated a small auction facility in Concord, Massachusetts with its Boston facility. Capital expenditures for the automobile auction business are expected to be $7 million in 1997 and to total approximately $40 million during the period 1998 through 2001. Capital expenditures in 1997 are for on-going improvements and new information systems at existing automobile auction sites.
Competition
Within the automobile auction industry, ADESA's competition includes independently owned auctions as well as major chains and associations with auctions in geographic proximity. ADESA competes with other auctions for a supply of automobiles to be sold on consignment for automobile dealers, financial institutions and other sellers. ADESA also competes for a supply of rental repurchase vehicles from automobile manufacturers for auction at factory sales. The automobile manufacturers often choose between auctions across multi-state areas in distributing rental repurchase vehicles. ADESA competes for these sellers of automobiles by attempting to attract a large number of dealers to purchase vehicles, which ensures competitive prices and supports the volume of vehicles auctioned, and by providing a full range of services including reconditioning services which prepare automobiles for auction, transporting automobiles and the prompt processing of sale transactions. Another factor affecting the industry, the impact of which is yet to be determined, is the entrance of the "superstore", large used car dealerships, that have emerged in densely populated markets.
AFC is well positioned as a provider of floorplan financing services to the used vehicle industry. AFC's competition includes other specialty lenders, as well as banks and other financial institutions. AFC competes with other floorplan providers and strives to distinguish itself based upon ease of use, quality of service and price. A key component of AFC's program is on-site personnel to assist automobile dealers with their financing needs.
Auto auction sales for the industry are expected to rise at a rate of 6 percent to 8 percent annually. With the increased popularity of leasing and the high cost of new cars, the same cars may come to auction more than once. Automotive services expect to participate in this industry's growth through selective acquisitions and expanded services.
Environmental Matters
The Company's automotive services business is subject to regulation by various federal, state and local authorities in the areas of air quality, water quality, solid wastes, and other environmental matters. The Company considers operations of this business to be in substantial compliance with those environmental regulations currently applicable to its operations and believes all necessary permits to conduct such operations have been obtained. The Company does not currently anticipate that its potential capital expenditures for environmental matters will be material. However, because environmental laws and regulations are constantly evolving, the character, scope and ultimate costs of environmental compliance cannot be estimated.
Investments
The investments segment is comprised of real estate operations, financial guaranty reinsurance and a portfolio of securities.
- Real Estate Operations. The Company owns 80 percent of Lehigh, a Florida real estate company. Lehigh owns 4,000 acres of land and approximately 8,000 home sites near Fort Myers, Florida, 1,100 home sites in Citrus County, Florida, and 3,000 home sites and 13,000 acres of residential, commercial and industrial land at Palm Coast, Florida. The Palm Coast properties and $18 million receivable portfolio were purchased in April 1996. The real estate strategy is to acquire large residential community properties at low cost, add value, and sell them at going market prices.
- Reinsurance. Minnesota Power has a 21 percent equity investment in Capital Re. Capital Re is a Delaware holding company engaged primarily in financial and mortgage guaranty reinsurance through its wholly owned subsidiaries, Capital Reinsurance Company and Capital Mortgage Reinsurance Company. Capital Reinsurance Company is a reinsurer of financial guarantees of municipal and non-municipal debt obligations. Capital Mortgage Reinsurance Company is a reinsurer of residential mortgage guaranty insurance. The Company's equity investment in Capital Re at December 31, 1996, was $102 million.
- Securities Portfolio. Minnesota Power manages a securities portfolio which is intended to provide earnings and cash flow contributions and is available for reinvestment in existing businesses, acquisitions and other corporate purposes. The Company plans to continue to concentrate in market neutral strategies that are designed to provide stable and acceptable returns without sacrificing needed liquidity. Returns will continue to be partially dependent on general market conditions. As of December 31, 1996, the Company had approximately $155 million invested in the securities portfolio.
Environmental Matters
Certain businesses included in the Company's investments segment are subject to regulation by various federal, state and local authorities in the areas of air quality, water quality, solid wastes, and other environmental matters. The Company considers these businesses to be in substantial compliance with those environmental regulations currently applicable to its operations and believes all necessary permits to conduct such operations have been obtained. The Company does not currently anticipate that its potential capital expenditures for environmental matters will be material. However, because environmental laws and regulations are constantly evolving, the character, scope and ultimate costs of environmental compliance cannot be estimated.
Executive Officers of the Registrant Initial Executive Officers Effective Date - ------------------ --------------
Edwin L. Russell, Age 52 Chairman, President and Chief Executive Officer May 14, 1996 President and Chief Executive Officer January 22, 1996 President May 9, 1995
Robert D. Edwards, Age 52 Executive Vice President and President - MP Electric July 26, 1995 Executive Vice President and Chief Operating Officer March 1, 1993 Group Vice President - Corporate Services and Chief Financial Officer January 1, 1991
John A. Cirello, Age 53 Executive Vice President and President and Chief Executive Officer - MP Water Resources July 24, 1995
James P. Hallett, Age 43 President and Chief Executive Officer - ADESA August 21, 1996
John E. Fuller, Age 53 President and Chief Executive Officer - Automotive Finance Corporation January 1, 1994
Donnie R. Crandell, Age 53 Senior Vice President and President - MP Real Estate Holdings January 1, 1996 Senior Vice President - Corporate Development December 1, 1994 Retired February 28, 1994 Vice President - Corporate Development March 1, 1993
David G. Gartzke, Age 53 Senior Vice President - Finance and Chief Financial Officer December 1, 1994 Vice President - Finance and Chief Financial Officer March 1, 1993 Vice President - Finance and Treasurer January 1, 1991
Laurence H. Fuller, 48 Vice President - Corporate Development February 10, 1997
Philip R. Halverson, Age 48 Vice President, General Counsel and Secretary January 1, 1996 General Counsel and Corporate Secretary March 1, 1993 General Counsel and Assistant Secretary January 23, 1991
James A. Roberts, Age 46 Vice President - Corporate Relations January 1, 1996
Mark A. Schober, Age 41 Controller March 1, 1993
James K. Vizanko, Age 43 Treasurer March 1, 1993
All of the executive officers above, except Mr. Russell, Mr. Cirello, Mr. Crandell, Mr. Hallet, Mr. John Fuller, and Mr. Laurence Fuller, had been employed by the Company for more than five years in executive or management positions. Mr. Russell was previously group vice president of J. M. Huber Corporation, a $1.5 billion diversified manufacturing and natural resources company; Mr. Cirello was president of Metcalf & Eddy Services, Inc. from 1992 to 1995, responsible for $64 million in water/wastewater operation services, and before that was vice president - Eastern Region of Chemical Waste Management; Mr. Crandell was director of business development of the Company, vice president of Topeka and vice president of business development for Topeka prior to March 1, 1993; Mr. Hallet was previously executive vice president of ADESA and president of ADESA's Canadian operations; Mr. John Fuller was previously president and 50 percent owner of CITA, Inc., which he founded in 1987 (CITA was renamed Automotive Finance Corporation in December 1993 and sold to ADESA Corporation in January 1994); and Mr. Laurence Fuller was previously senior vice president, new business development and strategic planning, for Diners Club International, a subsidiary of CitiCorp, Inc. Prior to election to the positions shown above, the following executive officers held other positions with the Company after January 1, 1992: Mr. Roberts was director of corporate relations and director of governmental relations; Mr. Schober was director of internal audit; and Mr. Vizanko was director of investments and analysis, and manager of financial planning and analysis. There are no family relationships between any executive officers of the Company. All officers and directors are elected or appointed annually.
The present term of office of the above executive officers extends to the first meeting of the Company's Board of Directors after the next annual meeting of shareholders. Both meetings are scheduled for May 13, 1997.
Item 2. Properties.
Electric Operations
The Company had an annual and all-time record net peak load of 1,462 MW on November 12, 1996. The Company's average 1996 load factor was 87 percent. Information with respect to existing power supply sources is shown below.
The Company has electric transmission and distribution lines of 500 kilovolts (kV) (7.8 miles), 230 kV (606.4 miles), 161 kV (42.9 miles), 138 kV (5.8 miles), 115 kV (1,257.3 miles) and less than 115 kV (6,114.1 miles). The Company owns and operates 178 substations with a total capacity of 8,539.2 megavoltamperes. Some of the transmission and distribution lines interconnect with other utilities.
The Company owns and has a substantial investment in offices and service buildings, area headquarters, an energy control center, repair shops, motor vehicles, construction equipment and tools, office furniture and equipment, and leases offices and storerooms in various localities within the Company's service territory. It also owns miscellaneous parcels of real estate not presently used in electric operations.
Substantially all of the electric plant of the Company is subject to the lien of its Mortgage and Deed of Trust which secures first mortgage bonds issued by the Company. The Company's properties are held by it in fee and are free from other encumbrances, subject to minor exceptions, none of which are of such a nature as to substantially impair the usefulness to the Company of such properties. Other property, including certain offices and equipment, is utilized under leases. In general, some of the electric lines are located on land not owned in fee, but are covered by necessary consents of various governmental authorities or by appropriate rights obtained from owners of private property. These consents and rights are deemed adequate for the purposes for which the properties are being used. In September 1990 the Company sold a portion of Boswell Unit 4 to WPPI. WPPI has the right to use the Company's transmission line facilities to transport its share of generation.
Substantially all of the plant of SWL&P is subject to the lien of its Mortgage and Deed of Trust which secures first mortgage bonds issued by SWL&P. Approximately one-half of BNI Coal's equipment is leased under a leveraged lease agreement which expires in 2002. The remaining property and equipment are owned by BNI Coal.
The Company is a member of the Mid-Continent Area Power Pool (MAPP). The MAPP enhances electric service reliability, and provides the opportunity for members to enter into various wholesale power transactions and coordinate planning, installation and operation of new generation and transmission facilities. The MAPP membership consists of various electric power suppliers located in North Dakota, South Dakota, eastern Montana, Nebraska, Iowa, Minnesota, Wisconsin, upper Michigan, Kansas, Manitoba and Saskatchewan and marketers and brokers located throughout North America. The electric power suppliers are investor-owned utilities including the Company, rural electric generation and transmission cooperatives, public power districts, municipal electric systems, municipal organizations, and the Western Area Power Administration - Billings, Montana. MAPP operates pursuant to an agreement that was approved by MAPP members on March 15, 1996, accepted by the FERC and became effective on November 1, 1996.
Water Services
Florida Water is largest investor owned provider of water and wastewater services in Florida, serving more than 170,000 customers over 120 communities. Florida Water maintains more than 150 water and wastewater facilities throughout the state with plants ranging in size from 6 connections to greater than 25,000 connections. Florida Water provides its customers with 12 billion gallons of water per year primarily from Florida's underground aquifer. Substantially all of Florida Water's properties used in its water and wastewater operations are encumbered by a mortgage.
Heater has water and wastewater systems located in subdivisions surrounding Raleigh, North Carolina, Fayetteville, North Carolina and Anderson, South Carolina. Water supply is primarily from ground water deep wells. Community ground water systems vary in size from 25 connections to 6,000 connections. Some systems are supplied by purchased water. Heater has approximately 180 systems and 375 wells serving 22,000 customers. Heater also has six wastewater treatment plants, ranging in size from 35,000 gallons per day (gpd) to 250,000 gpd, and 17 lift stations located in its wastewater collection systems. These systems serve approximately 1,000 customers. Substantially all of Heater's properties used in its water and wastewater operations are encumbered by a mortgage.
Investments
Property within the Company's real estate operations consists of 4,000 acres of land and approximately 8,000 home sites near Fort Myers, Florida; 1,110 home sites in Citrus County, Florida; and 3,000 home sites and 13,000 acres of residential, industrial and commercial land at Palm Coast, Florida.
Automotive Services
The following table sets forth the auto auctions currently owned or leased by ADESA. Each auction has a multi-lane, drive-through auction facility, as well as additional buildings for reconditioning, registration, maintenance, body work and other ancillary and administrative services. Each auction also has secure parking areas in which it stores vehicles for auction. All automobile auction property owned by ADESA is subject to liens securing various notes payable.
Item 3.

Item 3. Legal Proceedings.
Material legal and regulatory proceedings are included in the discussion of the Company's business in Item 1 and are incorporated by reference herein.
Item 4.

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 1996.
PART II
Item 5.

Item 5. Market for the Registrant's Common Equity and Related Stockholder Matters.
The Company has paid dividends without interruption on its common stock since 1948. A quarterly dividend of $.51 per share on the common stock was paid on March 1, 1997, to the holders of record on February 14, 1997. The Company's common stock is listed on the New York Stock Exchange. Dividends paid per share and the high and low prices for the Company's common stock for the periods indicated as reported by The Wall Street Journal, Midwest Edition, were as follows:
Dividends Price Range Paid Per Share ----------- -------------- Quarter High Low Quarterly Annual ------- ---- --- --------- ------
1996 - First $ 29 3/4 $ 26 1/8 $ .51 - Second 29 26 .51 - Third 28 3/4 26 .51 - Fourth 28 7/8 26 3/8 .51 $2.04
1995 - First $ 26 3/8 $ 24 1/4 $ .51 - Second 28 25 1/4 .51 - Third 28 1/8 26 3/8 .51 - Fourth 29 1/4 27 1/2 .51 $2.04
The amount and timing of dividends payable on the Company's common stock are within the sole discretion of the Company's Board of Directors. In 1996 the Company paid out 90 percent of its per share earnings in dividends. Over the longer term, the Company's goal is to reduce dividend payout to between 75 percent and 80 percent of per share earnings. This is expected to be accomplished by increasing earnings rather than reducing dividends.
The Company's Articles of Incorporation and Mortgage and Deed of Trust contain provisions which under certain circumstances would restrict the payment of common stock dividends. As of December 31, 1996, no retained earnings were restricted as a result of these provisions. At March 1, 1997, there were approximately 24,000 common stock shareholders of record.
Item 6.

Item 6. Selected Financial Data.
Item 7.

Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations.
The management's discussion and analysis of financial condition and results of operations appearing on pages 13 through 22 of the Minnesota Power 1996 Annual Report are incorporated by reference in this Form 10-K Annual Report.
Item 8.

Item 8. Financial Statements and Supplementary Data.
The financial statements, together with the report thereon of Price Waterhouse LLP dated January 27, 1997, appearing on pages 23 through 40 of the Minnesota Power 1996 Annual Report, are incorporated by reference in this Form 10-K Annual Report.
Item 9.

Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.
Not applicable.
PART III
Item 10.

Item 10. Directors and Executive Officers of the Registrant.
The information required for this Item is incorporated by reference herein from the "Election of Directors" section in the Company's Proxy Statement for the 1997 Annual Meeting of Shareholders, except for information with respect to executive officers which is set forth in Part I hereof.
Item 11.

Item 11. Executive Compensation.
The information required for this Item is incorporated by reference herein from the "Compensation of Executive Officers" section in the Company's Proxy Statement for the 1997 Annual Meeting of Shareholders.
Item 12.

Item 12. Security Ownership of Certain Beneficial Owners and Management.
The information required for this Item is incorporated by reference herein from the "Security Ownership of Certain Beneficial Owners and Management" section in the Company's Proxy Statement for the 1997 Annual Meeting of Shareholders.
Item 13.

Item 13. Certain Relationships and Related Transactions.
The information required for this Item is incorporated by reference herein from the "Certain Relationships and Related Transactions" section in the Company's Proxy Statement for the 1997 Annual Meeting of Shareholders.
PART IV
Item 14.

Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K.
(a) Certain Documents Filed as Part of Form 10-K.
(1) Financial Statements
Pages in Annual Report* -------------- Minnesota Power Report of Independent Accountants 23 Consolidated Balance Sheet at December 31, 1996 and 1995 24 For the three years ended December 31, 1996 Consolidated Statement of Income 25 Consolidated Statement of Retained Earnings 25 Consolidated Statement of Cash Flows 26 Notes to Consolidated Financial Statements 27-40 - ------------------ * Incorporated by reference herein from the Minnesota Power 1996 Annual Report.
Page ---- (2) Financial Statement Schedules Report of Independent Accountants on Financial Statement Schedule 32 Minnesota Power and Subsidiaries Schedule: II-Valuation and Qualifying Accounts and Reserves 33
All other schedules have been omitted either because the information is not required to be reported by the Company or because the information is included in the consolidated financial statements or the notes thereto.
(3) Exhibits including those incorporated by reference
Exhibit Number - -------
*2 - Agreement and Plan of Merger by and among Minnesota Power & Light Company, AC Acquisition Sub, Inc., ADESA Corporation and Certain ADESA Management Shareholders dated February 23, 1995 (filed as Exhibit 2 to Form 8-K dated March 3, 1995, File No. 1-3548).
*3(a)1 - Articles of Incorporation, restated as of July 27, 1988 (filed as Exhibit 3(a), File No. 33-24936).
*3(a)2 - Certificate Fixing Terms of Serial Preferred Stock A, $7.125 Series (filed as Exhibit 3(a)2, File No. 33-50143).
*3(a)3 - Certificate Fixing Terms of Serial Preferred Stock A, $6.70 Series (filed as Exhibit 3(a)3, File No. 33-50143).
*3(b) - Bylaws as amended January 23, 1991 (filed as Exhibit 3(b), File No. 33-45549).
Exhibit Number - -------
*4(a)1 - Mortgage and Deed of Trust, dated as of September 1, 1945, between the Company and Irving Trust Company (now The Bank of New York) and Richard H. West (W.T. Cunningham, successor), Trustees (filed as Exhibit 7(c), File No. 2-5865).
*4(a)2 - Supplemental Indentures to Mortgage and Deed of Trust:
Reference Number Dated as of File Exhibit ------ ----------- --------- -------
First March 1, 1949 2-7826 7(b) Second July 1, 1951 2-9036 7(c) Third March 1, 1957 2-13075 2(c) Fourth January 1, 1968 2-27794 2(c) Fifth April 1, 1971 2-39537 2(c) Sixth August 1, 1975 2-54116 2(c) Seventh September 1, 1976 2-57014 2(c) Eighth September 1, 1977 2-59690 2(c) Ninth April 1, 1978 2-60866 2(c) Tenth August 1, 1978 2-62852 2(d)2 Eleventh December 1, 1982 2-56649 4(a)3 Twelfth April 1, 1987 33-30224 4(a)3 Thirteenth March 1, 1992 33-47438 4(b) Fourteenth June 1, 1992 33-55240 4(b) Fifteenth July 1, 1992 33-55240 4(c) Sixteenth July 1, 1992 33-55240 4(d) Seventeenth February 1, 1993 33-50143 4(b) Eighteenth July 1, 1993 33-50143 4(c)
4(a)3 - Nineteenth Supplemental Indenture, dated as of February 1, 1997, between the Company and The Bank of New York (formerly Irving Trust Company) and W.T. Cunningham (successor to Richard H. West), Trustees.
*4(b) - Mortgage and Deed of Trust, dated as of March 1, 1943, between Superior Water, Light and Power Company and Chemical Bank & Trust Company and Howard B. Smith, as Trustees, both succeeded by First Bank N.A., as Trustee (filed as Exhibit 7(c), File No. 2-8668), as supplemented and modified by First Supplemental Indenture thereto dated as of March 1, 1951 (filed as Exhibit 2(d)(1), File No. 2-59690), Second Supplemental Indenture thereto dated as of March 1, 1962 (filed as Exhibit 2(d)1, File No. 2-27794), Third Supplemental Indenture thereto dated July 1, 1976 (filed as Exhibit 2(e)1, File No. 2-57478), Fourth Supplemental Indenture thereto dated as of March 1, 1985 (filed as Exhibit 4(b), File No. 2-78641) and Fifth Supplemental Indenture thereto dated as of December 1, 1992 (filed as Exhibit 4(b)1 to Form 10-K for the year ended December 31, 1992, File No. 1-3548).
4(b)1 - Sixth Supplemental Indenture, dated as of March 24, 1994, between Superior Water, Light and Power Company and Chemical Bank (formerly Chemical Bank & Trust Company) and Peter Morse (successor to Howard B. Smith), Trustees.
4(b)2 - Seventh Supplemental Indenture, dated as of November 1, 1994, between Superior Water, Light and Power Company and Chemical Bank (formerly Chemical Bank & Trust Company) and Peter Morse (successor to Howard B. Smith), Trustees.
4(b)3 - Eighth Supplemental Indenture, dated as of January 1, 1997, between Superior Water, Light and Power Company and First Bank N.A. Trustee.
Exhibit Number - -------
*4(c) - Indenture, dated as of March 1, 1993, between Southern States Utilities, Inc. (now Florida Water Services Corporation) and Nationsbank of Georgia, National Association (now SunTrust Bank, Central Florida, N.A.), as Trustee (filed as Exhibit 4(d) to Form 10-K for the year ended December 31, 1992, File No. 1-3548).
4(c)1 - First Supplemental Indenture, dated as of March 1, 1993, between Southern States Utilities, Inc. (now Florida Water Services Corporation) and Nationsbank of Georgia, National Association (now SunTrust Bank, Central Florida, N.A.), as Trustee.
*4(d) - Amended and Restated Trust Agreement, dated as of March 1, 1996, relating to MP&L Capital I's 8.05% Cumulative Quarterly Income Preferred Securities, between the Company, as Depositor, and The Bank of New York, The Bank of New York (Delaware), Philip R. Halverson, David G. Gartzke and James K. Vizanko, as Trustees (filed as Exhibit 4(a) to Form 10-Q for the quarter ended March 31, 1996, File No. 1-3548).
*4(e) - Amendment No. 1, dated April 11, 1996, to Amended and Restated Trust Agreement, dated as of March 1, 1996, relating to MP&L Capital I's 8.05% Cumulative Quarterly Income Preferred Securities (filed as Exhibit 4(b) to Form 10-Q for the quarter ended March 31, 1996, File No. 1-3548).
*4(f) - Indenture, dated as of March 1, 1996, relating to the Company's 8.05% Junior Subordinated Debentures, Series A, Due 2015, between the Company and The Bank of New York, as Trustee (filed as Exhibit 4(c) to Form 10-Q for the quarter ended March 31, 1996, File No. 1-3548).
*4(g) - Guarantee Agreement, dated as of March 1, 1996, relating to MP&L Capital I's 8.05% Cumulative Quarterly Income Preferred Securities, between the Company, as Guarantor, and The Bank of New York, as Trustee (filed as Exhibit 4(d) to Form 10-Q for the quarter ended March 31, 1996, File No. 1-3548).
*4(h) - Agreement as to Expenses and Liabilities, dated as of March 20, 1996, relating to MP&L Capital I's 8.05% Cumulative Quarterly Income Preferred Securities, between the Company and MP&L Capital I (filed as Exhibit 4(e) to Form 10-Q for the quarter ended March 31, 1996, File No. 1-3548).
4(i) - Officer's Certificate, dated March 20, 1996, establishing the terms of the 8.05% Junior Subordinated Debentures, Series A, Due 2015 issued in connection with the 8.05% Cumulative Quarterly Income Preferred Securities of MP&L Capital I.
*4(j) - Rights Agreement dated as of July 24, 1996, between Minnesota Power & Light Company and the Corporate Secretary of Minnesota Power & Light Company, as Rights Agent (filed as Exhibit 4 to Form 8-K dated August 2, 1996, File No. 1-3548).
4(k) - Indenture, dated as of May 15, 1996, relating to the ADESA Corporation's 7.70% Senior Notes, Series A, Due 2006, between ADESA Corporation and The Bank of New York, as Trustee.
4(l) - Guarantee of Minnesota Power & Light Company, dated as of May 30, 1996, relating to the ADESA Corporation's 7.70% Senior Notes, Series A, Due 2006.
4(m) - ADESA Corporation Officer's Certificate 1-D-1, dated May 30, 1996, relating to the ADESA Corporation's 7.70% Senior Notes, Series A, Due 2006.
Exhibit Number - -------
*10(a) - Asset Holdings III, L.P. Note Purchase Agreement, dated as of November 22, 1994 (filed as Exhibit 10(i) to Form 10-K for the year ended December 31, 1995, File No. 1-3548).
*10(b) - Lease and Development Agreement, dated as of November 28, 1994 between Asset Holdings III, L.P., as Lessor and A.D.E. of Knoxville, Inc., as Lessee (filed as Exhibit 10(j) to Form 10-K for the year ended December 31, 1995, File No. 1-3548).
*10(c) - Lease and Development Agreement, dated as of November 28, 1994 between Asset Holdings III, L.P., as Lessor and ADESA-Charlotte, Inc., as Lessee (filed as Exhibit 10(k) to Form 10-K for the year ended December 31, 1995, File No. 1-3548).
*10(d) - Lease and Development Agreement, dated as of December 21, 1994 between Asset Holdings III, L.P., as Lessor and Auto Dealers Exchange of Concord, Inc., as Lessee (filed as Exhibit 10(l) to Form 10-K for the year ended December 31, 1995, File No. 1-3548).
*10(e) - Guaranty and Purchase Option Agreement between Asset Holdings III, L.P. and ADESA Corporation, dated as of November 28, 1994 (filed as Exhibit 10(m) to Form 10-K for the year ended December 31, 1995, File No. 1-3548).
10(f) - Receivables Purchase Agreement dated as of December 31, 1996, among AFC Funding Corporation, as Seller, Automotive Finance Corporation, as Servicer, Pooled Accounts Receivable Capital Corporation, as Purchaser, and Nesbitt Burns Securities Inc., as Agent.
10(g) - First Amendment to Receivables Purchase Agreement, dated as of February 28, 1997, among AFC Funding Corporation, as Seller, Automotive Finance Corporation, as Servicer, Pooled Accounts Receivable Capital Corporation, as Purchaser, and Nesbitt Burns Securities Inc., as Agent.
10(h) - Purchase and Sale Agreement dated as of December 31, 1996, between AFC Funding Corporation and Automotive Finance Corporation.
+*10(i) - Minnesota Power Executive Annual Incentive Plan, effective January 1, 1996 (filed as Exhibit 10(a) to Form 10-K for the year ended December 31, 1995, File No. 1-3548).
+*10(j) - Minnesota Power and Affiliated Companies Supplemental Executive Retirement Plan, as amended and restated, effective August 1, 1994 (filed as Exhibit 10(b) to Form 10-K for the year ended December 31, 1995, File No. 1-3548).
+*10(k) - Executive Investment Plan-I, as amended and restated, effective November 1, 1988 (filed as Exhibit 10(c) to Form 10-K for the year ended December 31, 1988, File No. 1-3548).
+*10(l) - Executive Investment Plan-II, as amended and restated, effective November 1, 1988 (filed as Exhibit 10(d) to Form 10-K for the year ended December 31, 1988, File No. 1-3548).
+*10(m) - Deferred Compensation Trust Agreement, as amended and restated, effective January 1, 1989 (filed as Exhibit 10(f) to Form 10-K for the year ended December 31, 1988, File No. 1-3548).
+*10(n) - Executive Long-Term Incentive Plan, as amended and restated, effective January 1, 1994 (filed as Exhibit 10(e) to Form 10-K for the year ended December 31, 1994, File No. 1-3548).
+*10(o) - Minnesota Power Executive Long-Term Incentive Compensation Plan, effective January 1, 1996 (filed as Exhibit 10(a) to Form 10-Q for the quarter ended June 30, 1996, File No. 1-3548).
Exhibit Number - -------
+*10(p) - Directors' Long-Term Incentive Plan, as amended and restated, effective January 1, 1994 (filed as Exhibit 10(f) to Form 10-K for the year ended December 31, 1994, File No. 1-3548).
+*10(q) - Minnesota Power Director Stock Plan, effective January 1, 1995 (filed as Exhibit 10 to Form 10-Q for the quarter ended March 31, 1995, File No. 1-3548).
+*10(r) - Minnesota Power Director Long-Term Stock Incentive Plan, effective January 1, 1996 (filed as Exhibit 10(b) to Form 10-Q for the quarter ended June 30, 1996, File No. 1-3548).
12 - Computation of Ratios of Earnings to Fixed Charges and Supplemental Ratios of Earnings to Fixed Charges.
13 - Minnesota Power 1996 Annual Report - Management's Discussion and Analysis of Financial Condition and Results of Operations, and the Company's financial statements listed in Item 14 (a)(1) of this report.
*21 - Subsidiaries of the Registrant (reference is made to the Company's Form U-3A-2 for the year ended December 31, 1996, File No. 69-78).
23(a) - Consent of Independent Accountants.
23(b) - Consent of General Counsel.
*27 - Financial Data Schedule (filed as Exhibit 27 to Form 8-K dated March 19, 1997, File No. 1-3548).
- -------------------------- * Incorporated herein by reference as indicated. + Management contract or compensatory plan or arrangement required to be filed as an exhibit to this report pursuant to Item 14(c) of Form 10-K.
(b) Reports on Form 8-K.
Report on Form 8-K dated and filed on March 19, 1997, with respect to Item 7. Financial Statements and Exhibits.
Report of Independent Accountants on Financial Statement Schedule
To the Board of Directors of Minnesota Power
Our audits of the consolidated financial statements referred to in our report dated January 27, 1997 appearing on page 23 of the 1996 Annual Report to Shareholders of Minnesota Power (which report and consolidated financial statements are incorporated by reference in this Annual Report on Form 10-K) also included an audit of the Financial Statement Schedule listed in Item 14(a) of this Form 10-K. In our opinion, the Financial Statement Schedule presents fairly, in all material respects, the information set forth therein when read in conjunction with the related consolidated financial statements.
Price Waterhouse LLP
PRICE WATERHOUSE LLP Minneapolis, Minnesota January 27, 1997
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
MINNESOTA POWER & LIGHT COMPANY (Registrant)
Dated: March 28, 1997 By EDWIN L. RUSSELL ----------------------------------- Edwin L. Russell Chairman, President and Chief Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
Signature Title Date --------- ----- ----
EDWIN L. RUSSELL Chairman, President, March 28, 1997 - ------------------------ Edwin L. Russell Chief Executive Officer and Director
D.G. GARTZKE Senior Vice President- March 28, 1997 - ------------------------ D.G. Gartzke Finance and Chief Financial Officer
MARK A. SCHOBER Controller March 28, 1997 - ------------------------ Mark A. Schober
Signature Title Date --------- ----- ----
MERRILL K. CRAGUN Director March 28, 1997 - ------------------------ Merrill K. Cragun
DENNIS E. EVANS Director March 28, 1997 - ------------------------ Dennis E. Evans
PETER J. JOHNSON Director March 28, 1997 - ------------------------ Peter J. Johnson
GEORGE L. MAYER Director March 28, 1997 - ------------------------ George L. Mayer
PAULA F. MCQUEEN Director March 28, 1997 - ------------------------ Paula F. McQueen
ROBERT S. NICKOLOFF Director March 28, 1997 - ------------------------ Robert S. Nickoloff
JACK I. RAJALA Director March 28, 1997 - ------------------------ Jack I. Rajala
AREND J. SANDBULTE Director March 28, 1997 - ------------------------ Arend J. Sandbulte
NICK SMITH Director March 28, 1997 - ------------------------ Nick Smith
BRUCE W. STENDER Director March 28, 1997 - ------------------------ Bruce W. Stender
DONALD C. WEGMILLER Director March 28, 1997 - ------------------------ Donald C. Wegmiller