Item 1. Business.
MGE Energy operates in the following business segments:
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Electric utility operations-generating, purchasing, and distributing electricity through MGE.
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Gas utility operations-purchasing and distributing natural gas through MGE.
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Nonregulated energy operations-constructing, owning, and leasing new electric generating capacity that will assist MGE through MGE Energy's wholly owned subsidiaries MGE Power, MGE Power Elm Road and MGE Power West Campus.
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Transmission Investments-investing in companies engaged in the business of providing electric transmission services, such as ATC. In the fourth quarter of 2005, the investment in ATC was transferred from MGE to MGE Transco.
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All Other-investing in companies and property which relate to the regulated operations, financing the regulated operations, or providing construction services to the other subsidiaries through its wholly owned subsidiaries MGE Construct, MAGAEL and CWDC, and Corporate functions.
MGE's utility operations represent a majority of the assets, liabilities, revenues, expenses, and operations of MGE Energy. MGE Energy's nonregulated energy operations currently include a undivided interest in the assets of the West Campus Cogeneration Facility. MGE Power West Campus owns 55% of the facility, which represents its interest in the electric generating assets and the UW owns 45% of the facility, which represents their interest in the steam and chilled water assets. The UW's share of the plant and portion of the earnings from the WCCF are not reflected in the consolidated financial statements of MGE and MGE Energy. Nonregulated energy operations also include an undivided 8.33% ownership interest in each of two 615 MW generating units being constructed in Oak Creek, Wisconsin.
As a public utility, MGE is subject to regulation by the PSCW and the FERC. The PSCW has authority to regulate most aspects of MGE's business including rates, accounts, issuance of securities, and plant and transmission line siting. The PSCW also has authority over certain aspects of MGE Energy as a holding company of a public utility. FERC has jurisdiction, under the Federal Power Act, over certain accounting practices and certain other aspects of MGE's business.
MGE Energy's subsidiaries are also subject to regulation under local, state, and federal laws regarding air and water quality and solid waste disposal. See "Environmental" below.
MGE Energy was organized as a Wisconsin corporation in 2001. MGE was organized as a Wisconsin corporation in 1896. Their principal offices are located at 133 South Blair Street, Madison, Wisconsin 53703.
Electric Utility Operations
MGE generates and distributes electricity in a service area covering a 315 square-mile area of Dane County, Wisconsin. Its service area includes the city of Madison, Wisconsin.
At December 31, 2007, MGE supplied electric service to nearly 136,000 customers, with approximately 89% located in the cities of Fitchburg, Madison, Middleton, and Monona and 11% in adjacent areas. Of the total number of customers, approximately 87% were residential and 13% were commercial or industrial. Electric revenues for 2007, 2006, and 2005 were comprised of the following:
Electric operations accounted for approximately 62.8%, 63.3%, and 60.8% of MGE's total 2007, 2006, and 2005 regulated revenues, respectively.
See Item 2, Properties, for a description of MGE's electric utility plant.
MGE has chosen to join the MRO as its regional reliability council. The essential purposes of the MRO are: (1) the development and implementation of regional and NERC reliability standards, and (2) determining compliance with those standards, including enforcement mechanisms. The MRO also provides other services consistent with its reliability charter.
Transmission
Reliability 2000 legislation enacted in Wisconsin mandated, among other things, the creation of a statewide transmission company to own the investor-owned utilities' transmission assets. Pursuant to these provisions, effective January 1, 2001, MGE transferred all of its electric utility transmission assets to ATC in exchange for an ownership interest in ATC. At December 31, 2007, MGE Transco held a 3.6% ownership interest in ATC as a result of the aforementioned assets transferred and subsequent additional capital contributions made.
ATC is owned by the utilities that contributed facilities or capital in accordance with Wisconsin law. ATC's purpose is to provide reliable, economic transmission service to all customers in a fair and equitable manner. ATC plans, constructs, operates, maintains, and expands transmission facilities that it owns to provide adequate and reliable transmission of power. ATC is regulated by FERC for all rate terms and conditions of service and is a transmission-owning member of the Midwest ISO. MGE is however a non-transmission owning member of the Midwest ISO.
Regional Transmission Organizations
On February 1, 2002, MGE started taking network transmission service from the Midwest ISO. Midwest ISO is a nonprofit RTO approved by FERC. The Midwest ISO is responsible for monitoring the electric transmission system that delivers power from generating plants to wholesale power transmitters. Its role is to ensure equal access to the transmission system and to maintain or improve electric system reliability in the Midwest.
As a FERC approved RTO, Midwest ISO is required to provide a real-time market-based mechanism for congestion management. On April 1, 2005, Midwest ISO implemented its bid-based energy market. At that time, MGE began offering substantially all of its generation on the Midwest ISO market and purchasing much of its load requirement from the Midwest ISO market in accordance with the Midwest ISO Tariff.
Additionally, on May 1, 2004, MGE became a member of PJM. PJM is also an RTO. PJM is a neutral and independent party that coordinates and directs the operation of the region's transmission grid, administers a competitive wholesale electricity market, and plans regional transmission expansion improvements to maintain grid reliability and relieve congestion. MGE has two purchase power agreements, for a total of 65 MW, that are impacted by this market.
Fuel supply and generation
MGE satisfies its customers' electric demand with purchased power and internal generation. During the years ended December 31, 2007, 2006, and 2005, MGE's electric energy delivery requirements were satisfied by the following sources:
Sources used depend on market prices, generating unit availability, weather, and customer demand.
Coal
MGE and two other utilities jointly own Columbia, a coal-fired generating facility, which accounts for 29% (225 MW) of MGE's net generating capability. Power from this facility is shared in proportion to each owner's ownership interest. MGE has a 22% ownership interest in Columbia. The other owners are Alliant, which operates Columbia, and WPSC. The Columbia units burn low-sulfur coal obtained (pursuant to long-term contracts) from the Powder River Basin coal fields located in Wyoming and Montana.
MGE's share of the coal inventory supply for the units increased from 31 days on December 31, 2006, to 33 days on December 31, 2007. The co-owners' current goal is to maintain approximately a 35 day inventory.
MGE also owns the Blount Generating Facility located in Madison, Wisconsin, which is fueled by coal, gas, and other alternative renewable sources. On January 19, 2006, MGE announced a plan, subject to certain conditions, that includes discontinuing coal use at the end of 2011 at Blount. The plant will continue to run on natural gas but will be reduced from its current approximate 190 MW capacity to 100 MW when coal burning is discontinued.
Natural gas and oil
MGE owns gas fired combustion turbines. These turbines are primarily located in Madison and Marinette, Wisconsin and have a total of 174 MW of generating capacity.
See discussion above for discussion of the Blount Generating Facility and see below discussion under Nonregulated Operations for MGE's interest in a natural gas-fired cogeneration facility on the UW campus.
Renewable generation sources
On September 29, 2006, MGE formalized plans to acquire 29.7 MW or 18 turbines in a wind-powered electric generating facility to be constructed in Worth County, Iowa. This project is expected to be completed in the first quarter of 2008. At December 31, 2007, MGE had incurred $55.9 million (excluding AFUDC) of costs on the project, which is reflected in the Construction Work in Progress balance on MGE and MGE Energy's consolidated balance sheets. Additionally, MGE had recorded a total of $2.4 million in AFUDC-debt and equity which is also reflected in Construction Work in Progress at December 31, 2007. MGE will begin recovering the cost of this project in rates in 2008.
Purchased power
As mentioned under the discussion on "Regional Transmission Organizations" above, at the time Midwest ISO implemented its bid-based energy market, MGE began offering substantially all of its generation on the Midwest ISO market and purchasing much of its load requirement from the Midwest ISO market in accordance with the Midwest ISO Tariff. Accordingly, the Midwest ISO market is the source of MGE's purchased power needs.
MGE also has purchase power contracts with two companies located in the PJM market. These agreements provide a means for MGE to participate in the PJM market via the receipt of FTRs. Under these agreements MGE has the contractual right to 65 MW of power.
On September 21, 2007, MGE entered into a ten-year purchase power agreement which provides MGE with firm capacity, energy, and a pro-rata share of the counterparty's rights to renewable attributes beginning on June 1, 2012, and ending on May 31, 2022 (the "base term"). This agreement obligates MGE to purchase a minimum of 50 MW of capacity each year and a fixed amount of energy. Pursuant to the terms of this agreement, MGE has the option to extend the ten year term and/or purchase additional energy and capacity during the base term. MGE has not exercised either of these options at this time.
On April 23, 2007, MGE entered into a 20-year purchase power agreement for wind generation. Under this agreement, MGE has agreed to purchase 30 MW of wind power from the Top of Iowa II project which is being constructed in Iowa. This facility became operational in January 2008. MGE does not have any capacity payment commitments under this agreement. However, MGE is obligated to purchase its ratable share of the energy produced by the project.
On February 21, 2007, MGE and Invenergy signed an amendment to an existing purchase power agreement. Under this amended agreement, MGE has agreed to purchase for a 20-year term approximately 15 MW of wind power at a facility to be constructed near Brownsville, Wisconsin. Construction of this facility began in June 2007 and the facility is expected to be operational in early 2008. MGE does not have any capacity payment commitments under this agreement. However, MGE is obligated to purchase its ratable share of the energy produced by the unit.
Gas Utility Operations
MGE transports and distributes natural gas in a service area covering 1,625 square miles in seven south-central Wisconsin counties. Its service area includes the city of Madison, Wisconsin.
On December 31, 2007, MGE supplied natural gas service to nearly 140,000 customers in the cities of Elroy, Fitchburg, Lodi, Madison, Middleton, Monona, Prairie du Chien, Verona, and Viroqua; 24 villages; and all or parts of 45 townships. Of the total number of customers, approximately 89% were residential and 11% were commercial or industrial. Gas revenues for 2007, 2006, and 2005 were comprised of the following:
Gas operations accounted for approximately 37.2%, 36.7%, and 39.2% of MGE's total 2007, 2006, and 2005 regulated revenues, respectively.
MGE can curtail gas deliveries to its interruptible customers. Approximately 7% of gas deliveries in 2007 and 8% of gas sold in 2006 were to interruptible customers.
Gas supply
MGE has physical interconnections with ANR and NNG. MGE's primary service territory, which includes Madison and the surrounding area, receives deliveries at one NNG and four ANR gate stations. MGE also receives deliveries at NNG gate stations located in Elroy, Prairie du Chien, Viroqua, and Crawford County. Interconnections with two major pipelines provide competition in interstate pipeline service and a more reliable and economical gas supply mix, which includes gas from Canada and from the mid-continent and Gulf/offshore regions in the United States.
During the winter months, when customer demand is high, MGE is primarily concerned with meeting its obligation to firm customers. MGE meets customer demand by using firm supplies under contracts finalized before the heating season, supplies in storage (injected during the summer), and other firm supplies purchased during the winter period.
By contract, a total of 5,430,964 Dth can be injected into ANR's storage fields in Michigan from April 1 through October 31. These gas supplies are then available for withdrawal during the subsequent heating season, November 1 through March 31. Using storage allows MGE to buy gas supplies during the summer season, when prices are normally lower, and withdraw these supplies during the winter season, when prices are typically higher. Storage also gives MGE more flexibility in meeting daily load fluctuations.
MGE's contracts for firm transportation service include winter maximum daily quantities of:
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161,150 Dth (including 96,078 Dth of storage withdrawals) on ANR.
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59,608 Dth on NNG.
Nonregulated Energy Operations
MGE Energy, through its subsidiaries, seeks to develop generation sources that will assist MGE in meeting the electricity needs of its customers. Decisions on the type of energy source and its size, timing, ownership, and financing depend upon a number of factors including the growth of customer demand in MGE's service area and surrounding areas, the effectiveness of customer demand management efforts, the costs and availability of alternative power sources, the availability of transmission capacity, issues associated with siting power generation sources, available financing and ownership structures, regulatory treatment and recovery, construction lead times and risks, and other factors. The decisions tend to involve long-time horizons due to the lead time involved in siting and constructing new generation sources and the associated transmission infrastructure.
WCCF
MGE Power West Campus and the UW jointly own undivided interests in a natural gas-fired cogeneration facility on the UW campus. The facility has the capacity to produce 20,000 tons of chilled water, 500,000 pounds per hour of steam, and approximately 150 MW of electricity. The UW owns 45% of the facility, which represents its interest in the chilled-water and steam assets. These assets are used to meet the UW's growing need for air-conditioning and steam-heat capacity. MGE Power West Campus owns 55% of the facility, which represents its interest in the electric generating assets. These assets are used to provide electricity to MGE's customers. The UW's share of the plant and portion of the earnings from the WCCF are not reflected in the consolidated financial statements of MGE or MGE Energy. MGE Power West Campus' share of the cost of this project is reflected in Property, Plant, and Equipment on MGE and MGE Energy's consolidated balance sheets
MGE leases the electric generating assets owned by MGE Power West Campus and is responsible for operating the entire facility. On April 26, 2005, the facility lease between MGE and MGE Power West Campus commenced. The financial terms of the facility lease include a capital structure of 53% equity and 47% long-term debt, return on equity of 12.1%, and a lease term of 30 years. At the end of the lease term in 2035, MGE may, at its option, renew the facility lease for an additional term, purchase the generating facility at fair market value or allow the lease contract to end. Under the Joint Ownership Agreement for WCCF, the State has an option to acquire at the higher of book or market cost, a 45 MW interest in WCCF or enter into a purchase power agreement for 45 MWs of capacity.
Elm Road
On November 4, 2005, MGE Power Elm Road closed on the exercise of an option to acquire an undivided 8.33% ownership interest in each of two 615 MW advanced technology, coal-fired generating units being constructed by We Energies in Oak Creek, Wisconsin. MGE Power Elm Road's estimated share of capital costs for its 8.33% ownership interest in both units is approximately $171 million (excluding capitalized interest) which it intends to finance primarily through funds received from MGE Energy. MGE Energy expects that these funds will be raised through the sale of common stock (via the Stock Plan), short-term debt, and operating cash flows. At December 31, 2007, MGE Power Elm Road had incurred $103.7 million (excluding capitalized interest) of costs on the project, which is reflected in the Construction Work In Progress balance on MGE and MGE Energy's consolidated balance sheets.
On the date of acquisition, MGE Energy and its subsidiaries entered into various agreements, including a facility lease agreement. This facility lease agreement is between MGE Power Elm Road (a nonregulated subsidiary of MGE Energy) and MGE. The financial terms of the facility lease include a capital structure of 55% equity and 45% long-term debt, and return on equity of 12.7%, a lease term of 30 years, and a 5% rent reduction in the first five years.
On November 1, 2005, MGE received approval from the PSCW to defer payments made to MGE Power Elm Road for carrying costs during construction of the facility, management fees, and community impact mitigation costs. MGE began collecting the carrying costs in rates in 2006. MGE estimates total carrying costs to be approximately $53.6 million. Of these costs, $21.1 million is estimated to relate to the capitalized interest and the debt portion of the facility. These costs will be recognized over the period in which the facility will be depreciated. The remaining $32.5 million is estimated to represent the equity portion and is being recognized over the period recovered in rates.
Environmental
MGE is subject to local, state, and federal regulations concerning air quality, water quality, and solid waste disposal. The EPA administers certain federal statutes relating to such matters. The DNR administers certain state statutes as to such matters and has primary jurisdiction over standards relating to air and water quality and solid and hazardous waste. Those regulations affect the manner in which MGE conducts its operations, the costs of those operations, as well as some capital and operating expenditures. It can also affect the siting, timing, and cost of new projects or other significant actions affecting the environment. MGE is not able to predict the direction of future regulations or if compliance with any such regulations will involve additional expenditures for pollution control equipment, plant modifications, or curtailment of operations. Such actions could reduce capacity or efficiency at existing plants or delay the construction and operation of future generating facilities.
Air quality
Air quality regulations promulgated by the EPA and DNR in accordance with the Federal Clean Air Act and the Clean Air Act Amendments of 1990 impose restrictions on emission of particulates, sulfur dioxide (SO2) nitrogen oxides (NOx) and other pollutants and require permits for operation of emission sources. These permits have been obtained by MGE and must be renewed periodically. Various initiatives, including the Clean Air Interstate Rule (CAIR), Clean Air Mercury Rule (CAMR), maximum achievable control technology (MACT) standards, new source performance standards (NSPS) and Regional Haze Regulations, as well as existing and proposed state mercury emissions limits, may result in additional operating and capital expenditure costs.
The CAIR requires NOx and SO2 emission reductions in two phases and includes a regional cap-and-trade system. The first phase begins in 2009 for NOx and 2010 for SO2, and contemplates reductions of 55% and 40%, respectively, increasing in the second phase by 2015 to 65% and 70%, respectively; in each case over 2003 levels. MGE owns several generation units currently subject to CAIR: Blount Generating Station, Columbia, M34 (West Marinette) and Fitchburg Substation. In future generation years, Elm Road will be and WCCF may be affected by CAIR. MGE anticipates that it may need to purchase NOx and SO2 allowances and /or install equipment at Columbia to meet CAIR allocations for its generation fleet. The exact cost of the allowances and/or equipment installation is not known at this time.
CAMR seeks to reduce mercury emissions from coal-fired power plants through a system of monitoring and several compliance options, including equipment installations and allowance trading options through a cap-and-trade system, which are scheduled to commence in 2009; although there is some uncertainty in light of a February 8, 2008 U.S. Court of Appeals decision invalidating the rule's cap-and-trade provisions. In March 2007, the DNR proposed state mercury rules under NR 446 to address its requirements under CAMR. The state's proposed rule is significantly different from the federal CAMR. If the state's version of CAMR as currently proposed becomes a rule, it will increase CAMR compliance costs for Columbia, Blount and Elm Road (those facilities currently subject to CAMR) because it is more restrictive in scope than the federal CAMR. However, it is unknown at this time what those additional costs would be. The Wisconsin DNR has announced that it intends to introduce a revised proposed rule some time in 2008. Thus, the economic and operational effect on MGE is not known at this time.
Air modeling indicates that emissions from Columbia may impair visibility at certain Class I Scenic Areas and may therefore be subject to Regional Haze and Best Available Retrofit Technology (BART) regulations. DNR expects to submit rules on BART and/or Regional Haze to EPA in 2008 with BART becoming effective in 2013. The State of Minnesota has also asserted that Wisconsin emission sources significantly contribute to visibility impairment at the Boundary Water Canoe Wilderness Area and Voyageurs National Park. Minnesota has asked Wisconsin to evaluate reducing the Wisconsin statewide average SO2 and NOx emission rates for electric generating units to approximately 0.25 lbs/MMBtu by 2018. If adopted, these rates could affect capital, operational and maintenance expenses at MGE's generating facilities.
In 1998, the EPA issued a rule that imposed a NOx emission budget for emission sources in Wisconsin. In 2000, the Court of Appeals for the District of Columbia invalidated a portion of the rule as applied to Wisconsin; however, the Court stayed that portion of the challenge concerning Wisconsin's alleged impacts on downwind, eight-hour ozone nonattainment areas. EPA has also stayed that portion of the rule concerning Wisconsin's alleged impacts on downwind eight-hour ozone nonattainment areas. If that portion of the rule concerning eight-hour ozone nonattainment areas is upheld, the resulting NOx emission budget for Wisconsin could potentially affect the level of permissible NOx emissions from Blount, Columbia, and WCCF.
The EPA recently lowered the acceptable 24-hour National Ambient Air Quality Standards (NAAQS) for fine particulate matter, i.e., particles that are 2.5 microns or smaller in diameter and states must monitor and collect data on fine particulate levels in order to establish attainment and nonattainment areas for the new standard. States (including Wisconsin) determine designation by county and/or area based on whether the county/area meets the NAAQS (designated as attainment) or the county does not meet the NAAQS (designated as nonattainment), as measured by air monitors placed in that county/area. In mid-December 2007, Wisconsin recommended that the EPA designate all areas in the state as attainment. However, EPA will finalize designations (attainment or nonattainment) in 2009. Updated air monitoring results may play a role in EPA's designation decision. Designations of nonattainment and implementation of the fine particulate NAAQS could affect capital, operational and maintenance expenses at generating facilities.
Compliance with these and other related environmental initiatives is expected to result in significant additional operating and capital expenditures at Columbia. The Columbia operator's current estimates show that MGE's share of the capital expenditures required to comply with these environmental initiatives will be between $130 million and $200 million. According to current estimates, compliance with these initiatives is also expected to result in an increase to MGE's pro-rata share of Columbia's on-going operating expenses. The operator and MGE management are continuing to explore various alternatives to comply with these standards. Accordingly, actual capital expenditures may fall above or below the range provided. These standards and initiatives may also result in additional capital and operating expenditures at MGE's other generating facilities. MGE expects that the costs to comply with these standards will be fully recoverable through rates. Pursuant to an order issued by the PSCW on September 14, 2007, MGE is permitted to defer pre-certification and pre-construction costs related to compliance with CAIR and CAMR regulations at Columbia. Additionally, MGE is entitled to 100% AFUDC on the related pre-construction costs.
Water quality
MGE is subject to water quality regulations issued by the DNR. These regulations include categorical-effluent discharge standards, which require the use of effluent-treatment processes equivalent to categorical "best practicable" or "best available" technologies under compliance schedules established under the Federal Water Pollution Control Act. The DNR has published categorical regulations for chemical and thermal discharges from electric-steam generating plants. The regulations limit discharges from MGE's plants into Lake Monona and other Wisconsin waters. The DNR has also proposed rules regarding thermal discharge which are subject to comment and further modification. Depending on the terms of the final rules, MGE may be required to make significant additional capital expenditures but are expected to be recoverable in rates.
In 2004, the EPA promulgated final rules under Section 316(b) of the Clean Water Act addressing cooling water intake structures for existing large power plants (Phase II rule). A challenge to this rule was upheld in a January 2007 court decision and significant parts of the rule were remanded to the EPA for further consideration. In July 2007, EPA suspended the Phase II rule in its entirety and directed states to use their "best professional judgment" in evaluating intake systems. The ruling, and EPA's actions in response, which may change the compliance requirements, may affect the timing and costs associated with MGE's WPDES permit for Blount and possibly the WPDES permit for the Oak Creek/Elm Road facility. At this time, MGE is unable to determine the timing or amount of that impact.
The WPDES permit for the Oak Creek/Elm Road facility has been contested. On November 29, 2007, an Administrative Law Judge (the "ALJ") determined that the two additional coal units that are part of the Oak Creek expansion are "new facilities" under Section 316(b) of the Federal Clean Water Act and therefore are subject to the standards promulgated by EPA for new facilities in the so-called Phase I rule. Unlike the Phase II rule for existing facilities previously discussed, the Phase I rules for new facilities largely withstood judicial review and are valid. The ALJ did not vacate the WPDES permit or any other permit necessary to continue construction of the two additional coal units, pointing out that, based upon the present record, the water intake currently under construction as part of the Oak Creek expansion may be permittable under the standards that apply to new facilities.
The ALJ remanded the WPDES permit to the WDNR with a direction that it reissue or modify the permit to reflect "best technology available" to comply with the standards applicable to new facilities under Wisconsin state law. As part of the decision, the ALJ restated his prior opinion that the water intake system currently under construction may not be operated so long as it remains a contested matter regarding the WPDES permit. The ALJ's ruling has been appealed to circuit court.
The Operator has advised us that there are alternatives under the EPA's rule for new facilities that would permit the use of the once-through cooling system rather than the use of cooling towers. The Operator has requested the WDNR to issue a modified permit and has submitted additional information to the WDNR supporting the request for approval of the once-through cooling system under this rule. The Operator anticipates the WDNR will complete the WPDES permit modifications process in the first half of 2008. At this time, we cannot predict with certainty what the WDNR's decision will be. A reissued permit would be subject to public comment and possible administrative and legal review.
While the process for modifying the WPDES permit proceeds, construction of the additional coal units will continue on the current schedule.
Solid waste
MGE is listed as a potentially responsible party for a site the EPA has placed on the national priorities Superfund list. The Lenz Oil site in Lemont, Illinois, was used for storing and processing waste oil for several years. This site requires clean up under the Comprehensive Environmental Response, Compensation and Liability Act. A group of companies, including MGE, is currently working on cleaning up the site. Management believes that its share of the final cleanup costs for the Lenz Oil site will not result in any materially adverse effects on MGE's operations, cash flows, or financial position. Insurance may cover a portion of the cleanup costs. Management believes that the cleanup costs not covered by insurance will be recovered in current and future rates. As of December 31, 2007, a $0.1 million gross liability was accrued for this matter.
Global climate change
The United States is currently not a party to the United Nations' Kyoto Protocol that became effective for signatories on February 16, 2005. The Protocol process generally requires developed countries to cap greenhouse gas (GHG) emissions at certain levels during the 2008 to 2012 time period. Although GHG is not currently regulated in the United States, MGE recognizes that these gases-particularly carbon dioxide (CO2), which is released in the burning of fossil fuels-may face future legislative or regulatory restrictions. Environmental-related legislation is regularly introduced in Congress and in the Wisconsin legislature. Such legislation typically includes various compliance dates and compliance limits. There are several proposed versions of legislation pending in Congress and in the Wisconsin legislature to address global climate changes, including efforts to reduce and control and/or tax the emission of greenhouse gases, such as carbon dioxide, created in the combustion of fossil fuels, including coal, natural gas, and oil. Bills are also considering releases associated with natural gas pipelines and company fleets. In addition, there could be national and state mandates to produce increasing percentages of electricity from renewable forms of energy, such as wind. Such legislation could have the potential for a significant financial impact on MGE, including the cost to install new emission control equipment, purchase allowances, or do fuel switching. However, the financial consequences of this compliance cannot be determined until final legislation is passed. MGE management would expect to seek and receive recovery of such compliance measures through rate increases, yet the probability and specific impact of such legislation cannot be reasonably estimated at this time. MGE will continue to monitor proposed legislation.
Employees
As of December 31, 2007, MGE had 724 employees. MGE employs 247 employees who are covered by a collective bargaining agreement with Local Union 2304 of the International Brotherhood of Electrical Workers and 102 employees who are covered by a collective bargaining agreement with Local Union No. 39 of the Office and Professional Employees International Union. Both of these collective bargaining agreements expire on April 30, 2009. There are also five employees covered by a collective bargaining agreement with Local Union No. 2-111 of the United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied Industrial, and Service Workers International Union. This collective bargaining agreement expires on November 1, 2009.
Financial Information About Segments
See Footnote 24 of the Notes to Consolidated Financial Statements for financial information relating to MGE Energy's and MGE's business segments.
Executive Officers of the Registrants
Executive
Title
Effective
Date
Service
Years as
an Officer
Gary J. Wolter(a)
Age: 53
Chairman of the Board, President and Chief Executive Officer
02/01/2002
Lynn K. Hobbie(b)
Age: 49
Senior Vice President
02/01/2000
James G. Bidlingmaier(b)
Age: 61
Vice President - Admin. and Chief Information Officer
02/01/2000
Kristine A. Euclide(b)
Age: 55
Vice President and General Counsel
11/15/2001
Terry A. Hanson(a)
Age: 56
Vice President, Chief Financial Officer and Secretary
10/01/2001
Scott A. Neitzel(b)
Age: 47
Vice President - Energy Supply
Vice President- Energy Supply Policy
09/01/2006
07/01/2002
Jeffrey C. Newman(a)
Age: 45
Vice President and Treasurer
01/01/2001
Peter J. Waldron(b)
Age: 50
Vice President and Operations Officer
Vice President - Energy Supply Operations
09/01/2006
07/01/2002
Note: Ages, years of service, and positions as of December 31, 2007.
(a)
Executive officer of MGE Energy and MGE
(b)
Executive officer of MGE
Item 1A.
Item 1A. Risk Factors.
MGE Energy and its subsidiaries, including MGE, operate in a market environment that involves significant risks, many of which are beyond their control. The following risk factors may adversely affect their results of operations, cash flows and market price for their publicly traded securities. While MGE Energy and MGE believe they have identified and discussed below the key risk factors affecting their business, there may be additional risks and uncertainties that are not presently known or that are not currently believed to be significant that may adversely affect their performance or financial condition in the future.
Regulatory Risk
We are subject to extensive government regulation in our business, which affects our costs and responsiveness to changing events and circumstances.
Our business is subject to regulation at the State and Federal levels. We are subject to regulation as a holding company by the PSCW. MGE is regulated by the PSCW as to its rates, terms and conditions of service; various business practices and transactions; financing; and transactions between it and its affiliates, including MGE Energy. MGE is also subject to regulation by the FERC, which regulates certain aspects of its business. The regulations adopted by the State and Federal agencies affect the manner in which we do business, our ability to undertake specified actions since pre-approval or authorization may be required, the costs of operations, and the level of rates charged to recover such costs. Our ability to attract capital is also dependent in part, upon our ability to obtain a fair return from the PSCW.
We face risk for the recovery of fuel and purchased power costs when they exceed the base rate established in MGE's current rate structure.
MGE burns natural gas in several of its peak electric generation facilities, and in many cases, the cost of purchased power is tied to the cost of natural gas. MGE bears significant regulatory risk for the recovery from customers of such fuel and purchased power costs when they are higher than the base rate established in its current rate structure.
We are subject to environmental laws and regulations that affect our costs and business plans.
Our subsidiaries are subject to environmental laws and regulations that affect the manner in which they conduct business, including capital expenditures, operating costs and potential liabilities. Changes and developments in these laws and regulations may change or limit our business plans, make them more costly to implement, or expose us to liabilities for past or current operations.
Numerous environmental regulations govern many aspects of our present and future operations, including air emissions, water quality, wastewater discharges, solid waste, and hazardous waste; and continue to evolve in response to real or perceived concerns, regulatory initiatives, non-governmental organizational initiatives and private parties and legal process. The development of these regulations can introduce uncertainty into the planning and implementation process for long-lead time projects, such as generating stations, and can introduce costly delays if previous decisions need to be revisited as a result of judicial mandate or regulatory change. These regulations generally require us to obtain and comply with a wide variety of environmental licenses, permits, inspections, and other approvals, and can result in increased capital, operating, and other costs, particularly with regard to enforcement efforts focused on power plant emissions obligations. These effects can be seen not only with respect to new construction, such as our participation in the Elm Road generating units, but could also require the addition of additional control equipment or the implementation of other compliance measures.
In addition, we may be a responsible party for environmental clean up at sites identified as containing hazardous materials. It is difficult to predict the costs potentially associated with a site clean-up due to the potential joint and several liability for all potentially responsible parties, the nature of the clean-up required and the availability of recovery from other potentially responsible parties.
We may incur material costs of compliance if federal and/or state legislation is adopted to address climate change.
Various persons, including legislators, regulators and private parties, have increasingly expressed concern about the effects of global warming and the effects of greenhouse gases (GHG). These concerns have prompted federal and state legislation that would regulate or cap such emissions to be actively discussed. There are several proposed versions of legislation pending in the U.S. Congress and in the Wisconsin legislature to address global climate changes, including efforts to reduce and control and/or tax the emission of GHG, such as carbon dioxide, created in the combustion of fossil fuels, including coal, natural gas, and oil. Bills are also considering releases associated with natural gas pipelines and company fleets. These legislative initiatives are sometime paired with efforts to mandate increasing percentages of electricity from renewable forms of energy, such as wind, or to reduce the demand for electricity. Such legislation could have the potential for a significant financial impact on MGE, including the cost to install new emission control equipment, purchase allowances, or do fuel switching. However, the financial consequences of this compliance cannot be determined until final legislation is passed.
Our business may be negatively affected by the restructuring of the energy industry.
MGE is a member of the Midwest ISO, a FERC-approved RTO. Effective April 1, 2005, Midwest ISO implemented its bid-based energy market. MGE cannot predict the impact the new market may ultimately have on its electric operations. Also, the ability of Midwest ISO to maintain its members is an important factor in the success of its operations.
Operating Risk
We are affected by weather, which affects customer demand and can affect the operation of our facilities.
The demand for electricity and gas is affected by weather. Very warm and very cold temperatures, especially for prolonged periods, can dramatically increase the demand for electricity for cooling and heating, respectively, as opposed to the softening effect of more moderate temperatures. Our electric revenues are sensitive to the summer cooling season and, to a lesser extent, the winter heating season. Similarly, very cold temperatures can dramatically increase the demand for gas for heating. A significant portion of our gas system demand is driven by heating. Extreme summer conditions or storms may stress electric transmission and distribution systems, resulting in increased maintenance costs and limiting the ability to meet peak customer demand.
We are affected by economic activity within our service area.
Higher levels of development and business activity generally increase the numbers of customers and their use of electricity and gas. Likewise, periods of recessionary economic conditions generally adversely affect our results of operations.
Our ability to manage our purchased power costs is influenced by a number of uncontrollable factors.
We are exposed to additional purchased power costs to the extent that our power needs cannot be fully covered by the supplies available from our existing facilities and contractual arrangements. Those needs, and our costs, could be affected by:
•
Increased demand due to, for example, weather, customer growth, or customer obligations,
•
The inability to transmit our contracted power from its generation source to our customers due to transmission line constraints, outages, or equipment failures,
•
Reductions in the availability of power from our owned or contracted generation sources due to equipment failures, shortages of fuel or environmental limitations on operations, and
•
Failure to perform on the part of any party from which we purchase capacity or energy.
An unexpected change in demand or the availability of generation or transmission facilities can expose us to increased costs of sourcing electricity in the short-term market where pricing may be more volatile.
Our financial performance depends on the equipment and facilities in our distribution system being operational.
Weather conditions, accidents, catastrophic events, and failures of equipment or facilities can disrupt or limit our ability to deliver electricity and gas. Efforts to repair or replace equipment and facilities may not be successful, or we may be unable to make the necessary improvements to our distribution system, causing service interruptions. The resulting interruption of services could result in lost revenues and additional costs.
We face construction risk in connection with the completion of generating units.
We have assumed risks under the agreements related to our ownership interest in two 615 MW coal-fired generating units being constructed in Oak Creek, Wisconsin. The completion of this project is subject to construction risks over which we will have limited or no control and which might adversely affect project costs and completion time. These risks include shortages of, the inability to obtain, or the cost of, labor or materials; the inability of the general contractor or subcontractors to perform under their contracts; strikes; adverse weather conditions; the inability to obtain necessary permits in a timely manner, legal challenges and appeals to granted permits, including the WPDES permit, and changes in applicable laws or regulations; governmental actions; and events in the global economy. In addition, in the case of the units being constructed in Oak Creek, if the units' final construction costs exceed the fixed costs allowed in the PSCW order, this excess will not be recoverable from MGE or its customers unless specifically allowed by the PSCW. Any Oak Creek project costs above the authorized amount, but below a 5% cap, will be subject to a prudence determination made by the PSCW.
Financial Risk
We are exposed to commodity price risk relating to our purchases of natural gas, electricity, coal and oil.
We face commodity price risk exposure with respect to our purchases of natural gas, electricity, coal and oil, SO2 allowances and risk through our use of derivatives, such as futures, forwards and swaps, to manage that commodity price risk. We could experience increased costs as a result of volatility in the market values of those commodities. We could also experience losses on our derivative contracts as a result of that market value volatility or if a counterparty fails to perform under a contract. In the absence of actively quoted market prices and pricing information from external sources, the valuation of these derivative contracts involves our exercise of judgment and use of estimates. As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the reported fair value of these contracts.
We are exposed to interest rate risk.
We are exposed to interest rate risk on our variable rate financing. MGE Energy had $103.5 million of variable-rate debt outstanding at December 31, 2007, including $61.0 million for MGE. Borrowing levels under commercial paper arrangements vary from period to period depending upon capital investments and other factors. Such interest rate risk means that we are exposed to increased financing costs and associated cash payments as a result of changes in the short-term interest rates.
Market performance affects our employee benefit plan asset values.
The performance of the capital markets affects the values of the assets that are held in trust to satisfy the future obligations under our pension and postretirement benefit plans. We have significant obligations in these areas and hold significant assets in these trusts. A decline in the market value of those assets may increase our current and longer-term funding requirements for these obligations.
We are exposed to credit risk primarily through our regulated energy business.
Credit risk is the loss that may result from counterparty nonperformance. We face credit risk primarily through MGE's regulated energy business. Failure of contractual counterparties to perform their obligations under purchase power agreements, commodity supply arrangements or other agreements may result in increased expenses for MGE as a result of being forced to cover the shortfall in the spot or short-term market, where prices may be more volatile.
As a holding company, we are dependent on upstream cash flows from our subsidiaries for the payment of dividends on our common stock.
As a holding company, we have no operations of our own, our ability to pay dividends on our common stock is dependent on the earnings and cash flows of our operating subsidiaries and their ability to pay upstream dividends or to repay funds to us. Prior to funding us, our subsidiaries have financial obligations that must be satisfied, including among others, debt service and obligations to trade creditors, and are subject to contractual and regulatory restrictions on the payment of dividends.
Disruptions in the financial markets as a result of the effects of sub-prime financing and related matters may affect our ability to finance at a reasonable cost and in accordance with our planned schedule.
The credit markets have experienced some disruption and uncertainty as a result of the developments associated with sub-prime mortgage issues. To the extent that such issues affect the ability or willingness of credit providers or investors to participate in the credit markets or particular types of investments, or affect their perception of the risk associated with particular types of investments, our cost of borrowing could be affected.
Item 1B.
Item 1B. Unresolved Staff Comments.
MGE Energy and MGE
None.
Item 2.
Item 2. Properties.
Electric Generation
Net generating capability in service at December 31, 2007, was as follows:
(1)
Baseload generation.
(2)
MGE's 22% share of two 512-MW units. The other owners are Alliant, which operates Columbia, and WPSC.
(3)
On January 19, 2006, MGE announced that it would cease coal-fired generation at Blount in 2011, subject to certain conditions, including regulatory approvals.
(4)
Facility is jointly owned. MGE Power West Campus owns a controlling interest in the electric generation plant and the UW owns a controlling interest in the chilled-water and steam plants. MGE leases the electric generating assets owned by MGE Power West Campus and is responsible for operating the facility. Amounts shown represent MGE's share of the net capability.
(5)
Based on the terms of the joint plant agreement between MGE and the UW, the UW has the ability to reduce net capability of these units by approximately 27 MW in the winter and approximately 17 MW in the summer.
Electric and Gas Distribution Facilities
Major electric distribution lines and substations in service at December 31, 2007, which are owned by MGE, are as follows:
Gas facilities include 2,398 miles of distribution mains, which are owned by MGE.
A significant portion of MGE's electric and gas distribution facilities is located above or underneath highways, streets, other public places or property that others own. MGE believes that it has satisfactory rights to use those places or property in the form of permits, grants, easements and licenses; however, it has not necessarily undertaken to examine the underlying title to the land upon which the rights rest.
Transmission Facilities
As required by Wisconsin law, MGE and other Wisconsin electric utilities transferred their electric transmission assets to ATC on January 1, 2001. MGE received an ownership interest in ATC in exchange for its transmission plant and related deferred taxes and deferred investment tax credits. That interest is presently held by MGE Transco. MGE receives a return on its investment in ATC that is approximately equal to the return it would have earned by retaining its transmission facilities.
Item 3.
Item 3. Legal Proceedings.
MGE Energy and MGE
MGE Energy and its subsidiaries, including MGE, from time to time are involved in various legal proceedings that are handled and defended in the ordinary course of business. While MGE Energy and MGE are unable to predict the outcome of these matters, management does not believe, based upon currently available facts, that the ultimate resolution of any of such proceedings would have a material adverse effect on their overall financial condition or results of operations.
Also see "Environmental" under Item 1, Business, for a description of several environmental proceedings involving MGE.
Item 4.
Item 4. Submission of Matters to a Vote of Security Holders.
MGE Energy and MGE
None.
PART II.
Item 5.
Item 5. Market for Registrants' Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities.
Market for Common Equity
MGE Energy
MGE Energy common stock is traded on Nasdaq under the symbol MGEE. On February 1, 2008, there were approximately 18,480 shareholders of record. The following table shows high and low sale prices for the common stock on Nasdaq for each quarter over the past two years.
MGE
As of February 1, 2008, there were 17,347,889 outstanding shares of common stock, all of which were held by MGE Energy. There is no market for shares of common stock of MGE.
Dividends
MGE Energy
The following table sets forth MGE Energy's quarterly cash dividends declared during 2007 and 2006:
MGE
The following table sets forth MGE's quarterly cash dividends declared during 2007 and 2006:
See "Liquidity and Capital Resources - Financing Activities" under Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations, for a description of restrictions applicable to dividend payments by MGE.
Issuer Purchases of Equity Securities
MGE Energy and MGE
None.
Item 6.
Item 6. Selected Financial Data.
MGE Energy
(In thousands, except per-share amounts)
*Includes current maturities.
Item 7.
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations.
General
MGE Energy is a holding company operating through subsidiaries in five business segments: electric utility operations, gas utility operations, nonregulated energy operations, transmission investments, and all other. Our principal subsidiary is MGE, which conducts our electric utility and gas utility operations and represents a majority portion of our assets, liabilities, revenues, and expenses. MGE generates and distributes electricity to nearly 136,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to nearly 140,000 customers in the Wisconsin counties of Columbia, Crawford, Dane, Iowa, Juneau, Monroe, and Vernon.
Our nonregulated energy operations have been formed to lease and own new electric generating capacity. Our nonregulated energy operations include the leasing of the cogeneration project on the UW-Madison campus. Our nonregulated energy operations also include an undivided 8.33% ownership interest in each of two 615 MW generating units being constructed in Oak Creek, Wisconsin. Both of these operations are included in MGE's consolidated financial statements as a result of the accounting requirements of FIN 46R.
The transmission investment segment consists of our investment in ATC and the related equity earnings.
Our all other segment includes corporate operations and services, as well as certain construction services.
Our primary focus today and for the foreseeable future is our core utility customers at MGE. MGE continues to face the challenge of providing its customers with reliable power at competitive prices. MGE plans to meet this challenge by building more efficient generation projects and continuing its efforts to control its operational costs. We believe it is critical to continue maintaining a strong credit standing and financial strength in MGE as well as the parent company in order to accomplish these goals.
Results of Operations
Year Ended December 31, 2007, Versus the Year Ended December 31, 2006
Executive Summary - MGE Energy and MGE
In 2007, MGE Energy's earnings were $48.8 million or $2.27 per share compared to $42.4 million or $2.06 per share in the prior year. MGE's earnings for the twelve months ended December 31, 2007, were $37.1 million compared to $32.6 million for the same period in the prior year.
During the twelve month period ended December 31, 2007, our utility operations experienced an increase in electric revenues of $15.6 million. This increase is primarily attributable to an increase in sales volumes, the effect of a fuel surcharge and an increase in sales for resale. Additionally, the electric rates for the twelve months ended December 31, 2007, are higher than those for the same period in the prior year, when the fuel credit and refund in effect during the twelve months ended December 31, 2006, are considered. As a result of lower actual fuel costs during the twelve months ended December 31, 2006, than those costs provided in the applicable rate order, the PSCW issued an interim order implementing a $0.00454 per kWh fuel credit. Additionally, the PSCW stated that MGE's electric rates set in the final order were subject to refund, together with interest, pending a full review of MGE's 2006 actual electric fuel costs. As a result of these actions, MGE recognized an obligation to make refunds to its customers by recording a $19.1 million gross reduction to other electric revenues during the twelve months ended December 31, 2006.
For the twelve months ended December 31, 2007, fuel used for electric generation increased $7.5 million or 15.2% compared to the twelve months ended December 31, 2006. This increase is attributable to an increase in the volume of internal generation and an increase in the per-unit cost of fuel. During this same period, purchased power expense increased by $0.4 million or 0.6%. This increase is attributable to an increase in the per-unit-cost offset by a decrease in volume of power purchased.
On April 26, 2007, the PSCW approved a $0.00339 per kWh fuel surcharge on MGE's electric rates to cover increased fuel and purchased power expenses. The fuel surcharge was applied to electric rates as of the date of the PSCW order. On August 31, 2007, MGE received a final decision from the PSCW which reduced the fuel surcharge to $0.00242 per kWh. This fuel surcharge went into place on the date of the order and remained in place until December 31, 2007. These surcharges resulted in a $5.6 million increase in electric revenue for the twelve months ended December 31, 2007. Pursuant to the provisions of the April 26, 2007, surcharge order, MGE's electric revenues resulting from this surcharge were subject to refund and interest at 11%. During the twelve months ended December 31, 2007, MGE recorded a $1.3 million adjustment to other electric revenue to account for the refund provision. This refund amount was applied to customers' accounts on October 6, 2007.
During the twelve months ended December 31, 2007, gas revenues increased $12.7 million. This increase is a result of increases in sales volumes, partially offset by a decline in the costs of gas and a decrease in other gas revenues. During this period, natural gas purchased increased $11.5 million as a result of an increase in volumes and an increase in the per therm cost.
The following discussion is based on the business segments as discussed in Footnote 24.
Electric Utility Operations
Electric sales and revenues
The following table compares MGE's electric retail revenues and electric kWh sales by customer class during the years ended December 31, 2007 and 2006:
Electric operating revenues were up 4.9% in 2007 due to the following:
(In millions)
Rate changes
$3.5
Volume
9.1
Sales for resale
1.5
Other revenues
1.5
Total
$15.6
•
Rates. Rates charged to retail customers for the twelve months ended December 31, 2007, were 1.1% or $3.5 million higher than those charged during the same period in the prior year.
On May 25, 2006, the PSCW approved a fuel credit to reduce 2006 electric rates by $0.00454 per kWh and stated that electric rates set in the final 2006 order are subject to refund. As a result of these provisions, customers' bills were credited $16.8 million during the twelve months ended December 31, 2006. Additionally, on April 24, 2007, when the PSCW completed their audit of 2006 electric fuel costs and issued a final order, $2.4 million (related to 2006 fuel costs including interest) was applied to customers' accounts.
On December 22, 2006, the PSCW approved a limited scope rate case reopener related to MGE's current electric rates. This order was expected to result in a net 0.15% decrease, on average, in retail electric rates for 2007 when compared to those in place for the year ended December 31, 2006 (assuming the 2006 fuel credit was in place for the entire year). Electric rates were subsequently increased from those presented in this order as a result of a $0.00339 per kWh fuel surcharge approved by the PSCW and in effect from April 26, 2007, to August 31, 2007, and a $0.00242 per kWh fuel surcharge approved by the PSCW and in effect from August 31, 2007, to December 31, 2007. These surcharges resulted in a $5.6 million increase to electric rates charged to customers during the twelve months ended December 31, 2007.
•
Volume. During 2007, there was a 2.8% increase in total retail sales volumes. This increase represents increased usage by residential and commercial.
•
Sales for resale. During 2007, sales for resale increased $1.5 million. The increase in sales for resale for the year ended December 31, 2007, when compared to the same period in the prior year is largely attributable to a change in the relationship between the cost of purchased power and the cost of internal generation.
•
Other Revenues. Other electric revenues increased $1.5 million for the twelve months ended December 31, 2007, compared to the same period in the prior year. To account for the effects of the fuel credit and refund described above under "Rates", during the twelve months ended December 31, 2006, MGE recognized a net $2.3 million reduction to other electric revenues.
In April 2007, the 2006 fuel credit of $2.3 million was provided to customers. As a result, MGE increased other revenues by the same amount to offset this credit reflected in "Rates" above.
During the twelve months ended December 31, 2007 and 2006, MGE recovered in electric rates carrying costs and other fees related to WCCF and Elm Road. MGE recorded a $8.2 million and $5.2 million reduction, respectively, to other electric revenues to eliminate the recognition of revenue related to these costs in the electric segment as revenue related to these costs is recorded by MGE Power Elm Road and MGE Power West Campus (see discussion of these revenues in the "nonregulated operations revenues" section).
For the twelve months ended December 31, 2007, MGE also experienced a $0.1 million decrease in other miscellaneous electric revenues.
Electric fuel and purchased power
In 2007, fuel used for electric generation increased $7.5 million, or 15.2%, compared to 2006. The per-unit cost of internal generation increased 4.5% for the year ended December 31, 2007, when compared to the same period in the prior year, reflecting the increased cost of natural gas.
The volume of internal generation also increased during this period reflecting a shift between internal generation and purchased power.
For the year ended December 31, 2007, purchased power expense increased by $0.4 million, or 0.6%. This increase reflects a $6.2 million or 8.1% increase in the per-unit-cost, offset by a $5.8 million or 7.0% decrease in volume of power purchased.
MGE has recorded transactions on the PJM and Midwest ISO markets in which we are buying and selling power within the same hour to meet our electric energy delivery requirements on a net basis.
Electric operating expenses
Electric operating expense increased $3.2 million in 2007. The following changes contributed to the net change in electric operating expenses for 2007:
(In millions)
Increased production costs
$2.0
Decreased transmission costs
(0.1)
Increased distribution costs
0.3
Increased customer services, promotions, and account costs
0.2
Increased other general and administrative expenses
0.8
Total
$3.2
Included in the decrease in transmission costs is a $0.9 million cash benefit received for SECA revenues related to prior years. SECA revenues are through and out rates previously charged to MGE by PJM for transactions between RTOs which were subsequently eliminated by FERC.
Electric maintenance expense
In 2007, electric maintenance expense increased $0.8 million, or 5.7%, due to a increase in the maintenance of distribution assets ($0.7 million) and the maintenance of general and administrative facilities ($0.1 million).
Electric depreciation
Electric depreciation expense increased $0.7 million in 2007. This increase is attributable to additions to electric assets.
Gas Utility Operations
Gas deliveries and revenues
The following table compares MGE's gas retail revenues and gas delivered by customer class during each of the years ended December 31, 2007 and 2006:
Gas revenues increased 6.9% in 2007 due to the following:
(In millions)
Gas costs/rates
$(0.6)
Gas deliveries
15.0
Other revenues
(1.7)
Total
$12.7
•
Gas costs/rates. Gas costs decreased for the year ended December 31, 2007, from those costs experienced for the year ended December 31, 2006. MGE's natural gas rates are subject to a purchased gas adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. As a result of a decrease in gas prices, MGE's average rate per therm for retail customers in 2007 decreased 0.3%.
•
Retail gas deliveries. In 2007, retail gas deliveries increased 8.4%. This increase is primarily attributable to an increase in heating degree days. Heating degree days for the year ended December 31, 2007, were 6,935 compared to 6,520 for the same period in the prior year.
•
Other gas revenues. In 2007, there was a $1.7 million decrease in other gas revenues. Under MGE's GCIM, if actual gas commodity costs are above or below a benchmark set by the PSCW, then MGE's gas sales service customers and shareholders share equally in any increased costs or savings. The PSCW allows MGE to resell gas pipeline capacity reserved to meet peak demands but not needed every day to serve customers. Revenues from capacity release that exceed or fall short of PSCW-targeted levels are shared equally. In 2007 and 2006, MGE shareholders received the benefit of $0.9 million and $2.5 million from capacity release revenues and commodity savings under the GCIM, respectively.
Natural gas purchased
In 2007, natural gas purchased increased $11.5 million, or 8.9%. Due primarily to higher retail sales volumes, the volume of natural gas purchased increased $10.8 million for the year ended December 31, 2007, when compared to the prior year. Additionally, a decrease in the natural gas purchase price coupled with an increase in the PGA provision provides for an overall increase in the cost per therm of 0.5% in 2007, which resulted in a $0.7 million overall increase in expense when compared to the prior year.
Gas operating expenses
Gas operating expense increased $0.4 million, or 1.2%, in 2007. The following changes contributed to the net change in gas operating expense for the year:
(In millions)
Decreased production costs
$(0.1)
Increased distribution costs
0.4
Increased customer services, promotions, account costs
0.3
Decreased other administrative and general expenses
(0.2)
Total
$0.4
Gas maintenance expenses
Gas maintenance expense increased $0.4 million , or 17.9% in 2007. This increase primarily relates to maintenance work performed on distribution assets.
Gas depreciation
Gas depreciation expense increased $0.2 million in 2007 as a result of additional gas plant assets.
Other Income (Expense)
Other income for the year ended December 31, 2007, for the electric and gas segments was $0.1 million, compared to other expense of $1.0 million for the same period in the prior year. During 2007, the gas and electric segments recognized $1.9 million in AFUDC-equity, $0.2 million in equity earnings from miscellaneous investments, and a $0.8 million gain on the sale of investments. This income was offset partially by $0.3 million in premium expense for a HDD collar, $2.1 million in charitable contributions and $0.4 million in net miscellaneous expenses.
During 2006, the gas and electric segments recognized a total of $2.2 million in charitable contributions. This expense was partially offset by $0.6 million in AFUDC-equity and $0.6 million in other miscellaneous income. The other miscellaneous income includes a $0.6 million gain on our heating degree day financial instrument.
Interest Expense
For the year-ended December 31, 2007, total interest expense for the electric and gas segments decreased $0.4 million when compared to the same period in the prior year. For the year ended December 31, 2007, there was a $1.0 million decrease in interest expense on short-term debt, a $0.6 million increase in AFUDC-debt (which is a reduction to interest expense), and a $0.5 million increase in interest income. These decreases in interest expense were offset by a $1.7 million increase in interest expense on long-term debt. This increase relates to interest incurred on the 5.25% medium-term notes, issued on December 29, 2006.
Nonregulated Energy Operations
Nonregulated Energy operating revenues
Operating revenues from nonregulated energy operations were $20.0 million and $18.4 million for the years ended December 31, 2007 and 2006. These amounts include $14.9 million and $15.0 million, respectively, in interdepartmental revenues. The interdepartmental revenues relate to the leasing arrangement between MGE and MGE Power West Campus which commenced on April 26, 2005. In accordance with the provisions of this leasing arrangement, the Nonregulated Energy Operations, via MGE Power West Campus, recorded $14.9 million and $15.0 million in lease revenue for the years ended December 31, 2007 and 2006, respectively. Upon consolidation, this interdepartmental amount is eliminated.
Also included in operating revenues is the recognition of revenues related to carrying costs for MGE Power West Campus and MGE Power Elm Road. MGE received approval from the PSCW to collect approximately $12.1 million in carrying costs incurred by MGE Power West Campus during construction of the WCCF facility. MGE is collecting these costs in rates over a period of ten years. For each of the years ended December 31, 2007 and 2006, MGE Power West Campus recognized $1.1 million related to carrying costs on WCCF, management, demolition, and removal fees.
MGE also received approval from the PSCW to collect carrying costs expected to be incurred by MGE Power Elm Road during construction of the Elm Road project. Current forecasts estimate the total carrying costs to be incurred to be $53.6 million. A portion of this amount is being recognized over the period allowed for recovery in rates ($32.5 million) and a portion is being deferred and will be recognized over the period in which the facility is depreciated ($21.1 million). For the years ended December 31, 2007 and 2006, MGE Power Elm Road recognized $4.1 million and $2.3 million related to carrying costs on the Elm Road project.
Nonregulated energy operations and maintenance expense
For the years ended December 31, 2007 and 2006, other operations and maintenance expense remained consistent. These expenses primarily relate to administrative and general expenses at MGE Power West Campus and MGE Power Elm Road.
Nonregulated energy depreciation expense
Depreciation expense began when the WCCF commenced operations on April 26, 2005. Depreciation expense for the year ended December 31, 2007, remained consistent when compared to the prior year.
Nonregulated energy interest expense, net
For the twelve months ended December 31, 2007, interest expense, net at the nonregulated energy operations segment was $2.5 million compared to $2.7 million for the same period in the prior year.
Interest expense for both 2007 and 2006 related to long-term borrowings at MGE Power West Campus was $2.8 million. In 2007, this interest expense is offset by a $0.1 million of miscellaneous interest income.
Also included in the nonregulated interest expense is interdepartmental interest expense at MGE Power Elm Road. During the twelve months ended December 31, 2007 and 2006, MGE Power Elm Road was charged $3.9 million and $1.9 million, respectively, in interest expense by MGE Energy on funds borrowed for the Elm Road Project. Under the provision of SFAS 34, MGE Power Elm Road capitalized all interest expense on the Elm Road Project during 2007 and 2006. For the years ended December 31, 2007 and 2006, MGE Power Elm Road recorded $0.2 million and $0.1 million in interest income on the cash advanced to Elm Road Services, LLC for construction of transmission equipment and work done by ATC related to Elm Road.
Transmission Investment Operations
Transmission investment other income (loss)
For the year ended December 31, 2007, other income at the transmission investment segment was $6.0 million, compared to $5.3 million for the same period in the prior year. The transmission investment segment holds our interest in ATC, and its income reflects our equity earnings in ATC.
All Other Operations
All other revenues
During the twelve months ended December 31, 2007 and 2006, the All Other segment did not record any revenues.
All other operations and maintenance expense
All other operations and maintenance expense for the year ended December 31, 2007, decreased $0.1 million when compared to the same period in the prior year. This decrease is related to a decrease in general and administrative expense at corporate.
All other interest income (expense)
All other interest income for the year ended December 31, 2007, was $2.3 million compared to $0.8 million for the year ended December 31, 2006. Interest income for the twelve months ended December 31, 2007 and 2006, includes $3.9 million and $1.9 million in interdepartmental income from MGE Power Elm Road. Additionally, there was $0.2 million in miscellaneous interest income for the year ended December 31, 2007. In 2007 and 2006, this interest income is offset in part by $1.8 million and $1.1 million, respectively, in interest expense on short-term debts.
Consolidated Other General Taxes
MGE Energy and MGE's other general taxes increased $0.4 million or 2.4% in 2007. This increase is primarily attributable to an increase in MGE's license fee tax and an increase in MGE's payroll taxes. The annual license fee tax expense is based on adjusted operating revenues of the prior year. These increases are slightly offset by a tax refund received for overpayment of license fees in prior years.
Consolidated Income Taxes
MGE Energy's effective income tax rate is 36.3% for the twelve months ended December 31, 2007, compared to 37.9% for the year ended December 31, 2006. This decrease is primarily attributable to the completion of tax recovery for prior year flow through. The PSCW has allowed rate recovery of deferred taxes on all temporary differences since June 1991 when the FERC Uniform System of Accounts was adopted. Unrecovered deferred taxes in existence at the time of adoption were authorized for rate recovery over 15 years. Recovery of these amounts was completed on December 31, 2006.
Other factors contributing to a decrease in the effective tax rate include the favorable settlement of an income tax examination for which a FIN 48 liability had been recorded, an increase in the domestic manufacturing tax deduction provided by the American Jobs Creation Act of 2004, a federal research tax credit under the new alternative simplified credit method, and an increase in AFUDC-equity primarily related to the Top of Iowa III project.
Minority Interest, Net of Tax
For the year ended December 31, 2007, MGE Energy (through its wholly owned subsidiary MGE Power) earned $7.7 million and $2.6 million for its interest in MGE Power West Campus and MGE Power Elm Road, respectively. Additionally, MGE Energy earned $0.5 million, net of tax for its interest in MGE Transco.
For the year ended December 31, 2006, MGE Energy (through its wholly owned subsidiary MGE Power) earned $7.8 million and $1.4 million for its interest in MGE Power West Campus and MGE Power Elm Road, respectively. Additionally, MGE Energy earned $0.4 million, net of tax for its interest in MGE Transco.
Year Ended December 31, 2006, Versus the Year Ended December 31, 2005
Executive Summary
In 2006, our earnings were $42.4 million or $2.06 per share compared to $32.1 million or $1.57 per share in the prior year. Results for 2005 were adversely impacted by the natural disasters in the Gulf of Mexico. These disasters and the related damage to the energy infrastructure, resulted in abnormally high fuel and purchased power costs that were not entirely recovered from our customers, and ultimately, lower 2005 earnings.
During 2006, utility operations experienced an increase in electric revenues of $7.9 million or 2.5%. This increase is attributable to an increase in rates, offset by decreases in retail volumes, sales for resale, and other electric revenues.
On December 12, 2005, the PSCW authorized MGE to increase 2006 electric revenues by $35.9 million. This increase was implemented to cover forecasted increases in fuel costs and the cost of additional facilities such as MGE Power West Campus and MGE Power Elm Road. During 2006, this authorized increase was partially offset by an interim credit issued by the PSCW.
For the year ended December 31, 2006, actual electric fuel costs were lower than those included in the aforementioned rate order. In 2006, fuel used for generation decreased $15.8 million or 24.3% compared to 2005. Additionally, purchased power expense decreased $4.5 million or 5.5% compared to 2005. As a result of lower actual fuel costs during 2006, the PSCW approved an interim credit and electric rates during this period were subject to refund. In response, MGE recorded a $19.1 decrease to other electric revenues to reflect the refund and credit due to customers. This amount includes $0.4 million in carrying costs incurred. As of December 31, 2006, $16.8 million of this amount had been credited on customers bills. The remaining $2.3 million was refunded to customers in March 2007.
During the year ended December 31, 2006, gas revenues decreased $15.3 million or 7.6%. This decrease is attributable to a 7.3% decrease in the cost per therm of gas and a decrease in gas deliveries.
Operation and maintenance expenses increased $8.5 million during the year ended December 31, 2006. This increase is primarily due to higher general and administrative expenses.
The following discussion is based on the business segments as discussed in Footnote 24.
Electric Utility Operations
Electric sales and revenues
The following table compares MGE's electric retail revenues and electric kWh sales by customer class during the years ended December 31, 2006 and 2005:
Electric operating revenues were up 2.5% in 2006 due to the following:
(In millions)
Rate changes
$28.8
Volume
(2.3)
Sales for resale
(11.9)
Other revenues
(6.7)
Total
$7.9
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Rates. On December 12, 2005, the PSCW authorized MGE to increase 2006 electric revenues by $35.9 million to cover rising fuel and purchased power costs and the cost of additional facilities needed to meet the rising electric needs of MGE's customers.
On March 9, 2006, the PSCW approved an interim fuel credit to reduce electric rates by $0.00069 per kWh as a result of lower January fuel costs than those in the aforementioned rate order. This credit was applied to rates as of March 9, 2006. Per the terms of the order issued on March 9, 2006, MGE's rates were also subject to refund. On May 25, 2006, the PSCW approved a stipulation filed by MGE. Under this stipulation, the interim credit was increased by $0.00454 per kWh. The aforementioned orders resulted in a $16.8 million reduction to customer bills for the year ended December 31, 2006.
On December 21, 2004, the PSCW authorized MGE to increase 2005 electric revenues by $27.4 million. Due to the natural disasters in the Gulf of Mexico and the abnormally high fuel costs that resulted, on November 11, 2005, the PSCW approved an interim fuel surcharge. During 2005, MGE recorded $1.7 million in additional electric revenues under this interim order.
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Sales for resale. During 2006, sales for resale decreased $11.9 million. Sales for resale include transactions conducted on the PJM and Midwest ISO markets reflecting our involvement in the PJM and Midwest ISO markets since their establishment on May 1, 2004, and April 1, 2005, respectively. MGE has recorded transactions on the PJM and Midwest ISO markets in which we are buying and selling power within the same hour to meet our electric energy delivery requirements on a net basis. This treatment resulted in a $154.4 million and $122.2 million reduction to sales for resale and purchased power expense for the years ended December 31, 2006 and 2005, respectively. The decrease in sales for resale for the year ended December 31, 2006, when compared to the same period in the prior year is largely attributable to a change in the relationship between the cost of purchased power and the cost of internal generation. Namely, during 2006 the cost to purchase power in certain periods was less than the cost to internally generate. Accordingly, MGE was purchasing more power from the market than they were selling power into the market for the year ended December 31, 2006, when compared to the same period in 2005.
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Volume. During 2006, there was a 0.7% decrease in total retail sales volumes. This decrease is primarily attributable to cooler temperatures during the summer months. Cooling degree days for the year ended December 31, 2006, decreased 24.8% from 847 for the year ended December 31, 2005, to 637 for the year ended December 31, 2006.
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Other Revenues. Other electric revenues decreased $6.7 million for the twelve months ended December 31, 2006, compared to the same period in the prior year. During the twelve months ended December 31, 2006, MGE recorded a net $2.3 million reduction to other electric revenues to account for the effects of the interim orders described above under "Rates."
During the year ended December 31, 2006, MGE recovered in electric rates carrying costs on WCCF and Elm Road. MGE recorded a $5.2 million adjustment to other electric revenues to eliminate the recognition of revenue related to these costs in the electric segment as revenue related to these carrying costs is recorded by MGE Power Elm Road and MGE Power West Campus (see discussion of these revenues in the "nonregulated operations revenue" section).
For the year ended December 31, 2005, MGE recorded a $0.8 million adjustment to other electric revenues to eliminate the recognition of revenues related to carrying costs on MGE Power West Campus.
Electric fuel and purchased power
In 2006, fuel used for electric generation decreased $15.8 million, or 24.3%, compared to 2005. The per-unit cost of internal generation decreased 11.3% for the year ended December 31, 2006, when compared to the same period in the prior year, reflecting the decreased cost of natural gas. Recall that fuel costs in 2005 were abnormally high due to the natural disasters that occurred in the Gulf of Mexico and the reduction in natural gas supplies that resulted.
The volume of internal generation also decreased during this period reflecting a shift between internal generation and purchased power. Namely, MGE found that during certain time periods it was more cost effective to satisfy demand through purchased power, rather than internal generation.
Despite a 14.5% increase in the volume of purchased power for the year ended December 31, 2006, purchased power expense decreased by $4.5 million, or 5.5%. This decrease reflects a 17.5% decrease in the per-unit-cost partially offset by the aforementioned increase in volume.
MGE has recorded transactions on the PJM and Midwest ISO markets in which we are buying and selling power within the same hour to meet our electric energy delivery requirements on a net basis. This treatment resulted in a $154.4 million and $122.2 million reduction to purchased power expense for the years ended December 31, 2006 and 2005, respectively.
Electric operating expenses
Electric operating expense increased $7.9 million in 2006. The following changes contributed to the net change in electric operating expenses for 2006:
(In millions)
Increased rent expense (a)
$4.9
Increased other general and administrative expenses
2.7
Increased transmission costs
0.1
Decreased production costs
(0.8)
Increased distribution costs
0.4
Increased customer services, promotions, and account costs
0.6
Total
$7.9
(a)
This increase relates to the commencement of the leasing arrangement between MGE and MGE Power West Campus on April 26, 2005. In accordance with the terms of this leasing arrangement, the electric segment recorded $15.0 million and $10.1 million in rent expense for the years ended December 31, 2006 and 2005, respectively. Upon consolidation, this amount is eliminated.
Electric maintenance expense
In 2006, electric maintenance expense increased $1.1 million, or 8.4%, due to a increase in the maintenance of distribution assets ($1.0 million) and the maintenance of general and administrative facilities ($0.1 million).
Electric depreciation
Electric depreciation expense increased $0.8 million in 2006. This increase is attributable to additions to electric production assets at the Columbia and Blount facilities.
Gas Utility Operations
Gas deliveries and revenues
The following table compares MGE's gas retail revenues and gas delivered by customer class during each of the years ended December 31, 2006 and 2005:
Gas revenues decreased 7.6% in 2006 due to the following:
(In millions)
Gas costs/rates
$ (6.5)
Gas deliveries
(8.5)
Gas transportation
(0.2)
Other effects
(0.1)
Total
$(15.3)
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Gas costs/rates. Gas costs decreased significantly for the year ended December 31, 2006, from those costs experienced for the year ended December 31, 2005. MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. As a result of a decrease in gas prices, MGE's average rate per therm for retail customers in 2006 decreased 3.3%.
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Retail gas deliveries. In 2006, retail gas deliveries decreased 4.5%. This decrease is primarily attributable to warmer temperatures. Heating degree days for the year ended December 31, 2006, were 6,520 compared to 6,840 for the same period in the prior year.
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Transportation and other gas revenues. In 2006, there was a $0.3 million decrease in transportation and other gas revenues. This decrease represents a $0.2 million decrease in transportation revenues and a $0.1 million decrease in revenues earned under the GCIM and other miscellaneous gas revenues. Under MGE's GCIM, if actual gas commodity costs are above or below a benchmark set by the PSCW, then MGE's gas sales service customers and shareholders share equally in any increased costs or savings. The PSCW allows MGE to resell gas pipeline capacity reserved to meet peak demands but not needed every day to serve customers. Revenues from capacity release that exceed or fall short of PSCW-targeted levels are shared equally. In 2006 and 2005, MGE shareholders received the benefit of $2.5 million and $2.7 million from capacity release revenues and commodity savings under the GCIM, respectively.
Natural gas purchased
In 2006, natural gas purchased decreased $16.8 million, or 11.5%. This decrease is primarily due to lower average wellhead prices. Natural gas prices (cost per therm) decreased 7.3% in 2006. As mentioned, in 2005 natural gas prices were atypically high due to the natural disasters that occurred in the Gulf of Mexico. For the year ended December 31, 2006, the amount of natural gas purchased also decreased from those levels experienced for the same period in the prior year. Due primarily to lower retail sales volumes, the volume of natural gas purchased decreased 4.6% for the year ended December 31, 2006.
Gas operating expenses
Gas operating expense increased $4.1 million, or 15.3%, in 2006. The following changes contributed to the net change in gas operating expense for the year:
(In millions)
Increased production costs
$0.4
Increased other administrative and general expenses
2.0
Increased distribution costs
0.2
Increased customer services, promotions, account costs
1.5
Total
$4.1
Gas maintenance expenses
Gas maintenance expense for the year ended December 31, 2006, did not change from the $2.3 million experienced for the same period in the prior year. This expense primarily relates to maintenance work performed on distribution assets.
Gas depreciation
Gas depreciation expense increased $0.4 million in 2006 as a result of additional gas plant assets. For example, during the year ended December 31, 2006, additional mains, services, and meters were placed in service.
Other Income (Expense)
Other expense for the year ended December 31, 2006, for the electric and gas segments was $1.0 million, compared to other income of $0.1 million for the same period in the prior year. During 2006, the gas and electric segments recognized a total of $2.2 million in charitable contributions. This expense was partially offset by $0.6 million in AFUDC-equity and $0.6 million in other miscellaneous income. The other miscellaneous income includes a $0.6 million gain on our heating degree day instrument.
For the year ended December 31, 2005, the gas and electric segments recognized a total of $0.4 million in AFUDC-equity funds and a $0.1 million gain on the sale of assets. This income was offset by $0.2 million in charitable contributions recorded in the electric and gas segments and $0.2 million in miscellaneous expense, net.
Interest Expense
For the year-ended December 31, 2006, total interest expense for the electric and gas segments increased $1.2 million when compared to the same period in the prior year. For the year ended December 31, 2006, there was a $1.3 million increase in interest expense on short-term debt at the electric and gas segments as a result of increased interest rates and higher levels of short-term debt for much of the year. These increases were offset by a $0.1 million increase in AFUDC-debt income at the electric and gas segments.
Nonregulated Energy Operations
Nonregulated Energy operating revenues
Operating revenues from nonregulated energy operations were $18.4 million for the year ended December 31, 2006. This amount includes $15.0 million in interdepartmental revenues. The interdepartmental revenues relate to the leasing arrangement between MGE and MGE Power West Campus which commenced on April 26, 2005. In accordance with the provisions of this leasing arrangement, the Nonregulated Energy Operations, via MGE Power West Campus, recorded $15.0 million and $10.1 million in lease revenue for the years ended December 31, 2006 and 2005, respectively. Upon consolidation, this interdepartmental amount is eliminated.
Also included in operating revenues is the recognition of revenues related to carrying costs for MGE Power West Campus and MGE Power Elm Road (2006 only). MGE received approval from the PSCW to collect approximately $12.1 million in carrying costs incurred by MGE Power West Campus during construction of the WCCF facility. MGE is collecting these costs in rates over a period of ten years. Of these costs, $4.1 million relates to the capitalized interest and the debt portion of the facility. These costs are recognized over the period in which the facility is being depreciated (40 years). The remaining amount of $8.0 million represents the equity portion and is recognized over the ten-year period for recovery in rates. For the years ended December 31, 2006 and 2005, MGE Power West Campus recognized $1.1 million and $0.6 million, respectively, related to carrying costs on WCCF, management, demolition, and removal fees.
MGE also received approval from the PSCW to collect carrying costs expected to be incurred by MGE Power Elm Road during construction of the Elm Road project. Current forecasts estimate the total carrying costs to be incurred to be $54.3 million. A portion of this amount is being recognized over the period allowed for recovery in rates ($32.6 million) and a portion is being deferred and will be recognized over the period in which the facility is depreciated ($21.7 million). For the year ended December 31, 2006, MGE Power Elm Road recognized $2.3 million related to carrying costs on the Elm Road project.
Nonregulated energy operations and maintenance expense
For the years ended December 31, 2006 and 2005, other operations and maintenance expense remained consistent. These expenses primarily relate to administrative and general expenses at MGE Power West Campus and MGE Power Elm Road.
Nonregulated energy depreciation expense
Depreciation expense began when the WCCF commenced operations on April 26, 2005. Depreciation expense for the year ended December 31, 2006, was $2.7 million compared to $1.9 million for the year ended December 31, 2005, reflecting a partial year of depreciation in 2005.
Nonregulated energy interest expense, net
For the twelve months ended December 31, 2006, interest expense, net at the nonregulated energy operations segment increased $1.1 million compared to the same period in the prior year. Interest expense at the nonregulated energy segment for the year ended December 31, 2006, represents interest expense on the long-term borrowings held by MGE Power West Campus. On September 30, 2003, MGE Power West Campus issued $30.0 million of 5.68% senior secured notes maturing September 25, 2033 and on October 27, 2005, issued $20.0 million of 5.19% senior secured notes also due September 25, 2033. Interest expense for the twelve months ended December 31, 2006 and 2005, related to these borrowings was $2.8 million and $1.9 million, respectively.
Also included in the nonregulated interest expense is interdepartmental interest expense at MGE Power Elm Road and MGE Power West Campus. During the twelve months ended December 31, 2006 and 2005, MGE Power Elm Road was charged $1.9 million and $0.2 million, respectively, in interest expense by MGE Energy on funds borrowed for the Elm Road Project. This expense is eliminated upon consolidation. During the year ended December 31, 2005, MGE Power West Campus recorded $0.4 million in interdepartmental interest expense. This expense is also eliminated upon consolidation.
The interest expense at MGE Power Elm Road is offset by $1.9 million and $0.2 million in capitalized interest during the twelve months ended December 31, 2006 and 2005, respectively. Under the provision of SFAS 34, MGE Power Elm Road is capitalizing interest on the Elm Road Project. During construction of the WCCF, MGE Power West Campus also recorded capitalized interest in accordance with the provisions of SFAS 34. During the twelve months ended December 31, 2005, $0.7 million in capitalized interest was recognized as an offset to interest expense. On April 26, 2005, when the electric generation facilities of WCCF began generating electricity, MGE Power West Campus discontinued the capitalization of interest, as the project was deemed to be substantially complete.
For the year ended December 31, 2006, MGE Power Elm Road recorded $0.1 million in interest income on the cash advanced to Elm Road Services, LLC for construction of transmission equipment and work done by ATC related to Elm Road.
Transmission Investment Operations
Transmission investment other income (loss)
For the year ended December 31, 2006, other income at the transmission investment segment was $5.3 million, compared to $4.9 million for the same period in the prior year. The transmission investment segment holds our interest in ATC, and its income reflects our equity earnings in ATC.
All Other Operations
All other revenues
During the twelve months ended December 31, 2006, the All Other segment did not record any revenues. However, MGE Construct received service fees of $1.3 million from the State in 2005. The service fees earned relate to MGE Construct's role as EPC contractor for WCCF. This amount is classified as nonregulated revenue within MGE Energy's financial statements. The total fee of $5.0 million had been recognized at December 31, 2005. This amount was recognized as services were rendered and was collected over a 22-month period.
All other operations and maintenance expense
All other operations and maintenance expense for the year ended December 31, 2006, increased $0.2 million when compared to the same period in the prior year. This increase is related to a increase in general and administrative expense at corporate. For the year ended December 31, 2005, the all other segment recorded a $0.2 million gain as a result of the settlement of disputed legal fees.
All other interest income (expense)
All other interest income for the year ended December 31, 2006, was $0.8 million compared to $0.1 million for the year ended December 31, 2005. Interest income for the twelve months ended December 31, 2006 and 2005, includes $1.9 million and $0.2 million in interdepartmental income from MGE Power Elm Road. Additionally, for the year ended December 31, 2005, this balance includes $0.4 million in interdepartmental income from MGE Power West Campus. This interest income is eliminated upon consolidation. This interest income for the year ended December 31, 2006, is offset in part by $1.1 million in interest expense on short-term debt. Interest expense on these borrowings was $0.5 million for the same period in the prior year.
Consolidated Other General Taxes
MGE Energy and MGE's other general taxes increased 16.1% in 2006 primarily because MGE's license fee tax increased. The annual license fee tax expense is based on adjusted operating revenues of the prior year. Tax rates have not increased.
Consolidated Income Taxes
MGE Energy's effective income tax rate is 37.9% for 2006 compared to 38.2% in 2005. The lower effective tax rate is chiefly due to the recognition, in 2006, of tax benefits from the domestic manufacturing deduction, as provided by the American Jobs Creation Act of 2004, over time periods related to PSCW rate action.
Minority Interest, Net of Tax
For the year ended December 31, 2006, MGE Energy (through its wholly owned subsidiary MGE Power) earned $7.8 million and $1.4 million for its interest in MGE Power West Campus and MGE Power Elm Road, respectively. Additionally, MGE Energy earned $0.4 million, net of tax for its interest in MGE Transco.
For the year ended December 31, 2005, MGE Energy earned $5.4 million, net of tax , for its interest in MGE Power West Campus and less than $0.1 million for its interest in MGE Transco and MGE Power Elm Road. These amounts are recorded as minority interest expense, net of tax, on MGE's Consolidated Statement of Income.
Liquidity and Capital Resources
Cash Flows
The following summarizes cash flows for MGE Energy and MGE during the twelve months ended 2007, 2006, and 2005:
Cash Provided by Operating Activities
MGE Energy
MGE Energy's consolidated net cash provided by operating activities is derived mainly from the electric and gas operations of its principal subsidiary, MGE.
2007 vs.
Cash provided by operating activities decreased $24.5 million for the twelve months ended December 31, 2007, when compared to the same period in the prior year. This decrease is primarily attributable to increases in accounts receivable and unbilled revenues. MGE Energy's working capital accounts contributed to $8.5 million in cash used for operating activities for the twelve months ended December 31, 2007, compared to $8.7 million in cash provided by operating activities during the same period in the prior year.
During the twelve months ended December 31, 2007 and 2006, MGE Energy made $6.3 million and $5.8 million, respectively, in discretionary contributions to the pension and other postretirement benefit plans.
MGE Energy recorded $1.9 million in AFUDC-equity funds for the twelve months ended December 31, 2007, compared to $0.6 million for the same period in the prior year. This increase is primarily attributable to the construction of the Top of Iowa III wind generation project. Construction of this project is expected to be completed in the first quarter of 2008.
During the twelve months ended December 31, 2007, MGE Energy recorded a $3.1 million provision for doubtful accounts. This represents a $0.2 million decrease from the amount recorded during the same period in the prior year. The provision during 2006 was higher due to the atypically high fuel costs experienced in the latter portion of 2005 and the effects these costs had on the composition of the aging.
During the twelve months ended December 31, 2007, MGE Energy also recorded a $0.8 million gain on the sale of equity investments.
During the twelve months ended December 31, 2007, more working capital was used to support higher receivables and unbilled revenues, partially offset by an increase in payables and a decrease in inventories. In addition, there was a decrease in short term liabilities reflecting, in part, the payment of a $2.3 million refund to customers on April 24, 2007. That refund is the result of the interim fuel credit and subject to refund provision instituted by the PSCW in 2006. This payment had no impact on net income for the twelve months ended December 31, 2007. Included in the December 31, 2006, operating cash flows is the collection of the $2.4 million of the retainage receivable from the State under the EPC agreement related to the construction of WCCF. Cash outflows related to other noncurrent items, net were $1.8 million for the twelve months ended December 31, 2007, compared to cash inflows of $4.4 million in the twelve months ended December 31, 2006.
During the twelve months ended December 31, 2007, MGE Energy received $2.5 million in cash proceeds as a result of the Congestion Cost and Line Loss Allocation Services Agreement that they are a party to.
For the twelve months ended December 31, 2007, MGE Energy recorded $6.0 million in equity earnings from ATC and received $4.4 million in cash dividends from ATC. For the same period in the prior year, MGE Energy recorded $5.3 million in equity earnings from ATC and received $4.0 million in cash dividends from ATC.
2006 vs.
Cash provided by operating activities increased $47.7 million for the year ended December 31, 2006, when compared to the same period in the prior year. This increase is primarily attributable to an increase in net income and decreases in accounts receivable, inventories, and unbilled revenues. Namely, MGE Energy's net income increased $10.3 million for the year ended December 31, 2006, when compared to the same period in the prior year. MGE Energy's working capital accounts contributed to $8.7 million in cash provided by operating activities, compared to a use of cash of $23.8 million for the same period in the prior year.
As a result of the natural disasters that occurred in the Gulf of Mexico, fuel costs were atypically high in the latter portion of 2005. The high fuel costs had several impacts on the financial statements of MGE Energy for the year ended December 31, 2005. For instance, high fuel costs ultimately resulted in an increase to both electric and gas rates. The increase in rates for both the electric and gas segment resulted in higher billed and unbilled receivables at December 31, 2005. Additionally, the increase in fuel costs above those forecasted in MGE's rate order, was a source of the lower net income that was experienced for the year ended December 31, 2005, and caused the cost of inventories, such as gas in storage to be atypically high. The offsetting impact on cash flows of these disasters in 2005 is a reduction in accounts payable. Because of the high costs of gas, accounts payable levels at December 31, 2005, were higher than normal levels.
During 2006 and 2005, MGE Construct collected $2.4 million and $2.5 million of the retainage receivable from the State under the EPC agreement related to the construction of the WCCF, respectively. Additionally, during the year ended December 31, 2006, MGE billed $2.3 million (net of $16.8 million returned to customers between March 9, 2006, and December 31, 2006) in electric rates which, pursuant to an interim order issued by the PSCW, was required to be refunded to customers. This credit was recorded as a reduction to other electric revenues in the consolidated income statement of MGE Energy for the twelve months ended December 31, 2006, and is shown as a noncash adjustment to net income on the consolidated statement of cash flows of MGE Energy.
Other noncurrent items, net contributed $4.4 million to cash flows from operations for the year ended December 31, 2006, compared to $0.7 million in cash used for operations for the year ended December 31, 2005. Additionally, during the years ended December 31, 2006 and 2005, MGE Energy made $5.8 million and $5.5 million in voluntary cash contributions to the pension and other postretirement plans, respectively.
During the year ended December 31, 2006, MGE recorded a $3.2 million provision for doubtful accounts. This represents a $1.2 million increase from the amount recorded during the same period in the prior year. In 2006 MGE experienced a deterioration in the composition of the aging of its accounts receivable largely attributable to the increase in gas and electric rates that was experienced in the latter portion of 2005. MGE recorded $10.2 million in employee benefit expenses compared to $9.7 million for the prior year. See Footnote 13 for further discussion of MGE Energy's Pension and Other Postretirement Benefits.
For the year ended December 31, 2006, MGE Energy recorded $5.3 million in equity earnings from ATC and $4.0 million in cash dividends received from ATC. For the same period in the prior year, MGE Energy recorded $4.9 million in equity earnings from ATC and $3.6 million in cash dividends from ATC.
There was a $5.7 million decrease in deferred tax expense between 2006 and 2005. This decrease is largely attributable to the expiration, on December 31, 2005, of federal law permitting bonus tax depreciation. This law allowed taxpayers to claim additional bonus depreciation equal to 50% of the qualifying basis of certain property placed in service prior to January 1, 2006. For the year ended December 31, 2005, bonus tax depreciation resulted in approximately $11.2 million in deferred tax expense, due to the placement in service of WCCF.
MGE
2007 vs.
Cash provided by operating activities decreased $18.7 million for the twelve months ended December 31, 2007, when compared to the same period in the prior year. This decrease is primarily attributable to increases in accounts receivable and unbilled revenues. MGE's working capital accounts contributed $7.6 million in cash used for operating activities for the twelve months ended December 31, 2007, compared to $5.5 million in cash provided by operating activities during the same period in the prior year.
During the twelve months ended December 31, 2007 and 2006, MGE made $6.3 million and $5.8 million, respectively, in discretionary contributions to the pension and other postretirement benefit plans.
MGE recorded $1.9 million in AFUDC-equity funds for the twelve months ended December 31, 2007, compared to $0.6 million for the same period in the prior year. This increase is primarily attributable to the construction of the Top of Iowa III wind generation project.
During the twelve months ended December 31, 2007, MGE recorded a $3.1 million provision for doubtful accounts. This represents a $0.2 million decrease from the amount recorded during the same period in the prior year. The provision during 2006 was higher due to the atypically high fuel costs experienced in the latter portion of 2005 and the effects these costs had on the composition of the aging.
During the twelve months ended December 31, 2007, MGE also recorded a $0.8 million gain on the sale of equity investments.
MGE's working capital accounts contributed to $7.6 million in cash used for operating activities for the twelve months ended December 31, 2007, compared to $5.5 million in cash provided by operating activities during the same period in the prior year. During the twelve months ended December 31, 2007, more working capital was used to support higher receivable and unbilled revenues balances, partially offset by an increase in payables and a decrease in inventories. In addition, there was a decrease in short term liabilities reflecting, in part, the payment of a $2.3 million refund to customers on April 24, 2007. That refund is the result of the interim fuel credit and subject to refund provision instituted by the PSCW in 2006. This payment had no impact on net income for the twelve months ended December 31, 2007. Cash outflows related to other noncurrent items, net were $2.0 million for the twelve months ended December 31, 2007, compared to cash inflows of $4.4 million in the twelve months ended December 31, 2006.
During the twelve months ended December 31, 2007, MGE received $2.5 million in cash proceeds as a result of the Congestion Cost and Line Loss Allocation Services Agreement that they are a party to.
For the twelve months ended December 31, 2007, MGE recorded $6.0 million in equity earnings from ATC and received $4.4 million cash dividends from ATC. For the same period in the prior year, MGE recorded $5.3 million in equity earnings from ATC and received $4.0 million in cash dividends from ATC.
Minority interest, net of tax was $10.7 million for the twelve months ended December 31, 2007, compared to $9.6 million for the same period in the prior year. This increase primarily relates to an increase in carrying cost revenue recorded by MGE Power Elm Road.
2006 vs.
Cash provided by operating activities increased $64.4 million for the year ended December 31, 2006, when compared to the same period in the prior year. This increase is primarily attributable to an increase in net income and decreases in accounts receivable, inventories, and unbilled revenues. Namely, MGE's net income increased $6.6 million for the year ended December 31, 2006, when compared to the same period in the prior year. MGE's working capital accounts contributed to $5.5 million in cash provided by operating activities, compared to a use of cash of $43.8 million for the same period in the prior year.
As a result of the natural disasters that occurred in the Gulf of Mexico, fuel costs were atypically high in the latter portion of 2005. The high fuel costs had several impacts on the financial statements of MGE for the year ended December 31, 2005. For instance, high fuel costs ultimately resulted in an increase to both electric and gas rates. The increase in rates for both the electric and gas segment resulted in higher billed and unbilled receivables at December 31, 2005. Additionally, the increase in fuel costs above those forecasted in MGE's rate order, was a source of the lower net income that was experienced for the year ended December 31, 2005, and caused the cost of inventories, such as gas in storage to be atypically high. The offsetting impact on cash flows of these disasters in 2005 is a reduction in accounts payable. Because of the high costs of gas, accounts payable levels at December 31, 2005, were higher than normal levels.
Other noncurrent items, net resulted in $4.4 million in cash provided by operating activities for the year ended December 31, 2006, compared to $0.6 million in cash used by operating activities for the same period in the prior year. Additionally, during the years ended December 31, 2006 and 2005, MGE made $5.8 million and $5.5 million in voluntary cash contributions to the pension and other postretirement plans.
During the year ended December 31, 2006, MGE billed $2.3 million (net of $16.8 million returned to customers between March 9, 2006, and December 31, 2006) in electric rates which, pursuant to an interim order issued by the PSCW, is required to be refunded to customers. This credit was recorded as a reduction to other electric revenues in the consolidated income statement of MGE for the twelve months ended December 31, 2006, and is shown as a noncash adjustment to net income on the consolidated statement of cash flows of MGE.
During the year ended December 31, 2006, MGE recorded a $3.2 million provision for doubtful accounts. This represents a $1.2 million increase from the amount recorded during the same period in the prior year. In 2006, MGE experienced a deterioration in the composition of the aging of its accounts receivable largely attributable to the increase in gas and electric rates that was experienced in the latter portion of 2005. MGE recorded $10.2 million in employee benefit expenses compared to $9.7 million for the prior year. See Footnote 13 for further discussion of MGE's Pension and Other Postretirement Benefits.
For the year ended December 31, 2006, MGE recorded $5.3 million in equity earnings from ATC and $4.0 million in cash dividends received from ATC. For the same period in the prior year, MGE recorded $4.9 million in equity earnings from ATC and $3.6 million in cash dividends from ATC.
There was a $6.1 million decrease in deferred tax expense between 2006 and 2005. This decrease is largely attributable to the expiration, on December 31, 2005, of federal law permitting bonus tax depreciation. This law allowed taxpayers to claim additional bonus depreciation equal to 50% of the qualifying basis of certain property placed in service prior to January 1, 2006. For the year ended December 31, 2005, bonus tax depreciation resulted in approximately $11.2 million in deferred tax expense, due to the placement in service of WCCF.
For the year ended December 31, 2006, MGE recorded $9.6 million in minority interest, net of tax, compared to $5.4 million for the same period in the prior year. This amount relates to net income earned by MGE Energy from its interest in MGE Power West Campus, MGE Power Elm Road, and MGE Transco.
Capital Requirements and Investing Activities
MGE Energy
2007 vs.
In 2007, MGE Energy's cash used for investing activities increased $40.4 million. Capital expenditures for the year ended December 31, 2007, were $136.3 million. This amount represents a $43.7 million increase in capital expenditures from those made in the prior year. This increase is related to the construction activity for the Elm Road project ($23.3 million) and the Top of Iowa III wind project ($25.8 million). These increases are partially offset by a $1.6 million decrease in capital expenditures related to WCCF and a $3.8 million decrease in other MGE utility plant additions.
During 2007, MGE Energy made $0.3 million in capital contributions to miscellaneous investments. MGE Energy did not make any cash capital contributions to ATC. However, MGE (through MGE Transco) transferred $1.4 million in certain transmission assets to ATC in 2007. In exchange for this transfer, MGE Transco received $0.7 million in cash proceeds and $0.7 million in an additional investment in ATC. During the year ended December 31, 2006, MGE Energy made $2.0 million in capital contributions to ATC and other equity investments.
In 2007 and 2006 in connection with the Elm Road project, MGE Power Elm Road advanced $0.1 million and $0.8 million in funds to the WEPCO, who in turn provided these funds to ATC, respectively. These funds will be used by ATC for transmission system upgrades related to the Elm Road project. The majority of these funds are expected to be repaid when the first unit at Elm Road achieves commercial operation.
During the year ended December 31, 2007, MGE Energy's cash provided by other cash investing activities was $1.1 million compared to $0.9 million in the prior year. During the twelve months ended December 31, 2007, MGE Energy received $0.9 million in cash proceeds from the sale of equity investments.
2006 vs.
In 2006, MGE Energy's cash used for investing activities increased $18.7 million. Capital expenditures for the year ended December 31, 2006, were $92.6 million. This amount represents a $6.8 million increase from those made in the prior year. This increase is related to the construction activity for the Elm Road project ($5.1 million) and the Top of Iowa III wind project ($10.7 million). These increases are partially offset by a $8.5 million decrease in capital expenditures related to WCCF, reflecting the substantial completion of that project in April 2005 and a $0.5 million decrease in other MGE utility plant additions. During 2006 and 2005, MGE Energy made a $1.9 million and a $1.4 million capital contribution to ATC, respectively. Additionally, during 2006 and 2005, MGE Energy made $0.1 million and $0.3 million in capital contribution to other investments.
In the first quarter 2005, MGE collected $13.0 million in funds previously advanced to ATC in conjunction with the WCCF project. No additional funds were advanced to ATC directly during 2005 or 2006. Although MGE Energy did not advance any funds to ATC directly during the aforementioned periods, funds were indirectly advanced to ATC. Namely, in 2006 and 2005 in connection with the Elm Road project, MGE Power Elm Road advanced $0.8 million and $1.6 million in funds to the WEPCO, who in turn provided these funds to ATC, respectively. These funds will be used by ATC for transmission system upgrades related to the Elm Road project. These funds are expected to be repaid in full when the project is operational.
During the year ended December 31, 2006, MGE Energy's cash provided by other cash investing activities was $0.9 million compared to $0.4 million in the prior year.
MGE
2007 vs.
In 2007, MGE's cash used for investing activities increased $39.8 million. Capital expenditures for the year ended December 31, 2007, were $136.3 million. This amount represents a $43.7 million increase in capital expenditures from those made in the prior year. This increase is related to the construction activity for the Elm Road project ($23.3 million) and the Top of Iowa III wind project ($25.8 million). These increases are partially offset by a $1.6 million decrease in capital expenditures related to WCCF and a $3.8 million decrease in other MGE utility plant additions.
During 2007, MGE made $0.1 million in capital contributions to miscellaneous investments. MGE did not make any cash capital contributions to ATC. However, MGE (through MGE Transco) transferred $1.4 million in certain transmission assets to ATC in 2007. In exchange for this transfer, MGE Transco received $0.7 million in cash proceeds and $0.7 million in an additional investment in ATC. During the year ended December 31, 2006, MGE made $1.9 million in capital contributions to ATC and other equity investments.
In 2007 and 2006 in connection with the Elm Road project, MGE Power Elm Road advanced $0.1 million and $0.8 million in funds to the WEPCO, who in turn provided these funds to ATC, respectively. These funds will be used by ATC for transmission system upgrades related to the Elm Road project. The majority of these funds are expected to be repaid when the first unit at Elm Road achieves commercial operation.
During the year ended December 31, 2007, MGE's cash provided by other cash investing activities was $1.6 million compared to $0.9 million in the prior year. During the twelve months ended December 31, 2007, MGE received $0.9 million in cash proceeds from the sale of equity investments.
2006 vs.
Cash used for investing activities was $94.4 million for 2006, compared to $75.5 million in the prior year. Capital expenditures for the year ended December 31, 2006, were $92.6 million. This amount represents a $6.8 million increase from those made in the prior year. This increase is related to the construction activity for the Elm Road project ($5.1 million) and the Top of Iowa III wind project ($10.7 million). These increases are partially offset by a $0.5 decrease in other MGE utility plant additions and a $8.5 million decrease in capital expenditures related to WCCF, reflecting the substantial completion of that project in April 2005. During 2006 and 2005, MGE Transco made capital contributions to ATC totaling $1.9 million and $1.4 million, respectively. In the first quarter of 2005, MGE collected $13.0 million in funds previously advanced to ATC in conjunction with the WCCF project. No additional funds were advanced to ATC directly during 2005 or 2006. Although MGE did not advance any funds to ATC directly in 2005 or 2006, funds were indirectly advanced to ATC. Namely, in 2006 and 2005 in connection with the Elm Road project, MGE Power Elm Road advanced $0.8 million and $1.6 million, respectively in funds to WEPCO, who in turn provided these funds to ATC. These funds will be used by ATC for transmission system upgrades related to the Elm Road project. These funds are expected to be repaid in full.
During the year ended December 31, 2006, cash provided by other investing activities was $0.9 million compared to $0.4 million for the same period in the prior year.
Capital expenditures
The following table shows MGE Energy's budgeted capital expenditures for 2008 and actual capital expenditures for both 2007 and 2006:
(In thousands)
For the years ended December 31
(Budget)
(Actual)
(Actual)
Electric
:
$36,674
$70,687
$50,604
Gas
14,502
12,091
10,206
Utility plant total
51,176
82,778
60,810
Nonregulated
43,729
53,480
31,765
MGE Energy total
$94,905
$136,258
$92,575
As of December 31, 2007, MGE and MGE Energy had a working capital deficit (current liabilities exceeded current assets). This deficit is in part due to MGE currently funding the majority of its capital commitments for the Top of Iowa III wind project and the Elm Road project with short-term debt and the reclassification of $30.0 million of long term debt which matures in September 2008, from a long-term to a current liability. MGE intends to refinance the $30 million medium-term note with an additional long-term debt facility. MGE intends to fund future capital commitments for these projects with funds generated from normal operations, the issuance of long tem debt, and financing received from MGE Energy. MGE Energy intends to raise the funds for such financing primarily through the issuance of equity securities and short-term debt, as needed.
MGE Energy's and MGE's liquidity is primarily affected by their construction requirements. We allocate common plant for the financial statements and footnotes based on a prescribed formula (60% (electric) and 40% (gas)). MGE Energy's major 2007 capital projects include Elm Road and the Top of Iowa III wind project. During 2007, $53.0 million in capital expenditures were incurred for the construction of Elm Road. Included in this amount is $3.9 million of interest capitalized in accordance with the provisions set forth in SFAS No. 34, Capitalization of Interest Cost. During 2007, MGE expended $36.5 million on capital additions for the construction of the Top of Iowa III wind project and recorded an additional $2.2 million in AFUDC.
As of December 31, 2007, MGE Power Elm Road's remaining capital commitments for the Elm Road project are estimated to be $72.0 million. Included in this amount is $4.5 million, which has been accrued and recorded as construction work in progress at December 31, 2007. Based on current forecasts, capital expenditures for this project are expected to be $48.0 million in 2008, $20.5 million in 2009, and $3.5 million in 2010. These amounts may change as a result of modifications to the project cost estimate or timing differences.
As of December 31, 2007, MGE's remaining capital commitments for the Top of Iowa III wind project are estimated to be $9.0 million and is expected to be expended in 2008. Included in this amount is $8.7 million, which has been accrued and recorded as construction work in progress at December 31, 2007. These amounts may change as a result of modifications to the project cost estimate or timing differences.
MGE Energy used funds received as dividend payments from MGE and MGE Power West Campus as well as short- and long-term external financing to meet its 2007 capital requirements and cash obligations, including dividend payments. External financing included short-term financing under existing lines of credit and proceeds from equity issued under the Distribution Agreement with JP Morgan and the Stock Plan.
Financing Activities
MGE Energy
2007 vs.
Cash provided by MGE Energy's financing activities was $59.0 million for 2007, compared to cash used for financing activities of $6.9 million for 2006. For the year ended December 31, 2007, net short term debt borrowings were $46.5 million compared to net short term debt repayments of $25.5 million for the same period in the prior year. During the year ended December 31, 2007, MGE Energy's major capital expenditures (Top of Iowa III wind project and Elm Road project) were primarily funded with short-term debt, the issuance of common stock and additional long-term debt.
MGE Energy received $32.8 million and $17.1 million in cash proceeds as the result of stock issued during the twelve months ended December 31, 2007 and 2006, respectively. This increase is attributable to stock issued under the Stock Plan and stock issued pursuant under the Distribution Agreement.
Cash dividends paid on common stock during the year ended December 31, 2007, were $30.3 million compared to $28.5 million for the same period in the prior year. This increase is a result of a higher dividend per share ($1.41 vs. $1.39) and an increase in the number of shares outstanding.
During the twelve months ended December 31, 2007, MGE Energy repaid its outstanding obligation for its 7.49% medium-term notes which came due September 20, 2007 ($15.0 million) and issued $25.0 million in 6.247% medium-term notes due September 15, 2037.
2006 vs.
Cash used by MGE Energy's financing activities was $6.9 million for 2006, compared to cash provided by financing activities of $22.2 million for 2005. For the year ended December 31, 2006, net short term debt repayments were $25.5 million compared to net short-term debt borrowings of $29.2 million for the same period in the prior year. As a result of atypically high fuel costs in the latter portion of 2005, short term debt borrowings were above normal levels at December 31, 2005. Namely, to fund the purchase of the related inventory (natural gas, purchased power, etc.), MGE Energy was required to rely more heavily on short-term financing. Conversely, during 2006, although short term debt levels were up for most of the year, there was a large decrease in these levels in December 2006. Namely, in December 2006 MGE used most of the net proceeds from a medium-term note issuance to repay short term debt obligations. See discussion of financing activities under MGE for further discussion of this issuance. Cash dividends paid on common stock during the year ended December 31, 2006, were $28.5 million compared to $28.1 million for the same period in the prior year. This increase is a result of a higher dividend per share ($1.39 vs. $1.37) and an increase in the number of shares outstanding.
The aforementioned increases in uses of cash, were offset by additional proceeds from stock issued. Proceeds under the Stock Plan were $9.7 million for the year ended December 31, 2006. This represents a $7.4 million increase from that received in the prior year. This increase is attributable to a change from using open market purchases during the most of 2005 to satisfy Stock Plan requirements to using newly issued shares starting June 1, 2006. Additionally, on November 9, 2006, MGE Energy entered into a Distribution Agreement with JP Morgan in which MGE Energy may offer and sell up to 1,500,000 shares of its common stock. During 2006, MGE Energy received $7.4 million in net proceeds from shares issued under the Distribution Agreement. These sales are made pursuant to an effective shelf registration statement MGE Energy filed with the SEC in March 2003.
MGE
2007 vs.
During 2007, cash provided by MGE's financing activities was $56.2 million compared to cash used for financing activities of $2.4 million in 2006. During 2007, MGE had net short term borrowings of $31.5 million compared to net short term debt repayments of $36.5 million for the same period in the prior year. During the year ended December 31, 2007, MGE's major capital expenditures (Top of Iowa III wind project and Elm Road project) were primarily funded with short-term debt, equity contributions from MGE Energy and additional long-term debt.
During 2007, equity and affiliate financing received from MGE Energy by MGE Power West Campus and MGE Power Elm Road was $43.4 million compared to $27.3 million for the same period in the prior year. These equity contributions received by the aforementioned subsidiaries from MGE Energy are included in minority interest on the MGE consolidated balance sheet.
For the year ended December 31, 2007, cash dividends made by MGE, MGE Transco, and MGE Power West Campus were $28.7 million compared to $23.1 million for the same period in the prior year.
During the twelve months ended December 31, 2007, MGE repaid its outstanding obligation for its 7.49% medium-term notes which came due September 20, 2007 ($15.0 million) and issued $25.0 million in 6.247% medium-term notes due September 15, 2037.
Dividend payments by MGE to MGE Energy are subject to restrictions arising under a PSCW rate order and, to a lesser degree, MGE's First Mortgage Bonds. The PSCW order limits the amount of dividends that MGE may pay MGE Energy when its common equity ratio, calculated in the manner used in the rate proceeding, is less than 55%. Under those circumstances, MGE may not pay dividends in excess of $26.1 million plus dividends on shares issued in excess of the shares issued in the rate proceeding forecast if the proceeds are invested in MGE. MGE's common equity ratio at December 31, 2007, is estimated to be 53.1% as determined under the calculation used in the rate proceeding. MGE paid cash dividends of $15.6 million to MGE Energy in 2007. The rate proceeding calculation includes as indebtedness imputed amounts for MGE's outstanding purchase power capacity payments and other PSCW adjustments, but does not include the indebtedness associated with MGE Power West Campus, which is consolidated in accordance with FIN 46(R) into MGE's financial statements.
MGE has covenanted with the holders of its First Mortgage Bonds not to declare or pay any dividend or make any other distribution on or purchase any shares of its common stock unless, after giving effect thereto, the aggregate amount of all such dividends and distributions and all amounts applied to such purchases, after December 31, 1945, shall not exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2007, approximately $186.0 million was available for the payment of dividends under this covenant.
2006 vs.
During 2006, cash used for MGE's financing activities was $2.4 million compared to cash provided by financing activities of $42.6 million in 2005. During 2006, MGE had net short-term repayments of $36.5 million compared to net short-term debt borrowings of $25.7 million for the same period in the prior year. As a result of atypically high fuel costs in the latter portion of 2005, short term debt borrowings were above normal levels at December 31, 2005. Namely, to fund the purchase of the related inventory (natural gas, purchased power, etc.), MGE was required to rely more heavily on short-term financing. Conversely, during 2006 although short term debt levels were up for most of the year, there was a large decrease in these levels in December 2006. Namely, in December 2006 MGE used most of the net proceeds from a medium-term note issuance to repay short term debt obligations. See below for further discussion of this issuance.
During 2006, equity and affiliate financing received from MGE Energy by MGE Power West Campus, MGE Transco, and MGE Power Elm Road was $27.3 million compared to $33.9 million for the same period in the prior year. This decrease reflects the substantial completion of the WCCF project in April 2005 and the resulting decrease in capital needs for this project. These equity contributions received by the aforementioned subsidiaries from MGE Energy are included in minority interest on the MGE consolidated balance sheet.
These decreases in cash from financing activities were offset by decreases in the cash dividends and an increase in long term debt issued. Cash proceeds from long term debt issuances were $30 million in 2006 compared to $20 million in 2005. Namely, on December 29, 2006, MGE issued $30 million in 5.25% medium-term notes due January 15, 2017. On October 27, 2005, MGE Energy through its wholly owned subsidiary MGE Power West Campus issued $20.0 million of 5.19% senior secured notes due September 25, 2033.
For the year ended December 31, 2006, cash dividends made by MGE, MGE Transco, and MGE Power West Campus were $23.1 million compared to $36.3 million for the same period in the prior year.
Dividend payments by MGE to MGE Energy are subject to restrictions arising under a PSCW rate order and, to a lesser degree, MGE's First Mortgage Bonds. The PSCW order limits the amount of dividends that MGE may pay MGE Energy when its common equity ratio, calculated in the manner used in the rate proceeding, is less than 55%. Under those circumstances, MGE may not pay dividends in excess of $26.1 million plus dividends on shares issued in excess of the shares issued in the rate proceeding forecast if the proceeds are invested in MGE. MGE's common equity ratio at December 31, 2006, is estimated to be 53.1% as determined under the calculation used in the rate proceeding. The rate proceeding calculation includes as indebtedness imputed amounts for MGE's outstanding purchase power capacity payments and other PSCW adjustments, but does not include the indebtedness associated with MGE Power West Campus, which is consolidated in accordance with FIN 46(R) into MGE's financial statements.
In addition, MGE has covenanted with the holders of its First Mortgage Bonds not to declare or pay any dividend or make any other distribution on or purchase any shares of its common stock unless, after giving effect thereto, the aggregate amount of all such dividends and distributions and all amounts applied to such purchases, after December 31, 1945, shall not exceed the earned surplus (retained earnings) accumulated subsequent to December 31, 1945. As of December 31, 2006, approximately $167.5 million was available for the payment of dividends under this covenant.
During 2006 and 2005, MGE's dividend payments were restricted under a PSCW rate order and its mortgage bond indenture. MGE's common equity ratio at December 31, 2005, was approximately 55.7% as determined under the calculation used in the PSCW rate proceeding. As of December 31, 2005, approximately $148.2 million was available for the payment of dividends under the covenant in MGE's mortgage bond indenture.
MGE Energy's capitalization ratios were as follows:
Below is a table of MGE's current credit ratings. MGE Energy is not rated because it has not issued any debt securities.
Standard & Poor's
Moody's
First Mortgage Bonds
AA-
Aa2
Unsecured debt
AA-
Aa3
Commercial paper
A1+
P1
A security rating is not a recommendation to buy, sell, or hold securities and may be subject to revision or withdrawal at any time by the assigning rating agency. MGE's access to the capital markets, including the commercial paper market, and its financing costs in those markets are dependent on its securities' ratings. None of MGE's borrowing is subject to default or prepayment due to downgrading of securities' ratings, although such a down grading could increase fees and interest charges under MGE's and MGE Energy's credit facilities.
Contractual Obligations and Commercial Commitments for MGE Energy and MGE
MGE Energy's and MGE's contractual obligations as of December 31, 2007, representing cash obligations that are considered to be firm commitments, are as follows:
For additional information about:
(a)
Long-term debt consisting of secured First Mortgage Bonds, unsecured medium-term notes, and Industrial Development Revenue Bonds issued by MGE, and private placement debt issued by MGE Power West Campus. See Footnote 9 of the Notes to Consolidated Financial Statements.
(b)
Short-term debt consisting of commercial paper for MGE and borrowings under MGE Energy lines of credit, see Footnote 10 of the Notes to Consolidated Financial Statements.
(c)
Amount represents interest expense on long-term facilities. See Footnote 9 of the Notes to Consolidated Financial Statements for further discussion of the long term debt outstanding at December 31, 2007.
(d)
Operating leases. See Footnote 18 of the Notes to Consolidated Financial Statements.
(e)
Purchase obligations for MGE consist of the purchase of electricity and natural gas, electric transmission, natural gas storage capacity, natural gas pipeline transportation, and the purchase and transport of coal. See Footnote 18 of the Notes to Consolidated Financial Statements for additional discussion.
(f)
Other obligations are primarily related to investment commitments and charitable donations. Also included is the liability related to FIN 48. For additional information on the unrecognized tax benefit, see Footnote 12 of the Notes to Consolidated Financial Statements.
(g)
Purchase obligations for MGE and MGE Energy related to contracts for equipment and services related to the construction of Elm Road. See Footnotes 18 and 21 of the Notes to Consolidated Financial Statements.
(h)
Short-term debt consisting of commercial paper. See Footnote 10 of the Notes to Consolidated Financial Statements.
(i)
Contractual commitments for certain services and capital at the jointly owned Columbia plant that will be acquired to ensure compliance with certain environmental initiatives.
(j)
Purchase obligations for MGE and MGE Energy related to contracts for equipment and services related to the construction of the Top of Iowa III wind project. See Footnotes 18 and 22 of the Notes to Consolidated Financial Statements.
The above amounts do not include any contributions that may be made for MGE's pension and postretirement plans. Due to uncertainties in the future economic performance of plan assets, discount rates, and other key assumptions, management is unable to estimate these amounts at this time. During 2007 MGE made $6.3 million in employer contributions primarily related to the 2006 plan year. Additionally, in 2008 MGE made a $5.4 million contribution to the pension and other postretirement plans related to the 2007 plan year. These payments were made strictly at MGE's discretion as there were no contributions required related to the 2007 or 2006 plan year.
MGE Energy's and MGE's commercial commitments as of December 31, 2007, representing commitments triggered by future events and including financing arrangements to secure obligations of MGE Energy and MGE, and guarantees by MGE, are as follows:
(a)
Amount includes those facilities discussed in (c) plus an additional line of credit. MGE Energy has available at any time a $80.0 million committed revolving credit agreement, expiring in December 2010. At December 31, 2007, MGE Energy had borrowed $42.5 million under this credit facility. Accordingly, MGE Energy's available credit under this credit facility was $37.5 million at December 31, 2007.
(b)
Amounts include those guarantees described in (d) as well as guarantees held by MGE Energy. Also, MGE Energy has guaranteed debt service payments on a development project.
(c)
Amounts include a five-year, $55.0 million committed revolving credit agreement expiring in December 2010, and an additional $20.0 million line of credit that matures on March 31, 2008. Each credit facility is used to support commercial paper issuances. At December 31, 2007, there were no borrowings under either credit facility. At December 31, 2007, there was $61.0 million of commercial paper outstanding.
(d)
MGE has guaranteed repayment of certain receivables it sold to a financial institution under a chattel paper agreement. See Footnote 18 of the Notes to Consolidated Financial Statements.
Restructuring Activities
On January 19, 2006, MGE announced a plan, subject to certain conditions, that includes discontinuing coal use at the end of 2011 at Blount. The plant will continue to run on natural gas but will be reduced from its current approximate 190 MW capacity to 100 MW when coal burning is discontinued. MGE has determined that certain employee positions will be eliminated in 2011 as a result of this exit plan.
On January 19, 2006, MGE entered into severance agreements providing severance benefits to the nonunion employees affected by the exit plan. Additionally, on September 21, 2006, MGE ratified a labor agreement with the IBEW providing those union employees impacted by the exit plan with involuntary and voluntary severance benefits. The nonunion and union benefits are expected to be paid as follows: $0.1 million in 2008, $0.2 million in 2010, and $1.4 million in 2011.
MGE will recover in rates the costs associated with the discontinuance of coal at Blount. As such, the severance charges for these employees have been deferred and recognized on the consolidated balance sheet of MGE Energy and MGE as a regulatory asset.
Other Factors
Due to the performance of the United States debt and equity markets, the value of assets held in trusts to satisfy the obligations of pension and postretirement benefit plans may vary.
Critical Accounting Policies - MGE Energy and MGE
The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. On an on-going basis, we evaluate our estimates, including those related to unbilled revenues, pension obligations, income taxes, derivatives, and regulatory assets and liabilities. We base our estimates on historical experience and on various assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates under different assumptions or conditions. We believe the following critical accounting policies affect our more significant judgments and estimates used in the preparation of our consolidated financial statements.
Unbilled Revenues
Revenues from the sale of electricity and gas to customers are recorded when electricity/gas is delivered to those customers. The quantity of those sales is measured by customers' meters. Due to the large volume of those meters, it is impractical to read all of them at month end. Meters are read on a systematic basis throughout the month based on established meter-reading schedules. Consequently, at the end of any month, there exists a quantity of electricity and gas that has been delivered to customers but has not been captured by the meter readings. As a result, management must estimate revenue related to electricity and gas delivered to customers between their meter-read dates and the end of the period. These estimates include:
•
The amount of electricity expected to be lost in the process of its transmission and distribution to customers (line loss) and the amount of electricity actually delivered to customers.
•
The amount of gas expected to be lost in the process of its distribution to customers and the amount of gas actually delivered to customers.
•
The mix of sales between customer rate classes, which is based upon historical utilization assumptions.
MGE monitors the reasonableness of the unbilled revenue estimate through the review of ratios such as unbilled electric receivables to billed electric sales. MGE expects that this ratio will be in the range of 40% to 60%.
Allowance for Doubtful Accounts
MGE maintains allowances for doubtful accounts for estimated losses resulting from the inability of its customers to make required payments. It determines the allowance based on historical write-off experience, regional economic data, and review of the accounts receivable aging. The Company reviews its allowance for doubtful accounts monthly. Although management believes that the allowance for doubtful accounts is the Company's best estimate of the amount of probable credit losses, if the financial condition of the Company's customers were to deteriorate, resulting in an impairment of their ability to make payments, additional allowances may be required.
Pension and Other Postretirement Benefit Plans
MGE provides employees with certain retirement (pension) and postretirement (health care and life insurance) benefits. In order to measure the expense and obligations associated with these benefits, management must make a variety of estimates, including discount rates used to value certain liabilities, the expected return on plan assets set aside to fund these costs, the rate of compensation increase, employee turnover rates, retirement rates, health care trends, mortality rates, and other factors. These accounting estimates bear the risk of change due to the uncertainty attached to the estimate as well as the fact that these estimates are difficult to measure. Different estimates used by us could result in recognizing different amounts of expense over different periods of time.
We use third-party specialists to assist us in evaluating our assumptions as well as appropriately measure the costs and obligations associated with these retirement benefits. The discount rate and expected return on plan assets are based primarily on investment yields available and the historical performance of our plan assets. They are critical accounting estimates because they are subject to management's judgment and can materially affect net income.
•
Assumed return on assets. This assumption represents the rate of return on plan assets reflecting the average rate of earnings expected on the funds invested (or to be invested) to provide for the benefits included in the projected benefit obligation. For 2007, MGE used an assumed return on assets of 9.0% for pension and 7.85% for other postretirement benefits. One of the approaches MGE used in determining its assumed return on assets is based on historical returns. As of December 31, 2007, the ten-year historical return was 10.14%. Holding other assumptions constant, for every 1% reduction in the expected rate of return on plan assets, annual pension and other postretirement cost would increase by approximately $1.5 million, before taxes.
•
Discount rate. The discount rate represents the rate at which pension obligations could effectively be settled on a present-value basis. MGE uses high-grade bond yields as a benchmark for determining the appropriate discount rate.
•
Medical trend assumptions. The health care cost trend rate is the assumed rate of increase in per-capita health care charges.
See Footnote 13 for additional discussion of these plans.
Income Tax Provision
MGE Energy's and MGE's income tax provisions, including both current and deferred components, are based on estimates, assumptions, calculations, and interpretation of tax statutes for the current and future years. Determination of current-year federal and state income tax will not be settled for years.
Management regularly makes assessments of tax return outcomes relative to financial statement tax provisions and adjusts the tax provisions in the period when facts become final.
Additionally, in determining our current income tax provision we assess temporary differences resulting from differing treatments of items for tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are recorded in our balance sheets. When we maintain deferred tax assets, we assess the likelihood that these assets will be recovered through adjustments to future taxable income. To the extent we believe recovery is not more likely than not, we establish a valuation allowance. We record an allowance reducing the asset to a value we believe will be recoverable based on our expectation of future taxable income. We believe the accounting estimate related to the valuation allowance is a critical accounting estimate because it is highly susceptible to change from period to period as it requires management to make assumptions about our future income over the lives of the deferred tax assets, and the impact of increasing or decreasing the valuation allowance is potentially material to our results of operations.
In June 2006, the FASB issued FIN 48, Accounting for Uncertainty in Income Taxes, an interpretation of SFAS No. 109, Accounting for Income Taxes. FIN 48 clarifies the accounting for uncertainty in income taxes recognized in an enterprise's financial statements in accordance with SFAS No. 109. The interpretation applies to all tax positions accounted for in accordance with SFAS No. 109 and requires a recognition threshold and measurement standard for the financial statement recognition and measurement of a tax position taken, or expected to be taken, in an income tax return. FIN 48 defines the threshold for recognizing tax return positions in the financial statements as "more likely than not" that the position is sustainable, based on its merits. Subsequent recognition, derecognition, and measurement is based on management's best judgement given the facts, circumstances and information available at the reporting date. MGE Energy and MGE adopted the provisions of FIN 48 on January 1, 2007.
Accounting for Derivative Instruments
MGE accounts for derivative financial instruments under SFAS No. 133, Accounting for Derivatives and Hedging Activities, and SFAS No. 149, Amendment of SFAS No. 133 on Derivative Instruments and Hedging Activities. Under the provisions of SFAS No. 133, all derivatives except those qualifying for the normal purchase normal sale exception are recognized on the balance sheet at their fair value. Fair value is determined using current quoted market prices.
In the third quarter of 2002, MGE received approval from the PSCW to establish a regulatory asset or liability for the deferral of the effects of mark-to-market accounting as required by SFAS No. 133 on contracts related to MGE's regulated operations.
Regulatory Assets/Liabilities
Regulatory assets represent costs that have been deferred to future periods when it is probable that the regulator will allow future recovery of those costs through rates. MGE bases its assessment of recovery by precedents established by the regulatory body. Regulatory liabilities represent previous collections from customers that are expected to be refunded to customers in future periods. Regulatory assets and regulatory liabilities typically include deferral of energy costs, the normalization of income taxes, the deferral of certain operating expenses, and non-SFAS No. 143 removal cost. The accounting for these regulatory assets and liabilities is in accordance with the provisions of SFAS No. 71, Accounting for the Effects of Certain Types of Regulation.
MGE continually assesses whether the regulatory assets and liabilities meet the criteria for probability of future recovery. This assessment considers factors such as changes in the regulatory environment, recent rate orders to other regulated entities under the same jurisdiction, and the status of any pending or potential deregulation legislation. If future recovery of costs becomes no longer probable, the assets and liabilities would be recognized as current-period revenues or expenses.
Amortization of regulatory assets and liabilities is provided over the recovery period as allowed in the related regulatory agreement.
Conditional ARO
As of December 31, 2005, MGE adopted FASB Interpretation No. 47, "Accounting for Conditional Asset Retirement Obligations" (FIN 47). FIN 47 clarified that a legal obligation associated with the retirement of a long-lived asset whose timing and/or method of settlement are conditional on a future event is within the scope of SFAS No. 143. Under FIN 47, MGE is required to record a conditional ARO at its estimated fair value if that fair value can be reasonably estimated.
The adoption of FIN 47 required MGE to update an existing inventory of AROs, originally created for the adoption of SFAS No. 143, and to determine which, if any, of the conditional AROs could be reasonably estimated. The ability to reasonably estimate a conditional ARO was a matter of management judgment, based upon management's ability to estimate a settlement date or range of settlement dates and a method or potential method of settlement of its conditional AROs. In determining whether our conditional AROs could be reasonably estimated, management considered past practices, industry practices, management's intent, and the estimated economic life of the assets. The fair value of the conditional AROs was then estimated using an expected present value technique. Changes in management's assumptions regarding settlement dates, settlement methods, or assigned probabilities could have a material effect on the liability recorded at December 31, 2007. The liabilities associated with conditional AROs will be adjusted on an ongoing basis due to the passage of time and revisions to either the timing or the amount of the original estimates of undiscounted cash flows. These adjustments could have a significant impact on the Consolidated Balance Sheets. For more information regarding FAS 143/FIN 47, see Footnote 20 of the Notes to Consolidated Financial Statements.
Adoption of Accounting Principles and Recently Issued Accounting Pronouncements - MGE Energy and MGE
SFAS
In September 2006, the FASB issued FASB Statement 157, Fair Value Measurements (SFAS 157). SFAS No. 157 defines fair value, establishes a framework for measuring fair value, and expands disclosures about fair value measurements. Under SFAS 157, fair value refers to the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants in the market in which the reporting entity transacts. The standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or liability. SFAS 157 will be effective as of January 1, 2008. MGE and MGE Energy have created an inventory of items under the scope of this standard. This inventory primarily includes marketable securities and derivatives. The adoption of this standard does not materially impact MGE Energy's and MGE's financial statements. This standard will however require additional disclosure within the footnotes.
SFAS
In February 2007, the FASB issued SFAS 159, The Fair Value Option for Financial Assets and Financial Liabilities - Including an amendment of FASB Statement No. 115. This statement allows companies to choose to measure certain financial instruments and other items at fair value at specified election dates. Per the provisions of this standard, companies are permitted to choose the fair value option on an instrument-by-instrument basis. MGE has not elected to early adopt this statement. Accordingly, SFAS 159 is effective for MGE as of January 1, 2008. MGE has assessed this standard and the related implications. Based on this assessment, MGE has concluded that on January 1, 2008, it will not elect the fair value option available under this standard.
Pension Protection Act
During the third quarter of 2006, President Bush signed into law the Pension Protection Act of 2006, which will affect the manner in which companies, including MGE and MGE Energy, administer their pension plans. This legislation will require companies to, amongst other things, increase the amount by which they fund their pension plans, pay higher premiums to the Pension Benefit Guaranty Corporation if they sponsor defined benefit plans, amend plan documents and provide additional plan disclosures in regulatory filings and to plan participants. This legislation will be effective as of January 1, 2008. The U.S. Treasury Department's interim guidance indicates that further guidance is forthcoming. MGE does not expect significant changes in expected cash flows as a result of the Act. Absent changes in plan design as a result of the Act, the Act is not expected to materially impact MGE and MGE Energy's results of operations.
FSP FIN 39-1
In April 2007, the FASB issued FSP 39-1, Amendment of FASB Interpretation No. 39 (FSP FIN 39-1). This pronouncement amends FIN 39, Offsetting of Amounts Related to Certain Contracts, and allows companies to offset fair value amounts recognized for the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) against fair value amounts recognized for derivative instruments executed with the same counterparty under a master netting agreement. MGE and MGE Energy will be electing the accounting policies prescribed by this pronouncement. FSP FIN 39-1 will be effective for MGE and MGE Energy as of January 1, 2008. The effects of applying this pronouncement shall be recognized as a change in accounting principle through retroactive application for all financial statements presented unless it is impracticable to do so. The adoption of this pronouncement will have no impact on MGE or MGE Energy's net income.
FAS 160 and FAS 141(R)
In December 2007, the FASB issued FAS 160, Non-Controlling Interests in Consolidated Financial Statements, an amendment of ARB No. 51 and FAS 141(R), Business Combinations. These pronouncements will change the accounting and reporting for business acquisitions and noncontrolling interest in a subsidiary. In addition, FAS 160 will change the accounting and reporting for the deconsolidation of a subsidiary. FAS 160 and FAS 141(R) will be effective for MGE and MGE Energy as of January 1, 2009. MGE and MGE Energy are currently assessing the impact these pronouncements will have on their financial statements.
Inflation
The current financial statements report operating results in terms of historical cost, but they do not evaluate the impact of inflation. Because utilities can depreciate only the original cost of utility plant, there may not be adequate cash flows from existing plant to replace this investment. Under PSCW rate treatment, projected operating costs, including the impacts of inflation, are recovered in revenues.
Item 7A.
Item 7A. Quantitative and Qualitative Disclosures About Market Risk - MGE Energy and MGE.
MGE Energy and MGE are potentially exposed to market risk associated with interest rates, commodity prices, weather, and equity returns. MGE currently has no exposure to foreign currency risk. MGE manages some risk exposure through risk management policies and the use of derivative instruments. MGE's risk management policy prohibits speculative trading transactions.
Weather Risk
MGE's sales forecasts, used to establish rates, are set by the PSCW based upon estimated temperatures, which approximate 20-year averages. MGE's electric revenues are sensitive to the summer cooling season and, to some extent, to the winter heating season. A significant portion of MGE's gas system demand is driven by heating. MGE's gas margin (revenues less gas purchased) is collected under a combination of fixed and volumetric rates set by the PSCW based on "normal weather." As a result of weather-sensitive demand and volumetric rates, a portion of MGE's gas margin is at risk for warmer-than-normal weather. MGE may use weather derivatives, pursuant to its risk management program, to reduce the impact of weather volatility on its gas margin.
On September 26, 2007, MGE entered into a non-exchange traded weather derivative. This agreement extends from January 2008 until March 2008. This agreement has a premium of $0.2 million. Under this agreement, MGE is subject to a floor and a ceiling based on forecasted heating degree days during the indicated period. If heating degree days are below the floor, MGE is entitled to receive payment, and if actual heating degree days exceed the ceiling, MGE is obligated to make a payment. Any payment or receipt is limited to $1.3 million. MGE accounts for HDD Collars using the intrinsic value method pursuant to the requirements of EITF No. 99-2, Accounting for Weather Derivatives.
MGE may also be impacted by extreme weather conditions. Such conditions may damage critical operating assets or may negatively impact the price of commodity and other costs.
A summary of actual weather information in the utility segment's service territory during 2007, 2006, and 2005, as measured by degree days, may be found in Results of Operations.
Commodity Price Risk
MGE has commodity price risk exposure with respect to the price of natural gas, electricity, coal, emission credits, and oil. MGE employs established policies and procedures to reduce the market risks associated with changing commodity prices. MGE's commodity risks are somewhat mitigated by the current ratemaking process in place for recovering electric fuel cost, purchased energy costs, and the cost of natural gas. MGE's electric fuel costs are subject to fuel rules established by the PSCW. Under the electric fuel rules, MGE may be required to refund to customers if the fuel rules costs fall outside the lower end of the range and would be allowed to request a surcharge if the fuel rules costs exceeded the upper end of the range. The range is defined by the PSCW and has been modified throughout the years based on market conditions and other relevant factors. Pursuant to the PSCW order issued on December 14, 2007, MGE's will be subject to a plus or minus 2% range. MGE's gas segment is governed by the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to customers the cost of gas , subject to certain limited incentives. Under both the electric fuel rules and PGA clause, MGE may include in the cost of fuel (natural gas or power) the costs and benefits of fuel price risk management tools implemented under the risk management plan approved by the PSCW.
MGE also reduces price risk caused by market fluctuations via physical contracts and derivative contracts, including futures, swaps, options, forwards, and other contractual commitments. Under MGE's risk management plan, the maximum length of time over which cash flows related to energy commodities are currently being cash-flow hedged is one year. MGE's energy contracts are accounted for under SFAS 133. Many of the contracts qualify for the normal purchase and sales exemption to SFAS 133. Those that do not qualify for this exemption are recorded as assets or liabilities on the balance sheet at fair value. Changes in the fair value of derivative instruments are recorded in current earnings or deferred in accumulated other comprehensive income (loss), depending on whether a derivative is designated as, and is effective as, a hedge and depending on the type of hedge transaction.
If the derivative qualifies for regulatory deferral subject to the provisions of SFAS No. 71, Accounting for the Effects of Certain Types of Regulation, the derivatives are marked to fair value pursuant to SFAS No. 133 and are offset with a corresponding regulatory asset or liability.
At December 31, 2007, MGE has financial gas and electric commodity contracts to hedge commodity price risk in the gas and electric segments. These contracts are primarily comprised of exchange-traded option and future contracts to manage the cost of gas. MGE also holds FTRs which are used to hedge the risk of increased congestion charges. At December 31, 2007, the cost basis of these instruments exceeded their fair value by $0.3 million. Under the PGA clause and electric fuel rules, MGE may include in the costs of fuel (natural gas or power) the costs and benefits of the aforementioned fuel price risk management tools. Because these costs and benefits are recoverable, the related unrealized gain has been deferred on the balance sheet as a regulatory asset.
During 2007, MGE has also entered into futures and basis swaps to take advantage of physical and financial arbitrage opportunities between supply basins and pricing spreads between future months' gas supply. Under the incentive mechanism within the PGA Clause, MGE shareholders have the ability to receive 50% of the benefits or loss from these deals if certain thresholds are achieved. At December 31, 2007, these positions were in an unrealized gain position of $0.2 million. Of this amount, 50% is reflected in other comprehensive income and 50% is reflected as a regulatory asset pursuant to a rate order issued by the PSCW.
MGE's energy contracts are valued using readily available NYMEX pricing data.
Interest Rate Risk
Both MGE and MGE Energy have short term borrowings at varying interest rates. MGE issues commercial paper for its short-term borrowings, while MGE Energy draws from its current credit facility to meet its short term borrowing needs (see Footnote 10 of the Notes to Consolidated Financial Statements). Borrowing levels vary from period to period depending upon capital investments and other factors. Future short-term interest expense and payments will reflect both future short-term interest rates and borrowing levels. MGE Energy and MGE manage interest rate risk by limiting their variable rate exposure and continually monitoring the effects of market changes on interest rates. MGE is not exposed to changes in interest rates on a substantial portion of its long-term debt until that debt matures and is refinanced at market rates. Assuming the current level of variable rate borrowings and assuming a 1% change in the 2007 average interest rate under these borrowings, it is estimated that our 2007 interest expense and net income would have changed by $0.6 million for MGE and $1.0 million for MGE Energy.
Equity Price Risk - Pension-Related Assets
MGE currently funds its liabilities related to employee benefits through trust funds. These funds, which include investments in debt and equity securities, are managed by various investment managers. Changes in market value of these investments can have an impact on the future expenses related to these liabilities. Holding other assumptions constant, for every 1% reduction in the expected rate of return on plan assets, annual pension and other postretirement cost would increase by approximately $1.5 million, before taxes. MGE's risk of expense and annuity payments, as a result of changes in the market value of the trust funds, is mitigated in part through future rate actions by the PSCW.
Regulatory Recovery Risk
MGE's electric operations burn natural gas in several of its peak power plants or as a supplemental fuel at several coal-fired plants and, in many cases, the cost of purchased power is tied to the cost of natural gas. MGE bears significant regulatory risk for the recovery of such fuel and purchased power costs when they are higher than the base rate established in its current rate structure.
As noted above in Commodity Price Risk, the electric operations of MGE operate under a "fuel rules" adjustment clause for fuel and purchased power costs associated with the generation and delivery of electricity. This clause establishes a base rate for fuel and purchased power. Pursuant to a PSCW rate order issued on December 14, 2007, effective January 1, 2008, MGE is subject to a fuel rules bandwidth of -2% to +2%. MGE may be required to refund to customers if the fuel rules costs fall outside the lower end of the range (-2%), and would be allowed to request a surcharge if the fuel rules costs exceeded the upper end of the range (+2%). MGE assumes the risks and benefits of variances that are within the 2% bandwidth. For 2008, fuel and purchased power costs included in MGE's base fuel rates are $119.1 million.
Credit Risk - Counterparty
Credit risk is the loss that may result from counterparty nonperformance. MGE is exposed to credit risk primarily through its merchant energy business. MGE uses credit policies to manage its credit risk, which includes utilizing an established credit approval process, monitoring counterparty limits, employing credit mitigation measures such as collateral or prepayment arrangements, and using netting agreements.
Due to the possibility of extreme volatility in the prices of energy commodities and derivatives, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If such a counterparty were then to fail to perform its obligations under its contract (for example, fail to deliver the electricity MGE originally contracted for), MGE could sustain a loss that could have a material impact on its financial results.
Additionally, if a counterparty were to default and MGE were to liquidate all contracts with that entity, MGE's credit loss would include the loss in value of mark-to-market contracts; the amount owed for settled transactions; and additional payments, if any, to settle unrealized losses on accrual contracts.
MGE is obligated to provide service to all electric and gas customers within its respective franchised territories. MGE's franchised electric territory includes a 315 square-mile area in Dane County, Wisconsin, and MGE's franchised gas territory includes a service area covering 1,625 square miles in Wisconsin. For the year ended December 31, 2007, no one customer constituted more than 7% of total operating revenues for MGE and MGE Energy. Credit risk for electric and gas is managed by MGE's credit and collection policies, which are consistent with state regulatory requirements.
Cash, cash equivalents, and customer accounts receivable are the financial instruments that potentially subject MGE Energy and MGE to concentrations of credit risk. MGE Energy and MGE place their cash and cash equivalents with high credit-quality financial institutions. MGE has limited concentrations of credit risk from customer accounts receivable because of the large number of customers and strong economy in its service territory.
Item 8.
Item 8. Financial Statements and Supplementary Data.
MGE Energy
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 Rules 13a-15f. Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an assessment of the effectiveness of our internal control over financial reporting based on the framework in Internal Control - Integrated Framework issued by the Committee Sponsoring Organizations of the Treadway Commission. Based on our assessment under the framework in Internal Control - Integrated Framework, our management concluded that our internal control over financial reporting was effective as of December 31, 2007.
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.
The effectiveness of the Company's internal control over financial reporting as of December 31, 2007, has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report which appears herein.
February 26,
MGE
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 Rules 13a-15f. Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an assessment of the effectiveness of our internal control over financial reporting based on the framework in Internal Control - Integrated Framework issued by the Committee Sponsoring Organizations of the Treadway Commission. Based on our assessment under the framework in Internal Control - Integrated Framework, our management concluded that our internal control over financial reporting was effective as of December 31, 2007.
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.
February 26,
Report of Independent Registered Public Accounting Firm
To the Board of Directors and
Shareholders of MGE Energy, Inc.:
In our opinion, the consolidated financial statements listed in the accompanying index appearing under Item 15(a)(1) present fairly, in all material respects, the financial position of MGE Energy, Inc. and its subsidiaries at December 31, 2007 and 2006, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2007, 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 appearing 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. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2007, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The Company's management is responsible for these financial statements and financial statement schedule, for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in Management's Report on Internal Control Over Financial Reporting. Our responsibility is to express opinions on these financial statements, on the financial statement schedule, and on the Company's internal control over financial reporting based on our integrated audits. We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the financial statements included 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. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide 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.
/s/ PricewaterhouseCoopers LLP
Chicago, Illinois
February 26,
Report of Independent Registered Public Accounting Firm
To the Board of Directors and
Shareholder of Madison Gas and Electric Company:
In our opinion, the accompanying consolidated balance sheets and the related consolidated financial statements listed in the index appearing under Item 15(a)(1) present fairly, in all material respects, the financial position of Madison Gas and Electric Company and its subsidiaries at December 31, 2007 and 2006, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2007, 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 index appearing 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 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.
/s/ PricewaterhouseCoopers LLP
Chicago, Illinois
February 26,
MGE Energy, Inc.
Consolidated Statements of Income
(In thousands, except per-share amounts)
The accompanying notes are an integral part of the above consolidated financial statements.
MGE Energy, Inc.
Consolidated Statements of Cash Flows
(In thousands)
The accompanying notes are an integral part of the above consolidated financial statements.
MGE Energy, Inc.
Consolidated Balance Sheets
(In thousands)
The accompanying notes are an integral part of the above consolidated financial statements.
MGE Energy, Inc.
Consolidated Statements of Capitalization
(In thousands)
The accompanying notes are an integral part of the above consolidated financial statements.
MGE Energy, Inc.
Consolidated Statements of Common Equity and Comprehensive Income
(In thousands, except per-share amounts)
The accompanying notes are an integral part of the above consolidated financial statements.
Madison Gas and Electric Company
Consolidated Statements of Income
(In thousands)
The accompanying notes are an integral part of the above consolidated financial statements.
Madison Gas and Electric Company
Consolidated Statements of Cash Flows
(In thousands)
The accompanying notes are an integral part of the above consolidated financial statements.
Madison Gas and Electric Company
Consolidated Balance Sheets
(In thousands)
The accompanying notes are an integral part of the above consolidated financial statements.
Madison Gas and Electric Company
Consolidated Capitalization Statement
(In thousands)
The accompanying notes are an integral part of the above consolidated financial statements.
Madison Gas and Electric Company
Consolidated Statements of Common Equity and Comprehensive Income
(In thousands, except per-share amounts)
The accompanying notes are an integral part of the above consolidated financial statements.
Notes to Consolidated Financial Statements
December 31, 2007, 2006, and 2005
This report is a combined report of MGE Energy and MGE. The notes to the consolidated financial statements that follow include consolidated MGE Energy footnotes and certain footnotes related to MGE as signified below.
1.
Summary of Significant Accounting Policies.
a.
Regulation and System of Accounts - MGE Energy and MGE.
Accounting policies for regulated operations are in accordance with those policies prescribed by the regulatory authorities having jurisdiction, principally the PSCW and FERC. MGE's accounting records conform to the FERC uniform system of accounts.
b.
Principles of Consolidation - MGE Energy and MGE.
MGE, a wholly owned subsidiary of MGE Energy, is a regulated electric and gas utility headquartered in Madison, Wisconsin. MGE is the majority owner of MGE Transco. MGE Transco is a nonregulated entity formed to manage the investment in ATC.
Wholly owned subsidiaries of MGE Energy include CWDC, MAGAEL, MGE Construct, and MGE Power. MGE Power owns 100% of MGE Power West Campus and MGE Power Elm Road. MGE Power and its subsidiaries are part of our nonregulated energy operations, which were formed to own and lease new electric generation projects.
MGE consolidates the financial statements of entities in which it has a controlling financial interest, pursuant to the requirements of FIN 46R. In accordance with these provisions, MGE has consolidated MGE Power West Campus and MGE Power Elm Road. See Footnotes 2 and 21 to the Consolidated Financial Statements for more discussion of these entities.
The consolidated financial statements reflect the application of certain accounting policies described in this note. All significant intercompany accounts and transactions have been eliminated in consolidation.
c.
Use of Estimates - MGE Energy and MGE.
In order to prepare consolidated financial statements in conformity with generally accepted accounting principles, management must make estimates and assumptions. These estimates could affect reported amounts of assets, liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements, as well as the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from management's estimates.
d.
Cash Equivalents - MGE Energy and MGE.
MGE Energy and MGE consider all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents.
e.
Restricted Cash - MGE Energy and MGE.
MGE has certain cash accounts that are restricted to uses other than current operations and designated for a specific purpose. MGE's restricted cash accounts include amounts held as margin for certain financial transactions and cash held by trustees for certain employee benefits.
f.
Trade Receivables, Allowance for Doubtful Accounts, and Concentration Risk - MGE Energy and MGE.
Trade accounts receivable are recorded at the invoiced amount and do not bear interest. However, a 1% late payment charge is recorded on all receivables unpaid after the due date. The allowance for doubtful accounts associated with these receivables represents our best estimate of the amount of probable credit losses in our existing accounts receivable. We determine our allowance for doubtful accounts based on historical write-off experience, regional economic data, and review of the accounts receivable aging.
MGE is obligated to provide service to all electric and gas customers within its franchised territories. MGE's franchised electric territory includes a 315 square-mile area in Dane County, Wisconsin, and MGE's franchised gas territory includes a service area covering 1,625 square miles in Wisconsin. MGE manages this concentration and the related credit risk through its credit and collection policies, which are consistent with state regulatory requirements.
g.
Inventories - MGE Energy and MGE.
Inventories consist of natural gas in storage, fossil fuels, materials and supplies and SO2 allowances. MGE values natural gas in storage, coal at the Columbia facility, and materials and supplies using average cost. MGE values coal at Blount using last-in-first-out pricing (LIFO).
At December 31, 2007 and 2006, $0.9 million and $2.2 million, respectively, of the fossil fuel inventory at Blount was valued using LIFO. This inventory at current cost exceeds the LIFO stated value by $1.0 million and $0.4 million at December 31, 2007 and 2006, respectively. Additionally, during 2007 and 2006, liquidation of LIFO layers, carried at costs that were lower than current purchases, resulted in a decrease to costs of goods sold of $0.6 million and less than $0.1 million, respectively.
SO2 emission allowances are included in inventory and are recorded at the lower of weighted average cost or market. These allowances are charged to fuel expense as they are used in operations. MGE's emission allowance balances as of December 31, 2007 and 2006, were $1.6 million and $2.9 million, respectively.
h.
Regulatory Assets and Liabilities - MGE Energy and MGE.
Pursuant to SFAS No. 71, Accounting for the Effects of Certain Types of Regulation, MGE capitalizes as regulatory assets incurred costs that are expected to be recovered in future electric and natural gas rates. MGE also records as regulatory liabilities obligations to customers to refund previously collected revenue or to spend revenue collected from customers on future costs.
i.
Debt Issuance Costs - MGE Energy and MGE.
Premiums, discounts, and expenses incurred with the issuance of outstanding long-term debt are amortized over the life of the debt issue. Any call premiums or unamortized expenses associated with refinancing higher-cost debt obligations used to finance utility-regulated assets and operations are amortized consistent with regulatory treatment of those items.
j.
Property, Plant, and Equipment - MGE Energy and MGE.
Property, plant, and equipment is recorded at original cost. Cost includes indirect costs consisting of payroll taxes, pensions, postretirement benefits, other fringe benefits, and administrative and general costs. Also, included in the cost is AFUDC for utility property and capitalized interest for nonregulated property. Additions for significant replacements of property are charged to property, plant, and equipment at cost; minor items are charged to maintenance expense. The cost of removal of utility property less salvage value is charged to accumulated depreciation when property is retired. Depreciation rates on utility property are approved by the PSCW, are based on the estimated economic lives of property, and include estimates for salvage value and removal costs. Depreciation rates on nonregulated property are based on the estimated economic lives of the property.
Provisions at composite straight-line depreciation rates approximate the following percentages for the cost of depreciable property:
Electric
3.1%
3.1%
3.1%
Gas
3.3%
3.3%
3.4%
Nonregulated
2.5%
2.5%
2.5%
k.
Repairs and Maintenance Expense - MGE Energy and MGE.
In accordance with the provisions set forth in FSP AUG AIR-1, Accounting for Planned Major Maintenance Activities, MGE utilizes the direct expensing method for any such projects. Under this method, MGE expenses all costs associated with major planned maintenance activities as incurred.
l.
Purchased Gas Adjustment Clause - MGE Energy and MGE.
MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. At December 31, 2007 and 2006, MGE had over collected $4.5 million and $1.9 million, respectively. These amounts were recorded in other current liabilities on MGE's Consolidated Balance Sheet.
m.
Revenue Recognition - MGE Energy and MGE.
Operating revenues are recorded as service is rendered or energy is delivered to customers. At the end of the month, MGE accrues an estimate for the unbilled amount of energy delivered to customers. See Footnote 1w for further discussion of unbilled revenues.
MGE's rates include a provision for fuel costs. MGE records an adjustment to revenues for a fuel credit at the time MGE's actual fuel costs fall below the bandwidth prescribed by the PSCW and MGE concludes that it is probable that the credit will be approved by the PSCW staff. MGE will also record an adjustment to revenue when the PSCW institutes a "subject to refund" provision in an order. See Footnote 17 for further discussion of the fuel rules.
n.
Capitalized Interest - MGE Energy and MGE.
MGE Energy, through its subsidiaries MGE Power West Campus and MGE Power Elm Road, calculates capitalized interest in accordance with SFAS No. 34, Capitalization of Interest Cost, on construction projects for periods where financing is provided by MGE Energy through interim debt.
For the years ended December 31, 2007, 2006, and 2005, $3.9 million, $1.9 million, and $0.9 million in interest costs related to the Elm Road and/or WCCF projects were capitalized, respectively. The aforementioned amounts were capitalized as part of the cost of the asset in accordance with the provisions set forth in SFAS No. 34.
o.
Allowance for Funds Used During Construction - MGE Energy and MGE.
Allowance for funds used during construction is included in utility plant accounts and represents the cost of borrowed funds used during plant construction and a return on shareholders' capital used for construction purposes. In the Consolidated Income Statements, the cost of borrowed funds (AFUDC-debt) is presented as an offset to interest expense and the return on shareholders' capital (AFUDC- equity funds) is shown as an item within other income. As approved by the PSCW, MGE capitalized AFUDC-debt and equity on 50% of applicable average construction work in progress (excluding the wind project) during 2007 at 9.12%. Also, MGE received specific approval to recover 100% AFUDC on the Top of Iowa III wind project. Although the allowance does not represent current cash income, it is recovered under the ratemaking process over the service lives of the related properties.
p.
Investments - MGE Energy and MGE.
Investments in the common stock of companies in which MGE or MGE Energy's ownership interest is 50% or less and in which MGE or MGE Energy exercises significant influence over operating and financial policies are accounted for using the equity method. All other investments are carried at fair value or at cost, as appropriate.
q.
Capitalized Software Costs - MGE Energy and MGE.
Property, plant and equipment includes the capitalized costs of internal use software totaling $7.4 million at December 31, 2007, and $6.9 million at December 31, 2006. During both 2007 and 2006, MGE recorded $1.0 million of amortization expense related to these costs. These costs are amortized on a straight-line basis over the estimated useful lives of the assets. For internal use software, the useful lives range from five to ten years.
r.
Impairment of Long-Lived Assets - MGE Energy and MGE.
MGE reviews plant and equipment and other property for impairment when events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. MGE's policy for determining when long-lived assets are impaired is to recognize an impairment loss if the sum of the expected future cash flows (undiscounted and without interest charges) from an asset are less than the carrying amount of that asset. If an impairment loss is recognized, the amount that will be recorded will be measured as the amount by which the carrying amount of the asset exceeds the fair value of the asset. MGE believes there is no impairment of long-lived assets in accordance with SFAS No. 144 at December 31, 2007.
s.
Income Taxes and Excise Taxes - MGE Energy and MGE.
Income taxes
Under the liability method prescribed by SFAS No. 109, income taxes are deferred for all temporary differences between pretax financial and taxable income and between the book and tax basis of assets and liabilities using the tax rates scheduled by law to be in effect when the temporary differences reverse. Future tax benefits are recognized to the extent that realization of such benefits is more likely than not. A valuation allowance is recorded for those benefits that do not meet this criterion.
Regulation and SFAS No. 109 have resulted in a regulatory liability related to income taxes. Excess deferred income taxes result from past taxes provided at rates higher than current rates. The SFAS No. 109 regulatory liability and deferred investment tax credit reflect the revenue requirement associated with the return of these tax benefits to customers.
Investment tax credits from regulated operations are amortized over related property service lives.
The 2007, 2006, and 2005 tax credits for the generation of electricity from wind are based on kWh produced and sold during the years at the statutory tax credit rate of 2.0 cents per kWh or $0.5 million for 2007 and 1.9 cents per kWh or $0.4 million for both 2006 and 2005.
In June 2006, the FASB issued FIN 48, Accounting for Uncertainty in Income Taxes, an interpretation of SFAS No. 109, Accounting for Income Taxes. FIN 48 clarifies the accounting for uncertainty in income taxes recognized in an enterprise's financial statements in accordance with SFAS No. 109. The interpretation applies to all tax positions accounted for in accordance with SFAS No. 109 and requires a recognition threshold and measurement standard for the financial statement recognition and measurement of a tax position taken, or expected to be taken, in an income tax return. FIN 48 defines the threshold for recognizing tax return positions in the financial statements as "more likely than not" that the position is sustainable, based on its merits. Subsequent recognition, derecognition, and measurement is based on management's best judgement given the facts, circumstances and information available at the reporting date. MGE Energy and MGE adopted the provisions of FIN 48 on January 1, 2007. For further discussion, refer to Footnote 12.
Excise taxes
MGE Energy, through its utility operations, pays a state license fee tax in lieu of property taxes on property used in utility operations. License fee tax is calculated as a percentage of adjusted operating revenues of the prior year. The electric tax rate is 3.19% for retail sales and 1.59% for sales of electricity for resale by the purchaser. The tax rate on sales of natural gas is 0.97%. The tax is required to be estimated and prepaid in the year prior to its computation and expensing. License fee tax expense, included in other general taxes, was $11.8 million, $11.6 million, and $9.7 million for the years ended December 31, 2007, 2006, and 2005, respectively.
Operating income taxes, including tax credits, and license fee tax are included in rates for utility related items.
t.
Share-Based Compensation - MGE Energy and MGE.
The MGE Energy Board approved a Performance Unit Plan (the "Plan") on December 15, 2006. Under the Plan, eligible participants may receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the set performance period. Per the Plan's provisions, these awards are subject to a prescribed vesting schedule and must be settled in cash. Accordingly, no new shares of common stock will be issued in connection with the Plan. MGE and MGE Energy have adopted the provisions of SFAS 123R, Share-Based Payment. This guidance establishes standards for the accounting of transactions in which an entity exchanges equity instruments for goods and services. Additionally, this standard addresses the accounting for transactions in which an entity incurs liabilities in exchange for goods or services that are based on the fair value of the entity's equity instruments.
Based on the provisions of SFAS 123R, MGE Energy and MGE will initially measure the cost of the employee services received in exchange for the award based on current market value of MGE Energy common stock. The fair value of the award will be subsequently re-measured at each reporting date through the settlement date. Changes in fair value during the requisite period will be recognized as compensation cost over that period.
u.
Treasury Stock - MGE Energy.
Treasury shares are recorded at cost. Any shares of common stock repurchased are held as treasury shares unless cancelled or reissued.
v.
Comprehensive Income - MGE Energy and MGE.
The reporting of other comprehensive income is required under the provisions of SFAS No. 130, Reporting Comprehensive Income. Total Comprehensive income includes all changes in equity during a period except those resulting from investments by and distributions to shareholders. Comprehensive income is reflected in the Consolidated Statements of Common Equity and Comprehensive Income.
w.
Unbilled Revenues - MGE Energy and MGE.
Revenues from the sale of electricity and gas to customers are recorded when electricity/gas is delivered to those customers. The quantity of those sales is measured by customers' meters, and customers' bills are based on readings of those meters. However, due to the large number of those meters, it is impractical to read all of the meters at month-end. Meters are therefore read on a systematic basis throughout the month based on established meter-reading schedules. At the end of any month, there exists a quantity of electric and gas service that has been delivered but not metered or billed. Management must estimate this usage and related revenue. This estimate represents electricity and gas delivered to customers between their meter-read date and the end of the period.
In order to estimate unbilled revenues as of the end of a particular period, MGE performs a series of calculations based upon actual and estimated numbers and assumptions. MGE begins by calculating the amount of electricity and gas available for sale within its system during that period based upon known inputs (i.e., electricity and gas purchases from third parties, gas from storage, and MGE-generated electricity). These amounts are then adjusted to deduct the amounts actually included in customers' bills for that period.
In the case of electricity, the amount is further reduced by estimating the quantity of electricity lost in the process of transmitting and distributing it to customers. The resulting available-for-sale quantities are then allocated to various customer classes based upon historical utilization patterns for those customers. MGE applies published tariffs to determine the associated revenues. Utilization patterns are based upon assumptions regarding weather, economic conditions, and consistency of use over the period in question. Actual use can be affected by variations in those items. The resulting estimate is then compared to other available statistics, including billed sales for the particular period, in order to confirm its reasonableness. Namely, MGE monitors the reasonableness of the unbilled revenue estimate through the review of ratios such as unbilled electric receivables to billed electric sales. MGE expects that this ratio will be in the range of 40% to 60%.
x.
Derivative and Hedging Instruments - MGE Energy and MGE.
As part of regular operations, MGE enters into contracts including options, swaps, futures, forwards, and other contractual commitments to manage its exposure to interest rates, commodity prices, and gas margin. MGE evaluates its derivative contracts in accordance with SFAS No. 133, Accounting for Derivative Instruments and Hedging Activities, as amended and interpreted. SFAS No. 133 requires the Company to recognize all derivatives in the consolidated balance sheets at fair value, with changes in the fair value of derivative instruments to be recorded in current earnings or deferred in accumulated other comprehensive income (loss), depending on whether a derivative is designated as, and is effective as, a hedge and on the type of hedge transaction. Derivative activities are in accordance with the company's risk management policy.
If the derivative qualifies for regulatory deferral subject to the provisions of SFAS No. 71, Accounting for the Effects of Certain Types of Regulation, the derivatives are marked to fair value pursuant to SFAS No. 133 and any resulting loss or gain is offset with a corresponding regulatory asset or liability. Cash flows from such derivative instruments are classified on a basis consistent with the nature of the underlying hedged item.
2.
Variable Interest Entities - MGE Energy and MGE.
In January 2003, the FASB issued FIN 46, Consolidation of Variable Interest Entities-An Interpretation of ARB No. 51. In December 2003, the FASB issued the updated and final interpretation FIN 46R. FIN 46 was applicable immediately to VIEs created or obtained after January 31, 2003. FIN 46R was effective on December 31, 2003, for interests in entities that were previously considered special-purpose entities under then existing authoritative guidance.
a.
MGE Power West Campus.
MGE Power West Campus is not a subsidiary of MGE; however, it has been consolidated in the financial statements of MGE as of December 31, 2003, and subsequent periods due to the adoption of FIN 46R. MGE Power West Campus was created for the purpose of owning new generating assets. MGE Power West Campus' sole principal asset is the WCCF, which it leases to MGE pursuant to a long-term lease. MGE is responsible for operation of the plant during the term of the lease. Based on the nature and terms of these contractual relationships, MGE absorbs a majority of the expected losses, residual value, or both, associated with the ownership and operation of the WCCF. MGE is also the party most closely associated with MGE Power West Campus. As a result, MGE is the primary beneficiary and MGE Power West Campus is a VIE under FIN 46R.
b.
MGE Power Elm Road.
MGE Power Elm Road is not a subsidiary of MGE; however, it has been consolidated in the financial statements of MGE due to the adoption of FIN 46R. MGE Power Elm Road was created for the purpose of owning new generating assets. MGE Power Elm Road's sole principal assets are an 8.33% undivided ownership interest in two 615 MW coal-fired generating plants being constructed in Oak Creek, Wisconsin, which will be leased to MGE for the benefit of its customers. Based on the nature and terms of this contractual relationship, MGE is expected to absorb a majority of the expected losses, residual value, or both, associated with MGE Power Elm Road's ownership interest in these plants. MGE is also the party most closely associated with MGE Power Elm Road. As a result, MGE is the primary beneficiary and MGE Power Elm Road is a VIE under FIN 46R.
c.
Shared Savings Program.
FIN 46R also requires MGE to assess whether the participants within its Shared Savings program constitute VIEs in which MGE might be considered to be the consolidating entity. MGE has reviewed 87.7% of the total current Shared Savings program balance and has determined that the provisions of FIN 46R are not applicable via the "business scope exception." For the remaining 12.3% of the total current Shared Savings program balance, these entities are not legally obligated to provide the financial information to MGE that is necessary to determine whether MGE must consolidate these entities. MGE will continue to attempt to obtain information from these customers in order to determine whether they should be consolidated by MGE.
3.
Property, Plant, and Equipment - MGE Energy and MGE.
Property, plant, and equipment consisted of the following at December 31:
MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust. As of December 31, 2007, there was $1.2 million of bonds outstanding under that indenture. See Footnote 9 for further discussion of the mortgage indenture.
4.
Investments - MGE Energy and MGE.
a.
Equity Method Investments and Available for Sale Securities.
MGE and MGE Energy's available for sale securities represent publicly traded securities and private equity investments in common stock of companies in various industries.
Of the available for sale securities held by MGE Energy and MGE at December 31, 2007, $1.0 million and $0.5 million, respectively, were not evaluated for impairment because a) the Company did not estimate the fair value of those investments in accordance with paragraphs 14 and 15 of SFAS 107, Disclosures about Fair Value of Financial Instruments, and b) the Company did not identify any events or changes in circumstances that may have had a significant adverse effect on the fair value of those investments.
For the year ended December 31, 2006, MGE and MGE Energy recorded $0.1 million in investment impairment charges. These charges represent an other-than-temporary decline in the value of its investment portfolio. No such charges were recorded for the years ended December 31, 2007 and 2005.
During the year ended December 31, 2007, certain investments were liquidated. As a result of these liquidations, MGE and MGE Energy received $0.9 million in cash proceeds and recorded a $0.8 million gain on the sale of investments.
b.
ATC.
ATC owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC. That interest is presently held by MGE Transco, which is jointly owned by MGE and MGE Energy.
MGE Transco, through MGE, has a seat on the Board of Directors of ATC and has a 20% ownership interest in ATC Management, Inc. Due to MGE Transco's ability to exercise significant control over management activities, MGE Transco has accounted for its investment in ATC under the equity method of accounting. For the twelve months ended December 31, 2007, 2006, and 2005, MGE Transco recorded equity earnings from the investment in ATC of $6.0 million, $5.3 million, and $4.9 million, respectively. Dividend income received from ATC was $4.4 million, $4.0 million , and $3.6 million for the twelve months ended December 31, 2007, 2006, and 2005, respectively. During the twelve months ended December 31, 2007, MGE Transco made no cash contributions to ATC. However, on February 15, 2007, MGE (through MGE Transco) transferred $1.4 million in additional transmission assets to ATC. In exchange, MGE Transco received an additional $0.7 million investment in ATC and $0.7 million in cash consideration. MGE Transco made capital contributions to ATC of $1.9 million and $1.4 million for the twelve months ended December 31, 2006 and 2005, respectively.
At December 31, 2007, MGE Transco held a 3.6% ownership interest in ATC. MGE Transco's investment balance is different from the amount of the underlying equity in the net assets of ATC. This difference is attributable to the allocation of certain tax impacts related to the initial asset transfer and additional contributions required by tax-exempt shareholders.
At December 31, 2007, MGE is the majority owner and MGE Energy is the minority owner of MGE Transco. MGE Energy's proportionate share of the equity and net income of MGE Transco is classified within the MGE financial statements as minority interest.
5.
Joint Plant Ownership - MGE Energy and MGE.
a.
Columbia.
MGE and two other utilities jointly own Columbia, a coal-fired generating facility, which accounts for 29% (225 MW) of MGE's net generating capability. Power from this facility is shared in proportion to each company's ownership interest. MGE has a 22% ownership interest in Columbia. The other owners are Alliant, which operates Columbia, and WPSC. MGE's share of fuel, operating, and maintenance expenses for Columbia were $31.3 million, $29.7 million, and $28.5 million for the years ended December 31, 2007, 2006, and 2005, respectively. See Footnote 18 for discussion of MGE's future capital commitments as s result of this ownership interest.
Each owner provides its own financing and reflects its respective portion of facilities and operating costs in its financial statements. MGE's interest in Columbia, included in its gross utility plant in service, and the related accumulated depreciation reserves at December 31 were as follows:
(In thousands)
Utility plant
$112,079
$112,407
Accumulated depreciation
(70,562)
(69,522)
Net plant
$ 41,517
$ 42,885
b.
WCCF.
MGE Power West Campus and the UW jointly own the West Campus Cogeneration Facility located on the UW campus. MGE Power West Campus owns 55% of the facility and UW owns 45% of the facility. The UW owns a controlling interest in the chilled-water and steam plants, which are used to meet the growing needs for air-conditioning and steam-heat capacity for the UW campus. MGE Power West Campus owns a controlling interest in the electric generation plant, which is leased and operated by MGE.
Each owner provides its own financing and reflects its respective portion of the facility and operating costs in its financial statements. MGE Power West Campus' interest in WCCF at December 31 were as follows:
(In thousands)
Nonregulated Plant
$108,757
$108,310
Accumulated depreciation
(7,289)
(4,611)
Net plant
$101,468
$103,699
Operating charges are allocated to the UW based on the operating agreement. Under the provisions of this arrangement, the UW is required to reimburse MGE for their allocated portion of fuel and operating expenses. These allocations are based on formulas outlined in the operating agreement. For the years ended December 31, 2007, 2006, and 2005, the State was allocated $3.0 million, $2.6 million, and $0.9 million, respectively, in fuel and operating costs.
c.
Elm Road.
See Footnote 21 for a discussion of MGE Energy's joint ownership interest in Power Elm Road.
6.
Regulatory Assets and Liabilities - MGE Energy and MGE.
The following regulatory assets and liabilities are reflected in MGE's consolidated balance sheet as of December 31:
(In thousands)
Regulatory Assets
Environmental costs
$ 1,268
$ 1,386
Deferred charges related to interest - 2027A Series
Regulatory asset - SFAS No. 133
2,849
Tax recovery related to AFUDC equity
4,124
3,087
Asset retirement obligation - SFAS No. 143 and FIN 47
4,247
4,039
Unfunded pension and other postretirement liability
33,672
38,085
Debt related costs
3,829
2,427
Regulatory assets - Elm Road
1,025
1,427
Conservation costs
2,815
-
Blount restructuring costs
Other
Total regulatory assets
$53,564
$55,111
Regulatory Liabilities
Regulatory liability - SFAS No. 109
$ 5,549
$ 6,689
Regulatory liability - SFAS 158 medicare subsidy
1,558
3,668
Non-SFAS No. 143 removal cost
13,204
12,963
Vendor settlements
Regulatory liability - customer fuel credit
-
2,312
Deferred charges related to ATC
Conservation costs
-
Congestion Cost and Line Loss Allocation Agreement
2,845
-
Other
Total regulatory liabilities
$23,809
$27,150
MGE expects to recover its regulatory assets and return its regulatory liabilities through rates charged to customers based on PSCW decisions made during the ratemaking process or based on PSCW long-standing policies and guidelines. The adjustments to rates for these regulatory assets and liabilities will occur over the periods either specified by the PSCW or over the corresponding period related to the asset or liability. We believe it is probable that MGE will continue to recover from customers the regulatory assets described above based on prior and current ratemaking treatment for such costs. MGE is earning a return on all regulatory assets net of any related liabilities, except for amounts expended for environmental costs and $1.5 million in debt related costs. MGE expects to earn a return on the debt related item in its next base rate case.
Environmental Costs
MGE has received regulatory treatment on environmental costs including clean up of two landfill sites and a substation site and certain environmental costs at Columbia. As it relates to the landfills and substation, the regulators have only allowed MGE to recover actual environmental expenditures incurred excluding any carrying cost. As of December 31, 2007, MGE has recorded $0.9 million in regulatory assets for these environmental costs, including $0.1 million for accrual for estimated future site remediation and $0.8 million of deferrals for actual remediation costs incurred. These costs are being recovered over a four year period.
In addition, MGE has been allowed to defer actual costs plus carrying costs on certain Columbia environmental expenditures. As of December 31, 2007, MGE has recorded $0.4 million in regulatory assets related to these costs. The costs will be transferred to construction work in progress once a Certificate of Authority is received by the PSCW. MGE expects recovery of these costs over the life of the installed equipment.
Deferred Charges Related to Interest - 2027A Series
Deferred charges on the interest expense of the 2027A Series relates to the incremental difference in the interest that MGE earned on its construction bond fund and the actual interest that MGE paid out. That incremental difference between interest earned and interest expensed is currently being amortized over the remaining life of the bonds as part of the rate recovery allowed by the PSCW.
Regulatory Asset (liability) - SFAS No. 133
MGE has physical and financial contracts that are defined as derivatives under SFAS No. 133, Accounting for Derivative Instruments and Hedging Activities. The amounts recorded for the net mark-to-market value of the commodity based contracts is offset with a corresponding regulatory asset or liability because these transactions are part of the PGA or fuel rules clause authorized by the PSCW.
Tax Recovery Related to AFUDC Equity
AFUDC equity represents the after-tax equity cost associated with utility plant construction and results in a temporary difference between the book and tax basis of such plant. Deferred income taxes are provided on this temporary difference in accordance with SFAS No. 109, Accounting for Income Taxes. It is probable under PSCW regulation that MGE will recover in future rates the future increase in taxes payable represented by the deferred income tax liability. The amounts will be recovered in rates over the depreciable life of the asset for which AFUDC was applied. Tax recovery related to AFUDC equity represents the revenue requirement related to recovery of these future taxes payable, calculated at current statutory tax rates.
Asset Retirement Obligation - SFAS No. 143 and FIN 47
See Footnote 20 for further discussion.
Unfunded Pension and Other Postretirement Liability
As of December 31, 2006, MGE and MGE Energy adopted SFAS 158. Under SFAS 158, MGE is required to recognize the unfunded status of defined benefit pension and other postretirement pension plans as a net liability or asset on the balance sheet with an offset to other comprehensive income. The amount normally charged to other comprehensive income for the unfunded status represents future expenses that are expected to be recovered in rates. Accordingly, MGE has recorded such adjustments as a regulatory asset.
Debt Related Costs
This balance includes debt issuance costs of extinguished debt and other debt related expenses. See Footnote 9 for further discussion related to the swap lock. The PSCW has allowed rate recovery on unamortized issuance costs for extinguished debt facilities. When the facility replacing the old facility is deemed by the PSCW to be more favorable for the ratepayers, the PSCW will allow rate recovery of any unamortized issuance costs related to the old facility. These amounts are recovered over the term of the new facility and are classified as regulatory assets within the consolidated financial statements.
Regulatory Assets - Elm Road
On November 1, 2005, MGE received approval from the PSCW to defer payments made to MGE Power Elm Road for carrying costs during construction of the facility, management fees, community impact mitigation, and transition costs. At December 31, 2007, $0.6 million of the regulatory asset balance related to Elm Road represents deferred management fees, community impact, and transition costs and $0.4 million represents carrying costs on the carrying costs. MGE anticipates collection in rates of carrying costs over a four year period beginning in the year of payment. All other costs are collected in rates over a one to two year period.
Conservation Costs
MGE has received regulatory treatment for certain conservation expenditures. The expenditures are used for demand-side management programs to promote energy efficiency on the customer's premises. Costs for demand-side management programs are estimated in MGE's rates utilizing escrow accounting. The escrow accounting allows the utility to true-up its actual costs incurred and reflect the amount of the true-up in its next rate case filing and amortize the amount over the rate case period.
Blount Restructuring Costs
On January 19, 2006, MGE announced a plan, subject to certain conditions, that includes discontinuing coal use at the end of 2011 at Blount. The plant will continue to run on natural gas but will be reduced from its current approximate 190 MW capacity to 100 MW when coal burning is discontinued. MGE has determined certain employee positions will be eliminated in 2011 as a result of this exit plan. Accordingly, this plan has resulted in certain involuntary and voluntary severance benefits. Additionally, this exit plan resulted in a curtailment under SFAS 88 and retention bonus payments. MGE expects recovery of these amounts beginning in 2008 and continuing through 2011. Costs will be recovered in rates in the year cash payments are expected to be made.
Regulatory Liability - SFAS No. 109
Regulation and SFAS No. 109 have resulted in a regulatory liability related to income taxes. Excess deferred income taxes result from past taxes provided at rates higher than current rates. The SFAS No. 109 regulatory liability and deferred investment tax credit reflects the revenue requirement associated with the return of these tax benefits to customers.
Regulatory Liability - SFAS 158 Medicare Subsidy
This amount relates to the difference in treatment of the Medicare Part D Subsidy for tax and book purposes under the provisions of SFAS 158. For SFAS 109 purposes, the benefit of this subsidy is excluded from the computation of the unfunded liability. However, for financial statement purposes the unfunded liability includes (or is reduced by) the benefit of the Medicare Part D Subsidy. Such tax benefits will be returned to customers in rates in future periods.
Non-SFAS No. 143 Removal Costs
In connection with the adoption of SFAS No. 143, companies are required to reclassify cumulative collections for non-ARO removal costs as a regulatory liability, with an offsetting entry to accumulated depreciation. Under the current rate structure, these removal costs are being recovered as a component of depreciation expense.
Vendor Settlements
MGE has a settlement agreement with a certain vendor in which it has received various payments since 1999. All settlements received from this vendor are returned to customers generally over a two-year period beginning in the rate case period following the actual receipt.
Regulatory Liability - Customer Fuel Credit
See Footnote 17 for further discussion.
Congestion Cost and Line Loss Allocation Agreement
On February 14, 2007, MGE signed a five year Congestion Cost and Line Loss Allocation Service Agreement. Under the provisions of this agreement, certain load serving entities in the Wisconsin and Upper Peninsula of Michigan System (WUMS) agreed to aggregate and equitably allocate certain costs that have not been perfectly allocated by the MISO Day 2 market. Specifically, this agreement achieves a uniform line loss percentage and socializes the costs incurred as a result of shortages in the FTR allocation process. The benefit received or expense incurred under the agreement is required to be returned to or collected from customers. The amounts collected in 2007 related to this agreement will be returned to customers in 2008.
7.
Common Equity.
a.
Common Stock - MGE Energy.
On November 9, 2006, MGE Energy entered into a Distribution Agreement with JP Morgan in which MGE Energy may offer and sell up to 1,500,000 shares of its common stock. During 2007, MGE Energy issued 383,500 shares of its common stock for $12.7 million in net proceeds under this agreement. During 2006, MGE Energy issued 221,500 shares of its common stock for $7.4 million in net proceeds under this agreement. These sales are made pursuant to an effective shelf registration statement MGE Energy filed with the SEC in March 2003.
MGE Energy also sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales are covered by a shelf registration statement that MGE Energy filed with the SEC. During the period from March 2005 to May 2006, MGE Energy generally purchased shares in the open market for Stock Plan participants. In June 2006, MGE Energy switched from purchasing shares on the open market to issuing new shares of its common stock for the Stock Plan. For the twelve months ended December 31, 2007 and 2006, MGE Energy issued 591,443 and 299,396 new shares of common stock under the Stock Plan for net proceeds of $20.1 million and $9.7 million, respectively.
At December 31, 2005, MGE Energy held $0.1 million of treasury stock that had been purchased on the open market. The cost basis of these shares was shown at December 31, 2005, as a reduction to stockholders' equity on the MGE Energy consolidated financial statements. During the twelve months ended December 31, 2006, these shares were distributed to participants of the Stock Plan. No treasury stock was held by MGE Energy as of December 31, 2007 and 2006. During the twelve months ended December 31, 2007 and 2006, MGE Energy paid $30.3 million (or $1.41 per share) and $28.5 million (or $1.39 per share), respectively, in cash dividends on their common stock. Dividends on common stock at MGE are subject to restrictions imposed by the PSCW and the covenants of MGE's outstanding first mortgage bonds. See Footnote 9 and the "Liquidity and Capital Resources - Financing Activities" under Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations for further discussion of these covenants.
b.
Preferred Stock - MGE Energy and MGE.
MGE has 1,175,000 shares of $25 par value redeemable preferred stock (cumulative) that is authorized but unissued at December 31, 2007 and 2006.
c.
Dilutive Shares Calculation - MGE Energy.
MGE Energy does not hold any dilutive securities.
8.
Minority Interest - MGE.
a.
MGE Power West Campus.
MGE Power West Campus is not a subsidiary of MGE; however, it has been consolidated in the consolidated financial statements of MGE, due to the adoption of FIN 46(R) (see Footnote 2). MGE Power West Campus is 100% owned by MGE Power and MGE Power is 100% owned by MGE Energy. MGE Energy's proportionate share of the equity and net income (through its wholly owned subsidiary MGE Power) of MGE Power West Campus is classified within the MGE financial statements as minority interest. As of December 31, 2007 and 2006, MGE Power had invested (net of dividends) $15.6 million and $28.0 million in MGE Power West Campus, respectively. For the years ended December 31, 2007, 2006, and 2005, MGE Power had earned $7.7 million, $7.8 million, and $5.4 million, net of tax, from its interest in MGE Power West Campus, respectively. This amount is recorded as minority interest expense, net of tax, on MGE's consolidated statement of income.
b.
MGE Transco.
On October 28, 2005, MGE Transco was formed. On this date, MGE transferred its investment in ATC to MGE Transco and received an ownership interest in MGE Transco. During 2005 and 2006, MGE Energy contributed a total of $3.3 million to MGE Transco in exchange for an ownership interest. At December 31, 2007, MGE is the majority owner and MGE Energy is the minority owner of this entity. MGE Energy's proportionate share of the equity and net income of MGE Transco is classified within the MGE financial statements as minority interest. As of December 31, 2007 and 2006, MGE Energy had invested (net of dividends) $2.2 million and $2.9 million in MGE Transco. For the years ended December 31, 2007, 2006, and 2005, MGE Energy had earned $0.5 million, $0.4 million, and less than $0.1 million, net of tax, from its interest in MGE Transco, respectively. These amounts are recorded as minority interest expense, net of tax, on MGE's consolidated statement of income.
c.
MGE Power Elm Road.
Similar to MGE Power West Campus, MGE Power Elm Road is not a subsidiary of MGE; however, it has been consolidated in the consolidated financial statements of MGE, due to the adoption of FIN 46(R) (see Footnote 2). MGE Power Elm Road is 100% owned by MGE Power and MGE Power is 100% owned by MGE Energy. MGE Energy's proportionate share of the equity and net income (through its wholly owned subsidiary MGE Power) of MGE Power Elm Road is classified within the MGE financial statements as minority interest. As of December 31, 2007 and 2006, MGE Power had invested $93.4 million and $50.1 million in MGE Elm Road. For the years ended December 31, 2007, 2006, and 2005, MGE Power recognized earnings of $2.6 million, $1.4 million, and less than $0.1 million, net of tax, from its interest in MGE Power Elm Road, respectively. These amounts are recorded as minority interest expense, net of tax, on MGE's consolidated statement of income.
9.
Long-Term Debt.
a.
6.247% Medium-Term Notes - MGE and MGE Energy.
On September 19, 2007, MGE issued $25 million of 6.247% medium-term notes due September 15, 2037. The notes were issued pursuant to an Indenture dated as of September 1, 1998, between MGE and The Bank of New York Trust Company, N.A. (as successor to Bank One, N.A.), as Trustee. The notes are unsecured.
The net proceeds from the sale of the notes were used to refinance $15 million of MGE's 7.49% medium-term notes which became due on September 20, 2007, and short-term indebtedness. The notes carry an interest rate of 6.247% per annum, which is payable semiannually on March 15 and September 15 of each year, commencing on March 15, 2008. The notes are redeemable at any time at MGE's option at a redemption price equal to the greater of (i) 100% of the principal amount of the notes to be redeemed, plus accrued interest to the redemption date, or (ii) the discounted present value of the remaining scheduled payments of principal and interest on the Notes to be redeemed (as provided in the Notes), plus accrued interest to the redemption date.
On July 20, 2007, MGE had entered into a $25 million swap lock with a financial institution to fix a portion of the interest rate related to the aforementioned debt issuance. Under the terms of the swap lock, MGE agreed to pay a fixed rate of 5.813% per annum and receive from the financial institution a floating rate equal to six months U.S. LIBOR (London Interbank Offered Rate). On September 14, 2007, MGE terminated the swap lock and was obligated to make a $1.7 million payment as a result of the difference between these two rates. Of this amount, $1.5 million of the cost has been deferred on the December 31, 2007, balance sheet as a regulatory asset in accordance with the provisions of SFAS 71. This amount is expected to be collected in rates ratably over the term of the 6.247% medium-term notes beginning in 2010. The remaining $0.2 million of the cost of this instrument is reflected as an expense in MGE and MGE Energy's income statement for the twelve months ended December 31, 2007.
b.
5.25% Medium-Term Notes - MGE and MGE Energy.
On December 29, 2006, MGE issued $30 million in 5.25% medium-term notes due January 15, 2017. The notes were issued pursuant to an Indenture dated as of September 1, 1998, between MGE and The Bank of New York Trust Company, N.A., (as successor to Bank One, N.A.), as Trustee. The notes are unsecured. MGE used the net proceeds from the sale of the Notes to repay short-term indebtedness, namely, commercial paper.
The notes carry an interest rate of 5.25% per annum, which is payable semiannually on January 15 and July 15 of each year, commencing on July 15, 2007. The notes are redeemable at any time at MGE's option at a redemption price equal to or greater of (i) 100% of the principal amount of the Notes to be redeemed, plus accrued interest to the redemption date, or (ii) the discounted present value of the remaining scheduled payments of principal and interest on the notes to be redeemed (as provided in the notes), plus accrued interest to the redemption date.
c.
5.68% and 5.19% Senior Secured Notes - MGE and MGE Energy.
The 5.68% and the 5.19% senior secured notes require that MGE Power West Campus maintain a projected debt service coverage ratio of not less than 1.25 to 1.00, and debt to total capitalization ratio of not more than .65 to 1.00.
The debt is subject to a collateral assignment of lease payments that MGE will be making to MGE Power West Campus for use of the cogeneration facility.
d.
First Mortgage Bonds - MGE Energy and MGE.
MGE's utility plant is subject to the lien of its Indenture of Mortgage and Deed of Trust, under which its First Mortgage Bonds are issued.
MGE's outstanding First Mortgage Bonds contain certain debt covenant restrictions with respect to dividends. The covenant restricts the payment of dividends or any other distribution or purchase of shares to the existing earned surplus (retained earnings) on MGE common stock. MGE's earned surplus exceeded all such payments for all years covered under this report.
e.
Other Long-Term Debt - MGE Energy and MGE.
MGE has $30 million of 6.02% medium-term notes due in 2008, $15 million of 6.58% medium-term notes due in 2012, and $19.3 million of 4.875% Industrial Development Revenue Bonds, refinanced in 2012, due in 2027.
The indenture under which the medium-term notes were issued provides that they will be entitled to be equally and ratably secured in the event that MGE issues any additional First Mortgage Bonds.
Below is MGE Energy's and MGE's aggregate maturities for all long-term debt for years following the December 31, 2007, balance sheet.
(In thousands)
Amount
$30,000
-
-
-
34,300
Future years
199,200
Total*
$263,500
*Includes $30 million and $20 million maturity for MGE Power West Campus, which is consolidated with MGE's debt in accordance with FIN 46R (see Footnote 2).
10.
Notes Payable to Banks, Commercial Paper, and Lines of Credit - MGE Energy and MGE.
For short-term borrowings, MGE generally issues commercial paper (issued at the prevailing discount rate at the time of issuance), which is supported by unused bank lines of credit. On December 21, 2005, MGE entered into an amended and restated unsecured revolving credit facility under which it may borrow up to $55 million from a group of lenders. The credit facility is available for the issuance of letters of credit. The credit facility matures December 21, 2010. Interest rates on borrowings under the credit facility are based on either prime or LIBOR plus an adder based on the senior unsecured credit rating of MGE. Interest is payable monthly. The credit agreement requires MGE to maintain a ratio of consolidated debt to consolidated total capitalization not to exceed a maximum of 65%. The ratio calculation excludes assets, liabilities, revenues and expenses included in MGE's financial statements as a result of the application of FIN 46(R).
On August 1, 2007, MGE entered into a $20 million unsecured line of credit, which expires on March 31, 2008. This facility carries an interest rate based on LIBOR plus an applicable margin of 0.40% per annum. Interest is payable monthly commencing on September 1, 2007, and will be computed on any unpaid principal at the date of each borrowing. The line of credit will be used as a backup facility to MGE's commercial paper program. No borrowings are outstanding under this facility at this time. Borrowings may be made and repaid at any time during the term of the note and must be repaid upon the earlier of the maturity of the note or the occurrence of an event of default. Events of default include failures to pay scheduled principal or interest and certain bankruptcy-related events, in each case subject to applicable cure periods.
On December 21, 2005, MGE Energy entered into a five-year unsecured revolving credit facility under which it may borrow up to $80 million from a group of lenders. MGE Energy has the right to request an increase in the aggregate commitment amount up to a maximum amount of $20 million so long as no default or unmatured default exists. Interest rates on borrowings under the credit facility are based on either prime or LIBOR plus an adder based on the senior unsecured credit rating of MGE. Interest is payable monthly. Amounts borrowed may be repaid and reborrowed from time to time until maturity. The credit agreement requires MGE Energy to maintain a ratio of consolidated debt to consolidated total capitalization not to exceed a maximum of 65%.
Information concerning short-term borrowings for the past three years is shown below:
11.
Fair Value of Financial Instruments - MGE Energy and MGE.
At December 31, 2007 and 2006, the carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of MGE's long-term debt is based on quoted market prices at December 31. The estimated fair market value of MGE Energy's and MGE's financial instruments are as follows:
*Includes long-term debt due within one year.
See Footnotes 4 and 16 for a discussion of the fair value related to investments and derivatives, respectively.
12.
Income Taxes.
a.
MGE Energy Income Taxes.
MGE Energy files a consolidated federal income tax return that includes the operations of all subsidiary companies. The consolidated income tax provision consists of the following provision (benefit) components for the years ended December 31:
(In thousands)
Current payable:
Federal
$22,482
$16,169
$ 6,025
State
5,033
4,921
3,406
Net-deferred:
Federal
4,565
9,795
State
1,105
Amortized investment tax credits
(410)
(432)
(460)
Total income tax provision
$27,855
$25,899
$19,871
MGE Energy's consolidated income tax provision differs from the amount computed by applying the statutory federal income tax rate to income before income taxes, as follows:
Statutory federal income tax rate
35.0%
35.0%
35.0%
Amortized investment tax credits
(0.5)%
(0.6)%
(0.9)%
State income taxes, net of federal benefit
4.8%
5.0%
5.3%
Credit for electricity from wind energy
(0.6)%
(0.5)%
(0.7)%
Medicare subsidy
(0.4)%
(0.5)%
(0.4)%
Domestic manufacturing deduction
(0.6)%
(0.5)%
-
Other, individually insignificant
(1.4)%
-
(0.1)%
Effective income tax rate
36.3%
37.9%
38.2%
The significant components of deferred tax liabilities (assets) that appear on MGE Energy's consolidated balance sheets as of December 31 are as follows:
(In thousands)
Property-related
$105,527
$102,146
Investment in ATC
15,171
14,798
Bond transactions
2,274
2,416
Pension expense
1,781
Unfunded pension and other postretirement liability
13,514
15,286
Tax deductible prepayments
6,579
6,288
Other
7,929
5,671
Gross deferred income tax liabilities
152,775
147,446
Accrued expenses
(13,605)
(9,702)
Retirement benefits, other than pension
(8,105)
(7,102)
Deferred tax regulatory account
(3,479)
(4,043)
Unfunded pension and other postretirement liability
(14,826)
(18,954)
Other
(1,580)
(2,394)
Gross deferred income tax assets
(41,595)
(42,195)
Less valuation allowance
Net deferred income tax assets
(41,229)
(41,829)
Deferred income taxes
$111,546
$105,617
The valuation allowance reduces MGE Energy's deferred tax assets for state carryforward losses to estimated realizable value due to the uncertainty of future income estimates in various state tax jurisdictions.
For tax purposes, as of December 31, 2007, MGE Energy had approximately $7.5 million of state tax net operating loss deductions that expire between 2011 to 2019 if unused.
b.
MGE Income Taxes.
MGE Energy files a consolidated federal income tax return. The subsidiaries calculate their respective federal income tax provisions as if they were separate taxable entities.
On a separate company basis, the components of MGE's income tax provision are as follows for the years ended December 31:
(In thousands)
Current payable:
Federal
$21,899
$16,468
$ 5,669
State
4,882
4,910
3,314
Net-deferred:
Federal
4,241
9,791
State
1,104
Amortized investment tax credits
(410)
(432)
(460)
Total income tax provision
$27,085
$25,785
$19,418
MGE's income tax provision on a separate company basis differs from the amount computed by applying the statutory federal income tax rate to income before minority interest and income tax provision as follows:
Statutory federal income tax rate
35.0%
35.0%
35.0%
Amortized investment tax credits
(0.5)%
(0.6)%
(0.9)%
State income taxes, net of federal benefit
4.7%
5.0%
5.3%
Credit for electricity from wind energy
(0.6)%
(0.5)%
(0.7)%
Medicare subsidy
(0.4)%
(0.5)%
(0.4)%
Domestic manufacturing deduction
(0.6)%
(0.5)%
-
Other, individually insignificant
(1.4)%
-
(0.2)%
Effective income tax rate
36.2%
37.9%
38.1%
The significant components of deferred tax liabilities (assets) that appear on MGE's consolidated balance sheets as of December 31 are as follows:
(In thousands)
Property-related
$105,527
$102,146
Investment in ATC
15,171
14,798
Bond transactions
2,274
2,416
Pension expense
1,781
Unfunded pension and other postretirement liability
13,514
15,286
Tax deductible prepayments
6,579
6,288
Other
7,473
5,451
Gross deferred income tax liabilities
152,319
147,226
Accrued expenses
(13,362)
(9,679)
Retirement benefits, other than pension
(8,105)
(7,102)
Deferred tax regulatory account
(3,479)
(4,043)
Unfunded pension and other postretirement liability
(14,826)
(18,954)
Other
(1,836)
(2,394)
Gross deferred income tax assets
(41,608)
(42,172)
Less valuation allowance
Net deferred income tax assets
(41,242)
(41,806)
Deferred income taxes
$111,077
$105,420
The valuation allowance reduces MGE's deferred tax assets for state carryforward losses to estimated realizable value due to the uncertainty of future income estimates in various state tax jurisdictions.
For tax purposes, as of December 31, 2007, MGE had approximately $7.5 million of state tax net operating loss deductions that expire between 2011 to 2019 if unused.
c.
FIN 48 - MGE Energy and MGE.
MGE Energy and MGE adopted the provisions of FIN 48 on January 1, 2007. At the date of adoption, MGE Energy and MGE reclassified $0.3 million of accrued income taxes under prior accounting standards to its long term FIN 48 tax liability account. Additionally in the adoption accounting, MGE Energy and MGE reclassified $0.1 million of accrued interest under prior accounting standards to its FIN 48 interest payable account. These adjustments had no impact on retained earnings. MGE and MGE Energy have elected to recognize interest accrued related to unrecognized tax benefits in interest expense and penalties in operating expenses. During the year ended December 31, 2007, less than $0.1 million of interest expense was recognized and no penalties were incurred.
Under FIN 48, the difference between the tax benefit amount taken on prior year tax returns, or expected to be taken on a current year tax return, and the tax benefit amount recognized in the financial statements is an unrecognized tax benefit. A tabular reconciliation of unrecognized tax benefits and interest under FIN 48 from January 1, 2007 (date of adoption) to December 31, 2007, is as follows:
(In thousands)
Tax
Interest
Amounts of unrecognized tax benefits, January 1, 2007, upon adoption of FIN 48 (Amounts are for years prior to 2007)
$
$
Settlements with taxing authorities paid in 2007
(186)
(24)
Reductions to beginning balance of unrecognized tax benefits as a result of settlements with taxing authorities
(91)
(75)
Amount of unrecognized tax benefits from 2007 tax positions
-
Unrecognized tax benefits, December 31, 2007
$
$ -
Unrecognized tax benefits are liabilities shown with Other Deferred Liabilities on the December 31, 2007, balance sheets.
The unrecognized tax benefits recorded upon adoption of FIN 48 related to MGE's state tax matters that were under examination. In 2007, MGE reached a settlement regarding all state tax matters identified in the adoption of FIN 48. Unrecognized tax benefits arising in 2007 relate mainly to federal permanent differences and tax credits, the realization of which would not significantly impact the effective tax rate. The unrecognized tax benefits at December 31, 2007, are not expected to significantly increase or decrease within the next twelve months.
Wisconsin requires each corporation within a consolidated group to file a separate tax return.
The following table shows tax years that remain subject to examination by major jurisdiction:
Taxpayer
Open Years
MGE Energy and consolidated subsidiaries in federal return
through 2007
MGE Energy Wisconsin separate corporation return
through 2007
MGE Wisconsin separate corporation return
through 2007
13.
Pension Plans and Other Postretirement Benefits - MGE Energy and MGE.
MGE maintains qualified and nonqualified pension plans, health care and life insurance benefits, and two defined contribution 401(k) benefit plans for its employees and retirees. MGE's costs for the 401(k) plans were $1.0 million in both 2007 and 2006, and $0.9 million in 2005. A measurement date of December 31 is utilized for all pension and postretirement benefit plans.
MGE employs 247 individuals who are covered by a collective bargaining agreement with Local Union No. 2304 of the IBEW, 102 employees who are covered by a collective bargaining agreement with Local Union No. 39 of the Office and Professional Employees International Union (OPEIU), and 5 employees covered by a collective bargaining agreement with USW Local Union Unit No. 2-0111 (USW). On May 12, 2006, the OPEIU employees ratified a new three-year labor agreement; on September 21, 2006, the IBEW employees ratified a new three-year labor agreement; and on October 11, 2006, the USW also ratified a new three-year labor agreement. Pursuant to these agreements, the OPEIU, IBEW, and USW have agreed to defined contribution pension plans for employees hired after December 31, 2006. All new nonunion employees hired after December 31, 2006, have also been enrolled in the defined contribution pension plan, rather than the defined benefit pension plan previously in place for existing nonunion employees.
In September 2006, the FASB issued SFAS 158, Employers' Accounting for Pension and Other Postretirement Plans. This pronouncement requires the recognition of the funded status of defined benefit and postretirement benefit plans on the balance sheet. Additionally, this statement requires that certain previously disclosed but unrecognized costs be recognized on the balance sheet. The provisions of this statement were adopted by MGE as of December 31, 2006, and are reflected in the following disclosure.
a.
Benefit Obligations.
The accumulated benefit obligation for the defined benefit pension plan at the end of 2007 and 2006 was $153.3 million and $150.4 million, respectively. The accumulated benefit obligation for the other postretirement benefits at the end of 2007 and 2006, was $59.3 million and $50.0 million, respectively.
The following table shows assumed health care cost trend rates at December 31:
Health care cost trend rate assumed for next year
8%
8%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)
5%
5%
Year that the rate reaches the ultimate trend rate
The assumed health care cost trend rates have a significant effect on the amounts reported for the health care plans.
The following table shows how an assumed 1% increase or 1% decrease in health care cost trends could impact postretirement benefits in 2007 dollars:
(In thousands)
1% Increase
1% Decrease
Effect on other postretirement benefit obligation
$8,341
$(7,114)
On December 8, 2003, the "Medicare Prescription Drug, Improvement and Modernization Act of 2003" (the Act) was signed into law authorizing Medicare to provide prescription drug benefits to retirees. The Act introduced a prescription drug benefit under Medicare as well as a Federal subsidy to sponsors of retiree health care benefit plans that provide a benefit that is at least actuarially equivalent to the Medicare prescription drug benefit. Management believes the prescription drug benefit provided under MGE's postretirement benefit plans is at least actuarially equivalent to the Medicare prescription drug benefit. In response to the enactment of the Act, on May 19, 2003, FSP 106-2, Accounting and Disclosure Requirements Related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003, was issued, resulting in a remeasurement of its postretirement benefits and a remeasurement of its postretirement plans' assets and APBO as of January 1, 2004. For the year ended December 31, 2007, the subsidy due to MGE was $0.1 million.
b.
Plan Assets.
The expected long-term rate of return on the pension plan assets was 9.0% in both 2007 and 2006.
c.
Explanation of Long-Term Rate of Return.
MGE employs a building-block approach in determining the expected long-term rate of return for asset classes. Historical markets are studied and long-term historical relationships among asset classes are analyzed, consistent with the widely accepted capital market principle that assets with higher volatility generate a greater return over the long run. Current market factors such as interest rates and dividend yields are evaluated before long-term capital market assumptions are determined.
The expected long-term nominal rate of return for plan assets is primarily a function of expected long-term real rates of return for component asset classes and the plan's target asset allocation in conjunction with an inflation assumption. Consideration is also given to diversification, rebalancing, and active portfolio management. Peer data and historical returns are reviewed to check for appropriateness.
The asset allocation for MGE's pension plans at the end of 2007 and 2006, and the target allocation for 2008, by asset category, follows:
d.
Investment Strategy.
MGE employs a total return investment approach whereby a mix of equities, fixed income, and real estate investments are used to maximize the expected long-term return of plan assets for a prudent level of risk. Risk tolerance is established through careful consideration of plan liabilities, plan-funded status, and corporate financial condition. The investment portfolio contains a diversified blend of equity, fixed income, and real estate investments. Target asset allocations are as follows: 50% United States equity, 25% non-United States equity, 15% fixed income, and 10% real estate. Investment risk is measured and monitored on an ongoing basis through periodic investment portfolio reviews and liability measurements.
e.
Other Postretirement Benefits.
The fair value of plan assets for these postretirement benefit plans is $16.5 million and $15.3 million at the end of 2007 and 2006, respectively. The expected long-term rate of return on these plan assets was 7.85% and 7.78% in 2007 and 2006.
Of the above amounts, $13.5 million and $12.3 million at the end of 2007 and 2006, respectively, were held in the master pension trust and are allocable to postretirement health expenses. The target asset allocation and investment strategy for the portion of assets held in the master pension trust are the same as that explained for MGE's pension plans.
The remainder of postretirement benefit assets are held either in an insurance continuance fund for the payment of retiree life benefits or a health benefit trust for payment of retiree health claims. There is no formal target asset allocation for these assets, but the intent is to seek interest income and maintain stability of principal.
f.
Funded Status.
The funded status at the end of the year, and the related amounts recognized on the Consolidated Balance Sheet are as follows:
At December 31, 2007, MGE and MGE Energy included a $0.6 million current liability, a $74.1 million long-term liability, and a $33.7 million regulatory asset in the balance sheet to properly reflect the unfunded status of the plans.
At December 31, 2006, MGE and MGE Energy's balance sheets included a $0.6 million current liability, a $76.1 million long-term liability, and a $38.1 million regulatory asset to properly account for the unfunded status of the plan.
(In thousands)
Pension
Benefits
Other
Postretirement
Benefits
Amounts recognized as regulatory asset
Net actuarial loss
$17,178
$9,562
Prior service cost
3,197
1,277
Transition obligation
2,172
$20,661
$13,011
The qualified pension plans are 90% funded at December 31, 2007 (computed as a percent of projected benefit obligation).
The projected benefit obligation and fair value of plan assets for pension plans with a projected benefit obligation in excess of plan assets at December 31, 2007 and 2006, were as follows:
The projected benefit obligation, accumulated benefit obligation and fair value of plan assets for pension plans with an accumulated benefit obligation in excess of plan assets at December 31, 2007 and 2006, were as follows:
g.
Expected Cash Flows.
There are no required contributions for the 2007 plan year, but MGE may elect discretionary deductible contributions depending upon its valuation results and cash flow from operations. In 2007, MGE made $6.3 million in employer contributions to its pension and postretirement plans related to the 2006 and 2007 plan years. MGE has made a $5.4 million contribution in 2008 related to the 2007 plan year. See Footnote 27 for further discussion. These payments are made strictly at MGE's discretion as there are no contributions required for the 2007 plan year.
h.
Benefit Payments.
The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid as follows:
i.
Net Periodic Cost.
MGE has elected to recognize the cost of its transition obligation (the accumulated postretirement benefit obligation as of January 1, 1993) by amortizing it on a straight-line basis over 20 years.
On September 21, 2006, certain voluntary termination benefits were awarded to International Brotherhood of Electrical Workers (IBEW) who may be impacted by the discontinuance of coal use at Blount. These employees were offered certain supplemental early retirement benefits. As of December 31, 2007, four of the union employees declared their intent to retire early. The liability associated with these special termination benefits is reflected at the time they actually retire.
Additionally, during the twelve months ended December 31, 2006, a plan curtailment for MGE's bargaining pension and postretirement plans as defined in SFAS 88, Employers' Accounting for Settlements and Curtailments of Defined Benefit Pension Plans and for Termination Benefits had occurred. For the twelve months ended December 31, 2006, this resulted in a $0.1 million curtailment loss for the bargaining pension plan and a $0.2 million curtailment gain for the bargaining other postretirement plan, respectively. The net impact of the curtailment was recorded as a decrease to the regulatory asset established for the exit plan.
Assumed health care cost trend rates have a significant effect on the amounts reported for the health care plans. A 1% change in the assumed health care cost trend rates would have had the following effect:
(In thousands)
1% Increase
1% Decrease
Effect on total service and interest cost components
$809
$(684)
During the third quarter of 2006, President Bush signed into law the Pension Protection Act of 2006, which will affect the manner in which companies, including MGE and MGE Energy, administer their pension plans. This legislation will require companies to, amongst other things, increase the amount by which they fund their pension plans, pay higher premiums to the Pension Benefit Guaranty Corporation if they sponsor defined benefit plans, amend plan documents and provide additional plan disclosures in regulatory filings and to plan participants. This legislation will be effective as of January 1, 2008. The U.S. Treasury Department's interim guidance indicates that further guidance is forthcoming. MGE does not expect significant changes in expected cash flows as a result of the Act. Absent changes in plan design as a result of the Act, the Act is not expected to materially impact MGE and MGE Energy's results of operations.
14.
Share-Based Compensation - MGE Energy and MGE.
The MGE Energy Board approved a Performance Unit Plan (the "Plan") on December 15, 2006. Under the Plan, eligible participants may receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the set performance period. Per the Plan's provisions, these awards are subject to a prescribed vesting schedule and must be settled in cash. Accordingly, no new shares of common stock will be issued in connection with the Plan. MGE and MGE Energy have adopted the provisions of SFAS 123R, Share-Based Payment. This guidance establishes standards for the accounting of transactions in which an entity exchanges equity instruments for goods and services. Additionally, this standard addresses the accounting for transactions in which an entity incurs liabilities in exchange for goods or services that are based on the fair value of the entity's equity instruments.
On January 1, 2007, 22,479 units were granted based on the MGE Energy December 31, 2006, closing stock price. These units are subject to either a four or five year graded vesting schedule. Based on the provisions of SFAS 123R, on the grant date, MGE Energy and MGE measured the cost of the employee services received in exchange for the award based on current market value of MGE Energy common stock. The fair value of the awards on the grant date was $1.0 million. The fair value of the awards has been subsequently re-measured at December 31, 2007. Changes in fair value as well as the original grant have been recognized as compensation cost. Because this amount will be remeasured throughout the vesting period, the compensation cost is subject to variability.
For nonretirement eligible employees, stock based compensation costs are accrued and recognized using the graded vesting method. Pursuant to the provisions of SFAS 123R and the terms of the plan, compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule, are recognized on an abridged horizon also using the graded vesting method.
During the twelve months ended December 31, 2007, MGE recorded $0.3 million in compensation expense as a result of this plan. No compensation expense was recognized in 2005 and 2006 as there had not been any grants during those years. No forfeitures or cash settlements occurred during the aforementioned period. No awards were fully vested at December 31, 2007.
On January 18, 2008, 18,538 units were granted based on the MGE Energy closing stock price as of that date.
15.
Regional Transmission Organizations - MGE Energy and MGE.
On April 1, 2005, the Midwest ISO implemented its bid-based energy market. Midwest ISO is a FERC approved RTO that is required to provide real-time energy services and a market based mechanism for congestion management. MGE is a participant in this market. On April 1, 2005, MGE began offering substantially all of its generation on the Midwest ISO market and purchasing much of its load requirement from the Midwest ISO market in accordance with the Midwest ISO Tariff.
Additionally, on May 1, 2004, MGE became a member of PJM. PJM is also an RTO. PJM is a neutral and independent party that coordinates and directs the operation of the region's transmission grid, administers a competitive wholesale electricity market, and plans regional transmission expansion improvements to maintain grid reliability and relieve congestion. MGE has two purchase power agreements, for a total of 65 MW, that are impacted by this market.
MGE reports on a net basis transactions on the Midwest ISO and PJM markets in which it buys and sells power within the same hour to meet electric energy delivery requirements. This treatment resulted in a $157.3 million, $154.4 million, and $122.2 million reduction to sales for resale and purchased power expense for the years ended December 31, 2007, 2006, and 2005, respectively.
16.
Derivative and Hedging Instruments - MGE Energy and MGE.
As part of our regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to interest rates, commodity prices, and gas margin. MGE evaluates its derivative contracts in accordance with SFAS No. 133, Accounting for Derivative Instruments and Hedging Activities, as amended and interpreted. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts in which this exclusion can not be applied, SFAS No. 133 requires MGE Energy and MGE to recognize all derivatives in the consolidated balance sheets at fair value, with changes in the fair value of derivative instruments to be recorded in current earnings or deferred in accumulated other comprehensive income (loss), depending on whether a derivative is designated as, and is effective as, a hedge and depending on the type of hedge transaction. MGE's derivative activities are conducted in accordance with its electric and gas risk management program.
If the derivative qualifies for regulatory deferral subject to the provisions of SFAS No. 71, Accounting for the Effects of Certain Types of Regulation, the derivatives are marked to fair value pursuant to SFAS No. 133 and are offset with a corresponding regulatory asset or liability.
During 2007 and 2006, MGE purchased and sold exchange traded and over the counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on transmission paths in the Midwest ISO market, at December 31, 2007, MGE holds 2008 FTRs. An FTR is a financial instrument that entitles the holder to a stream of revenues or charges based on the differences in hourly day ahead energy prices between two points on the transmission grid.
At December 31, 2007 and 2006, the cost basis of these instruments exceeded their fair value by $0.3 million and $3.1 million, respectively. These financial instruments will expire throughout 2008. Accordingly, the fair value of these instruments is reflected as a current regulatory asset and current deferred liability. Depending on the nature of the instrument, the gain or loss associated with these transactions will be reflected as natural gas purchased, fuel for electric generation, or purchased power expense in the delivery month applicable to the instrument.
During 2007, MGE has also entered into futures and basis swaps to take advantage of physical and financial arbitrage opportunities between supply basins and pricing spreads between future months' gas supply. Under the incentive mechanism within the PGA clause, MGE shareholders have the ability to receive 50% of the benefits or loss from these deals if certain thresholds are achieved. At December 31, 2007 and 2006, these positions were in an unrealized gain position of $0.2 million and $0.5 million, respectively. Of this amount, 50% is reflected in other comprehensive income and 50% is reflected as a current regulatory asset. These instruments all expire in 2008.
MGE has also entered into a ten-year purchased power agreement which provides MGE with firm capacity and energy beginning June 12, 2012, and ending on May 31, 2022 (the "base term"). The agreement also allows MGE the option to purchase power during a period of time preceding the base term as well as an option to extend the contract after the base term. The agreement is a derivative contract and is recognized at its fair value on the balance sheet. The fair value of the contract at December 31, 2007, is $0.1 million. Also, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory liability.
On September 26, 2007, MGE entered into a non-exchange traded HDD collar. This agreement extends from January 2008 until March 2008 and has a premium of $0.2 million. Under this agreement, MGE is subject to a floor (3,450 HDD) and a ceiling (3,600 HDD), based on forecasted heating degree days during the indicated period. If heating degree days are below the floor, MGE is entitled to receive a payment, and if actual heating degree days exceed the ceiling, MGE is obligated to make a payment. Any payment or receipt is limited to $1.3 million. MGE will account for the HDD collar using the intrinsic value method pursuant to the requirements of EITF 99-2, Accounting for Weather Derivatives.
On November 1, 2006, MGE entered into a non-exchange traded weather derivative. This agreement extended from January 2007 until March 2007. This agreement had a premium of $0.3 million. Because heating degree days were in between the prescribed floor and ceiling, no additional gain or loss beyond the premium was recorded.
In October 2005, MGE also entered into two non-exchange traded weather derivatives. The first agreement extended from November 2005 until December 2005. This agreement had a premium of $0.1 million and resulted in a loss of less than $0.1 million. The second agreement extended from January 2006 until March 2006. This agreement also had a premium of $0.1 million and resulted in a gain of $0.6 million.
Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines.
17.
Rate Matters - MGE Energy and MGE.
a.
Rate proceedings.
On December 14, 2007, the PSCW authorized MGE to increase 2008 electric rates by 4.8% or $16.2 million and increase gas rates by 2.8% or $7.8 million. The electric increase will cover costs for MGE's new wind energy projects, statewide energy efficiency renewable energy programs, transmission improvements by ATC, and accelerated costs to discontinue coal use at the Blount Station. In addition to funding the statewide energy programs, the natural gas rate increase covered costs for area gas construction projects needed to accommodate customer growth. Authorized return on common stock equity was set at 10.8% based on 57.4% utility common equity. The PSCW order allows MGE to eliminate a base rate case proceeding for 2009 and request a limited reopener for certain items. The costs MGE can update in its limited reopener include monitored fuel rules costs, ERGS lease payments and operation and maintenance costs as a result of ERGS Unit 1 becoming operational, and ATC network service fees.
Pursuant to the provisions of this rate order, the fuel rules bandwidth effective January 1, 2008, will be plus or minus 2%. See below for further description of fuel rules.
On December 22, 2006, the PSCW approved a limited scope rate case reopener related to MGE's current electric rates. This order approved an update to MGE's electric fuel costs monitored under the fuel rules, an updated estimate of the 2007 Elm Road carrying costs, and a request for recovery of increased ATC-related transmission costs through December 31, 2007. This order will result in a net 0.15% decrease, on average, in retail electric rates for 2007. The PSCW also approved the recovery of 100% AFUDC on the Top of Iowa III wind project beginning in November 2006 and continuing until construction on the project ceases. The fuel rules bandwidth established by this order and effective January 1, 2007, was plus or minus 2%.
On December 12, 2005, the PSCW authorized MGE to increase 2006 electric revenues by $35.9 million and to increase gas revenues by $3.8 million. The increase to electric revenues is intended to cover increased fuel and purchased power costs and the costs of additional facilities needed to meet the rising electric and gas needs of our customers. Approximately $3.8 million of the increase in electric revenues relates to the recovery of the carrying costs for Elm Road.
On December 21, 2004, the PSCW authorized MGE to increase 2005 electric revenues by $27.4 million and to decrease 2005 gas revenues by $4.2 million. The increase to electric revenues is intended to cover rising fuel costs, commercial operation of WCCF, and increased transmission expenses.
b.
Fuel rules.
Actual electric fuel costs are subject to reconciliation to the amount approved by the PSCW in MGE's rate order covering the applicable period. Known as "fuel rules," the process can produce a fuel surcharge for MGE or require MGE to make a refund in the form of a credit, to the extent that the actual fuel costs are outside a range higher or lower than the level authorized by the PSCW in that rate order.
Under fuel rules effective January 1, 2007, MGE could apply for a fuel surcharge if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Conversely, MGE could have been required to provide a fuel credit to its customers if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order.
On April 26, 2007, the PSCW approved a $0.00339 per kWh interim fuel surcharge on MGE's electric rates to cover increased fuel and purchased power expenses. Pursuant to the provisions of the fuel surcharge, MGE's electric revenues resulting from this surcharge were subject to refund and interest at 11%. On August 31, 2007, MGE received a final decision which reduced the fuel surcharge from $0.00339 per kWh to $0.00242 per kWh. These surcharges resulted in a gross increase to electric rates of $6.9 million for the twelve months ended December 31, 2007. For the interim period April 26, 2007, through August 31, 2007, the difference between the interim surcharge and the final surcharge was required to be refunded to customers. Accordingly, on October 6, 2007, a refund of $1.3 million was applied to customers' accounts.
As a result of a decrease in electric fuel costs during the twelve months ended December 31, 2006, as compared to those in its latest order, a interim fuel credit was approved by the PSCW. To account for this credit, MGE recorded a $19.1 million reduction to other electric revenues. This reduction to other electric revenues reflected MGE's estimated obligation under the interim fuel credit and subject to refund provision implemented by the PSCW during 2006. During the year ended December 31, 2006, $16.8 million had been credited to electric customers. An additional $2.4 million (includes interest) was applied to customers' accounts in April 2007.
During the twelve months ended December 31, 2005, MGE was subject to a 3% bandwidth under the fuel rules. As a result of the natural disasters that occurred in the Gulf of Mexico and the related damage to the energy infrastructure, natural gas prices in 2005 rose to abnormally high levels. These increased prices caused MGE's fuel costs during the fourth quarter of 2005 to exceed the upper bandwidth limit. On November 11, 2005, the PSCW approved an interim rate order granting MGE's request for a fuel surcharge on its electric rates to cover increased fuel and purchased power costs. Between November 11, 2005, and December 31, 2005, MGE recorded $1.7 million in revenue under this interim order.
18.
Commitments.
a.
Coal Contracts - MGE Energy and MGE.
MGE has coal supply contracts related to the Blount plant. As of December 31, 2007, total coal commitments related to the Blount plant are estimated to be $6.9 million for 2008. Fuel procurement for MGE's jointly owned Columbia and Elm Road plants are handled by Alliant and We Energies, respectively, the operating companies. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates. As of December 31, 2007, MGE's share of the total coal commitments for the Columbia and Elm Road plants are estimated to be $12.2 million in 2008, $15.9 million in 2009, $22.2 million in 2010, $5.2 million in 2011, and $4.2 million in 2012.
MGE's Blount plant also utilized paper-derived fuel. MGE has a fixed commitment with a supplier of this alternative fuel. Commitments under this arrangement are $0.2 million per year for 2008, 2009, 2010, and 2011.
b.
Purchased Power Contracts - MGE Energy and MGE.
MGE has several purchase power agreements to help meet future electric supply requirements. As of December 31, 2007, MGE's total commitments for energy and purchase power agreements for capacity are estimated to be $9.1 million in 2008, $9.2 million in both 2009 and 2010, $9.3 million in 2011, and $16.8 million in 2012. Management expects to recover these costs in future customer rates.
On September 21, 2007, MGE entered into a ten-year purchase power agreement which provides MGE with firm capacity, energy, and a pro-rata share of the counterparty's rights to renewable attributes beginning on June 1, 2012, and ending on May 31, 2022 (the "base term"). This agreement obligates MGE to purchase a minimum of 50 MW of capacity each year and a fixed amount of energy. Pursuant to the terms of this agreement, MGE has the option to extend the ten year term and/or purchase additional energy and capacity during the base term. MGE has not exercised either of these options at this time.
On April 23, 2007, MGE entered into a 20-year purchase power agreement for wind generation. Under this agreement, MGE has agreed to purchase 30 MW of wind power from the Top of Iowa II project which is being constructed in Iowa. This facility became operational in January 2008. MGE does not have any capacity payment commitments under this agreement. However, MGE is obligated to purchase its ratable share of the energy produced by the project.
On February 21, 2007, MGE and Invenergy signed an amendment to an existing purchase power agreement. Under this amended agreement, MGE has agreed to purchase approximately 15 MW of wind power at a facility to be constructed near Brownsville, Wisconsin for a 20-year term. Construction of this facility began in June 2007 and the facility is expected to be operational in early 2008. MGE does not have any capacity payment commitments under this agreement. However, MGE is obligated to purchase its ratable share of the energy produced by the unit.
c.
Natural Gas Transportation and Storage Contracts - MGE Energy and MGE.
MGE's natural gas transportation and storage contracts require fixed monthly payments for firm supply pipeline transportation and storage capacity. The pricing components of the fixed monthly payments for the transportation and storage contracts are established by FERC but may be subject to change. As of December 31, 2007, these payments are estimated to be $15.0 million in 2008, $14.1 million in 2009, $13.8 million in 2010, $9.0 million in 2011, and $0.7 million in 2012. MGE also has natural gas supply commitments. These commitments include market-based pricing. As of December 31, 2007, total natural gas supply commitments for 2008 are estimated to be $30.7 million. Management expects to recover these costs in future customer rates.
d.
Environmental - MGE Energy and MGE.
MGE is listed as a potentially responsible party for a site the EPA has placed on the national priorities Superfund list. The Lenz Oil site in Lemont, Illinois, was used for storing and processing waste oil for several years. This site requires clean up under the Comprehensive Environmental Response, Compensation and Liability Act. A group of companies, including MGE, is currently working on cleaning up the site. Management believes that its share of the final cleanup costs will not result in any materially adverse effects on MGE's operations, cash flows, or financial position. Insurance may cover a portion of the cleanup costs. Management believes that the cleanup costs not covered by insurance will be recovered in current and future rates. At December 31, 2007, MGE accrued a $0.1 million gross liability for this matter. The expected range of loss for this item is estimated to be between $0.1 million and $0.2 million.
Effective March 31, 2006, Wisconsin adopted the Energy Efficiency and Renewables Act that focuses on three areas: increasing the use of renewable energy in Wisconsin, promoting the development of renewable energy technologies, and strengthening the state's energy efficiency programs. This new legislation requires that by 2015, 10% of the state's electricity be generated from renewable resources. As part of this initiative, MGE plans to add additional renewable energy resources, such as wind farms. See Footnote 22 for discussion of agreements relating to the development of wind generation resources.
Air quality regulations promulgated by the EPA and DNR in accordance with the Federal Clean Air Act and the Clean Air Act Amendments of 1990 impose restrictions on emission of particulates, sulfur dioxide (SO2), nitrogen oxides (NOx), and other pollutants and require permits for operation of emission sources. These permits have been obtained by MGE and must be renewed periodically.
Various initiatives including, but not limited to, the Clean Air Interstate Rule (CAIR), Clean Air Mercury Rule (CAMR), maximum achievable control technology (MATC) standards, new source performance standards (NSPS) and existing and proposed state mercury emissions limits, are expected to result in significant additional operating and capital expenditures at Columbia. The Columbia operator's current estimates show that MGE's share of the capital expenditures required to comply with these environmental initiatives will be between $130 million and $200 million. According to current estimates, compliance with these initiatives is also expected to result in an increase to MGE's pro-rata share of Columbia's on-going operating expenses. The operator and MGE management are continuing to explore various alternatives to comply with these standards. Accordingly, actual capital expenditures may fall above or below the range provided. These standards and initiatives may also result in additional capital and operating expenditures at MGE's other generating facilities. MGE expects that the costs to comply with these standards will be fully recoverable through rates. The PSCW is permitting MGE to defer pre-certification and pre-construction costs related to compliance with CAIR and CAMR regulations at Columbia. Additionally, MGE is entitled to 100% AFUDC on the related pre-construction costs. As of December 31, 2007, MGE had incurred $0.8 million in costs at Columbia related to these initiatives.
As of December 31, 2007, Columbia entered into various contractual commitments with vendors for a small portion of the aforementioned expenditures. MGE is indirectly a party to these agreements as a result of its joint ownership of Columbia and is also contractually obligated, under the applicable ownership and operating agreements, with respect to any commitments made. MGE's share of these commitments will be $0.9 million for 2008. These costs are expected to be capitalized and included in the consolidated balance sheet of MGE.
e.
Chattel Paper Agreement and Other Guarantees - MGE Energy and MGE.
MGE makes available to qualifying customers a financing program for the purchase and installation of energy-related equipment that will provide more efficient use of utility service at the customer's property. MGE is party to a chattel paper purchase agreement with a financial institution under which it can sell or finance an undivided interest with recourse, in up to $10.0 million of the financing program receivables, until August 31, 2008. At December 31, 2007, 2006, and 2005, respectively, MGE had sold a $3.8 million, $4.8 million, and $5.1 million interest in these receivables, which MGE accounted for as a sale under SFAS No. 140, Accounting for Transfers and Servicing of Financial Assets and Extinguishment of Liabilities - a Replacement of FASB Statement No. 125. MGE retains the servicing responsibility for these receivables.
On January 1, 2007, MGE adopted SFAS 156, Accounting for Servicing of Financial Assets, an amendment of SFAS 140 . SFAS 156 clarified when to separately account for servicing rights, requires these rights to be initially measured at fair value, and provides the option to subsequently account for those servicing rights at either fair value or under the amortization method previously required under SFAS 140. MGE continues to account for servicing rights under the amortization method. Initial determination of the servicing asset fair value is based on the present value of the estimated future cash flows. The discount rate is based on the PSCW authorized weighted cost of capital.
MGE maintains responsibility for collecting and remitting loan payments from customers to the financial institution and does not retain any interest in the assets sold to the financial institution. As of December 31, 2007, 2006, and 2005, MGE has recorded a servicing asset of $0.1 million, $0.1 million, and $0.2 million, respectively. MGE recognized gains of less than $0.1 million in each of the years ended December 31, 2007, 2006, and 2005, in connection with the sale of loan assets. The servicing asset recognized and the amount amortized in 2007 was $0.1 million. The loan assets are sold to the financial institution at cost, which approximates fair value in view of their market rates of interest. During 2007, 2006, and 2005, MGE received approximately $0.5 million, $0.7 million, and $0.5 million, respectively, from the financial institution for the sale of loan assets. During those same years, payments of $1.9 million, $1.2 million, and $1.7 million, respectively, were made by MGE to the financial institution.
MGE would be required to perform under the guarantee if the customer defaulted on its loan. The energy-related equipment installed at the customer sites is used to secure the customer loans. The loan balances outstanding at December 31, 2007, approximate the fair value of the energy-related equipment acting as collateral. The length of the MGE guarantee to the financial institution varies from one to ten years depending on the term of the customer loan. Principal payments for the next five years on the loans are $1.0 million in 2008, $0.6 million in 2009, $0.8 million in 2010, $0.5 million in 2011, and $0.3 million in 2012.
MGE Energy also has guaranteed debt service payments on a development project. This guarantee is a two year commitment ending in 2009 with a maximum financial exposure of $0.2 million for the term of the guarantee.
f.
Elm Road Purchase Commitments - MGE and MGE Energy.
Based on current forecasts, the remaining capital costs for the Elm Road project will be $48.0 million in 2008, $20.5 million in 2009, and $3.5 million in 2010. Included in the 2008 amount is $4.5 million, which has been accrued and recorded as construction work in progress at December 31, 2007. See Footnote 21 for further discussion.
g.
Top of Iowa III Wind Project Commitments - MGE and MGE Energy.
Based on current forecasts, the remaining capital commitments for the Top of Iowa III wind project will be $9.0 million in 2008. Included in this amount is $8.7 million, which has been accrued and recorded as construction work in progress at December 31, 2007. See Footnote 22 for further discussion.
h.
Leases - MGE Energy and MGE.
MGE has noncancelable operating leases, primarily for combustion turbines, railcars, and computer equipment. The operating leases generally do not contain renewal options, with the exception of certain railcar operating leases. These leases have a renewal option of one year or less. MGE is required to pay all executory costs such as maintenance and insurance for its leases.
Future minimum rental payments at December 31, 2007, under agreements classified as operating leases with noncancellable terms in excess of one year are as follows:
(In thousands)
$ 2,650
2,159
1,630
1,455
1,440
Thereafter
12,251
Total minimum future lease payments
$21,585
Rental expense under operating leases totaled $3.0 million for 2007, $3.1 million for 2006, and $2.7 million for 2005.
i.
Other Legal Matters.
MGE is involved in various other legal matters that are being defended and handled in the normal course of business. MGE maintains accruals for such costs that are probable of being incurred and subject to reasonable estimation. As of December 31, 2007, MGE has a total of $1.5 million accrued in the financial statements for such matters. The ultimate outcome of such matters are uncertain and may have an adverse effect on MGE's results of operations or cash flows.
j.
Other Commitments.
MGE Energy and MGE hold equity investments in various non-public entities. See Footnote 4 for further discussion. From time to time these entities require additional capital infusions from their investors. MGE Energy has committed to contribute $0.8 million in capital for such infusions. Additionally, MGE has committed to contribute $0.1 million in capital for such infusions. The timing of these infusions is dependent on the needs of the investee and is therefore uncertain at this time.
MGE has also made a $1.1 million commitment to the City of Madison for certain "green energy" projects. These funds will primarily be used to construct or purchase assets that will be owned by MGE and will be included in the property, plant and equipment balance on the MGE and MGE Energy's financial statements once the costs are incurred. The timing of the capital expenditures is dependent on the feasibility of the individual projects. MGE currently expects that $0.2 million will be expended each year in 2008, 2009, 2010, 2011, and $0.3 million in 2012.
19.
Restructuring Activities - MGE Energy and MGE.
On January 19, 2006, MGE announced a plan, subject to certain conditions, that includes discontinuing coal use at the end of 2011 at Blount. The plant will continue to run on natural gas but will be reduced from its current approximate 190 MW capacity to 100 MW when coal burning is discontinued. MGE has determined that certain employee positions will be eliminated in 2011 as a result of this exit plan.
On January 19, 2006, MGE entered into severance agreements providing severance benefits to the nonunion employees affected by the exit plan. Additionally, on September 21, 2006, MGE ratified a labor agreement with the IBEW providing those union employees impacted by the exit plan with involuntary and voluntary severance benefits. MGE has accounted for the involuntary union and nonunion severance benefits in accordance with the provisions of SFAS 146, Accounting for Costs Associated with Exit or Disposal Activities. These benefits were recognized initially at the respective communication dates based on the fair value of the liability as of the termination date and are being recognized ratably over the future service period of the employees.
Benefits are expected to be paid as follows: $0.1 million will be paid out in 2008, $0.2 million in 2010, and $1.4 million in 2011.
MGE will recover in rates the costs associated with the discontinuance of coal at Blount. As such, the severance charges for the union and nonunion employees have been deferred and recognized on the consolidated balance sheet of MGE Energy and MGE as a regulatory asset.
The following table presents the activity in the restructuring accrual from December 31, 2006, through December 31, 2007:
(In thousands)
Balance at December 31, 2006
$202
Additional expense during the period
Cash payments during the period
(7)
Balance at December 31, 2007
$609
The aforementioned exit plan has also resulted in a plan curtailment for MGE's bargaining pension and postretirement plans as defined in SFAS 88, Employers' Accounting for Settlements and Curtailments of Defined Benefit Pension Plans and for Termination Benefits. See Footnote 13 for discussion of the accounting implications.
20.
Asset Retirement Obligations - MGE Energy and MGE.
FIN 47 and SFAS 143
Effective January 1, 2003, MGE recorded an obligation for the fair value of its legal liability for asset retirement obligations associated with removing an electric substation, a combustion turbine generating unit, wind generating facilities, and photovoltaic generating facilities, all of which are located on property not owned by MGE and MGE Energy and would be removed upon the ultimate end of the lease. As of December 31, 2005, MGE adopted FIN 47. The adoption of FIN 47 required MGE to update an existing inventory of AROs, originally created for the adoption of SFAS 143, and to determine which, if any, of the conditional AROs could be reasonably estimated. The significant conditional AROs identified by MGE included the costs of abandoning in place gas services and mains, the abatement and disposal of equipment and buildings contaminated with asbestos and polychlorinated biphenyls, and the proper disposal and removal of tanks. Changes in management's assumptions regarding settlement dates, settlement methods, or assigned probabilities could have had a material effect on the liabilities recorded by MGE at December 31, 2007, as well as the regulatory asset recorded.
MGE also may have asset retirement obligations relating to the removal of various assets, such as certain electric and gas distribution facilities. These facilities are generally located on property owned by third parties, on which MGE is permitted to operate by lease, permit, easement, license, or service agreement. The asset retirement obligations associated with these facilities cannot be reasonably determined due to the indeterminate life of the related agreements.
In December 2007, upon substantial completion of the Top of Iowa III wind project, MGE recorded an obligation for the fair value of its legal liability for asset retirement obligations associated with the removal, demolition, and restoration of the facility and associated site.
The following table shows costs as of December 31, 2005 and 2006, and changes to the asset retirement obligations and accumulated depreciation through December 31, 2007. Amounts include conditional AROs per FIN 47.
(In thousands)
(a)
Original Asset
Retirement
Obligation
(b)
Accumulated
Accretion
(c)
(a + b)
Asset
Retirement
Obligation
(d)
Accumulated
Depreciation-
Related Asset
Balance, December 31, 2005
$3,934
$7,882
$11,816
$1,685
Changes through December 31, 2006
-
Balance, December 31, 2006
$3,934
$8,545
$12,479
$1,790
Changes through December 31, 2007
1,431
1,831
Balance, December 31, 2007
$5,365
$8,945
$14,310
$1,837
In 2007, MGE reduced accumulated accretion by $0.3 million due to the removal and retirement of assets.
Non-SFAS 143 Costs
Accumulated costs of removal that are non-SFAS No. 143 obligations are classified within the financial statements as regulatory liabilities. At December 31, 2007 and 2006, there were $13.2 million and $13.0 million of these costs recorded as regulatory liabilities within the financial statements, respectively.
21.
Elm Road - MGE Energy and MGE.
a.
Consolidation.
On November 4, 2005, MGE Power Elm Road acquired a 8.33% ownership interest in each of two 615 MW generating units being constructed in Oak Creek, Wisconsin. Each owner provides its own financing and reflects its respective portion of the facility and costs in its financial statements. MGE Power Elm Road's estimated share of capital costs for both units is approximately $171 million (excluding capitalized interest). At December 31, 2007, MGE Power Elm Road had incurred $103.7 million (excluding capitalized interest) of costs on the project, which is reflected in the Construction Work In Progress balance on MGE and MGE Energy's consolidated balance sheets. These amounts may change as a result of modifications to the project estimate or timing differences.
MGE Power Elm Road calculates capitalized interest in accordance with SFAS 34, Capitalization of Interest Cost, on the Elm Road project. At December 31, 2007, MGE Power Elm Road had recorded a total of $6.0 million in capitalized interest related to the Elm Road project.
On the date of acquisition, MGE Energy and its subsidiaries entered into various agreements, including a facility lease agreement. This facility lease agreement is between MGE Power Elm Road (a nonregulated subsidiary of MGE Energy) and MGE. The financial terms of the facility lease include a capital structure of 55% equity and 45% long-term debt, and return on equity of 12.7%, a lease term of 30 years, and a 5% lease payment reduction in the first five years.
b.
Nonregulated Revenues.
On November 1, 2005, MGE received approval from the PSCW to defer payments made to MGE Power Elm Road for carrying costs during construction of the facility, management fees, and community impact mitigation costs. MGE estimates that the total carrying costs on the Elm Road project will be $53.6 million. This estimate is subject to change based on changes in interest rates, timing of capital expenditures, and the total project cost.
MGE began collecting the carrying costs in rates in 2006. These amounts are being collected over multiple years. Of these costs, MGE estimates $21.1 million relates to the capitalized interest and the debt portion of the facility. These costs will be recognized over the period in which the facility will be depreciated. The remaining $32.5 million represents the equity portion and is being recognized over the period allowed for recovery in rates. For the year ended December 31, 2007, $6.8 million related to the carrying costs were recovered in rates. Of this amount, $2.7 million relates to the debt portion of the facility and was deferred on the consolidated financial statements of MGE and MGE Energy. The remaining $4.1 million represents the equity portion and was recognized as nonregulated revenues in the consolidated financial statements of MGE and MGE Energy.
c.
WPDES Permit.
On November 29, 2007, the Administrative Law Judge (the "ALJ") in the proceeding related to the previously issued Wisconsin Pollution Discharge Elimination System ("WPDES") permit determined that the two additional coal units that are part of the Oak Creek expansion are "new facilities" under Section 316(b) of the Federal Clean Water Act.
The ALJ did not vacate the WPDES permit or any other permit necessary to continue construction of the two additional coal units, pointing out that, based upon the present record, the water intake system currently under construction as part of the Oak Creek expansion may be permittable under the standards that apply to new facilities.
The ALJ remanded the WPDES permit to the Wisconsin Department of Natural Resources (the "WDNR") and directed the WDNR to reissue or modify the permit to reflect "best technology available" to comply with the standards applicable to new facilities under Wisconsin state law. As part of the decision, the ALJ restated his prior opinion that the water intake system currently under construction may not be operated so long as it remains a contested matter.
The Operator has advised us that there are alternatives under the United States Environmental Protection Agency's (the "EPA") rule for new facilities that would permit the use of the once-through cooling system rather than the use of cooling towers. The Operator has requested the WDNR to issue a modified permit and has submitted additional information to the WDNR supporting the request for approval of the once-through cooling system under this rule. The Operator anticipates the WDNR will complete the WPDES permit modification process in the first half of 2008. At this time, we cannot predict with certainty what the WDNR's decision will be. A reissued permit would be subject to public comment and possible administrative and legal review.
While the process for modifying the WPDES permit proceeds, construction of the additional coal units will continue on the current schedule.
22.
Top of Iowa III Wind Project - MGE Energy and MGE.
On September 29, 2006, MGE formalized plans to acquire 29.7 MW or 18 turbines in a wind-powered electric generating facility located in Worth County, Iowa. Construction of this facility is expected to be completed in the first quarter of 2008. MGE's costs to complete this project are $57.6 million (excluding AFUDC). At December 31, 2007, MGE had incurred $55.9 million (excluding AFUDC) of costs on the project, which is reflected in the Construction Work in Progress balance on MGE and MGE Energy's consolidated balance sheets. MGE was permitted to recover 100% AFUDC on the Top of Iowa III wind project beginning in November 2006 and continuing until construction on the project is complete. At December 31, 2007, MGE recognized a total of $2.4 million in AFUDC for this project.
MGE will begin recovering the costs of this project in rates in 2008.
23.
Adoption of Accounting Principles and Recently Issued Accounting Pronouncements - MGE Energy and MGE.
a.
SFAS 157.
In September 2006, the FASB issued FASB Statement 157, Fair Value Measurements (SFAS 157). SFAS No. 157 defines fair value, establishes a framework for measuring fair value, and expands disclosures about fair value measurements. Under SFAS 157, fair value refers to the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants in the market in which the reporting entity transacts. The standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or liability. SFAS 157 will be effective as of January 1, 2008. MGE and MGE Energy have created an inventory of items under the scope of this standard. This inventory primarily includes marketable securities and derivatives. The adoption of this standard does not materially impact MGE Energy's and MGE's financial statements. This standard will however require additional disclosure within the footnotes.
b.
SFAS 159.
In February 2007, the FASB issued SFAS 159, The Fair Value Option for Financial Assets and Financial Liabilities - Including an amendment of FASB Statement No. 115. This statement allows companies to choose to measure certain financial instruments and other items at fair value at specified election dates. Under this standard, companies are permitted to choose the fair value option on an instrument-by-instrument basis. MGE has not elected to early adopt this statement. Accordingly, SFAS 159 is effective for MGE as of January 1, 2008. MGE has assessed this standard and the related implications. Based on this assessment, MGE has concluded that on January 1, 2008, it will not elect the fair value option available under this standard.
c.
FSP FIN 39-1.
In April 2007, the FASB issued FSP 39-1, Amendment of FASB Interpretation No. 39 (FSP FIN 39-1). This pronouncement amends FIN 39, Offsetting of Amounts Related to Certain Contracts, and allows companies to offset fair value amounts recognized for the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) against fair value amounts recognized for derivative instruments executed with the same counterparty under a master netting agreement. MGE and MGE Energy will be electing the accounting policies prescribed by this pronouncement. FSP FIN 39-1 will be effective for MGE and MGE Energy as of January 1, 2008. The effects of applying this pronouncement shall be recognized as a change in accounting principle through retroactive application for all financial statements presented unless it is impracticable to do so. The adoption of this pronouncement is not expected to have any impact on MGE or MGE Energy's net income.
d.
FAS 160 and FAS 141(R).
In December 2007, the FASB issued FAS 160, Non-Controlling Interests in Consolidated Financial Statements, an amendment of ARB No. 51 and FAS 141(R), Business Combinations. These pronouncements will change the accounting and reporting for business acquisitions and noncontrolling interest in a subsidiary. In addition, FAS 160 will change the accounting and reporting for the deconsolidation of a subsidiary. FAS 160 and FAS 141(R) will be effective for MGE and MGE Energy as of January 1, 2009. MGE and MGE Energy are currently assessing the impact these pronouncements will have on their financial statements.
24.
Segment Information - MGE Energy and MGE.
Prior to 2005, MGE Energy operated in three business segments: electric utility operations, gas utility operations, and nonregulated. As of December 31, 2005, MGE Energy added segments for nonregulated energy operations, transmission investments, and all other operations. All prior year segment data has been re-presented to conform with the current year presentation and segment break out.
The electric utility business purchases, generates and distributes electricity, and contracts for transmission service. The gas utility business purchases and distributes natural gas and contracts for the transportation of natural gas. Both the electric and gas segments operate through MGE Energy's principal subsidiary, MGE.
The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power, MGE Power West Campus, and MGE Power Elm Road. These subsidiaries have been formed to construct, own and lease new electric generating capacity. MGE Power West Campus owns a controlling interest in the electric generation plant of the natural gas-fired cogeneration facility on the UW campus, which is leased to MGE, and MGE Power Elm Road has an undivided 8.33% ownership interest in each of two 615 MW generating units being constructed in Oak Creek, Wisconsin. When these units are completed, MGE Power Elm Road's portion will also be leased to MGE.
The transmission investment segment invests, through MGE Transco, in ATC, a company that provides electric transmission services primarily in Wisconsin. See Footnote 4 to the consolidated financial statements for further discussion of MGE Transco and the investment in ATC.
The "All other" segment includes: corporate, CWDC, MAGAEL, and MGE Construct. These entities' operations consist of investing in companies and property which relate to the regulated operations, financing the regulated operations, or providing construction services to the other subsidiaries.
General corporate expenses include the cost of executive management, corporate accounting and finance, information technology, risk management, human resources and legal functions, and employee benefits that are allocated to electric and gas segments based on formulas prescribed by the PSCW. Identifiable assets are those used in MGE's operations in each segment. Assets not allocated consist primarily of cash and cash equivalents, restricted cash, investments, other accounts receivable, and prepaid assets.
Sales between our electric and gas segments are based on PSCW approved tariffed rates. Additionally, intersegment operations related to the leasing arrangement between our electric segment and MGE Power West Campus/ MGE Power Elm Road are based on terms previously approved by the PSCW. Consistent with internal reporting and in accordance with the provisions of SFAS 131, management has presented the direct financing capital lease between MGE and MGE Power West Campus as an operating lease for purposes of segment reporting. Lease payments made by MGE to MGE Power West Campus are shown as operating expenses. The lease payments received by MGE Power West Campus from MGE are shown as lease income in interdepartmental revenues. The depreciation expense associated with the WCCF is reflected in the nonregulated energy segment.
The following table shows segment information for MGE Energy's and MGE's operations:
MGE Energy (In thousands)
Year ended December 31, 2007
Electric
Gas
Non-
Regulated
Energy
Transmission
Investment
All
Others
Consolidation/
Elimination
Entries
Consolidated
Total
Operating revenues
$334,488
$197,925
$ 5,181
$ -
$ -
$ -
$ 537,594
Interdepartmental revenues
21,134
14,858
-
-
(36,498)
-
Total operating revenues
334,994
219,059
20,039
-
-
(36,498)
537,594
Depreciation and amortization
(20,994)
(8,527)
(2,678)
-
-
-
(32,199)
Other operating expenses
(260,184)
(197,491)
(108)
(2)
(441)
36,498
(421,728)
Operating income (loss)
53,816
13,041
17,253
(2)
(441)
-
83,667
Other income (loss)
(589)
-
6,047
(31)
-
6,069
Interest income (expense), net
(9,860)
(2,962)
(2,509)
-
2,275
-
(13,056)
Income before taxes
44,598
9,490
14,744
6,045
1,803
-
76,680
Income tax provision
(15,147)
(3,594)
(5,917)
(2,427)
(770)
-
(27,855)
Net income
$ 29,451
$ 5,896
$ 8,827
$ 3,618
$1,033
$ -
$ 48,825
Year ended December 31, 2006
Operating revenues
$318,912
$185,226
$ 3,408
$ -
$ -
$ -
$ 507,546
Interdepartmental revenues
19,135
15,019
-
-
(34,654)
-
Total operating revenues
319,412
204,361
18,427
-
-
(34,654)
507,546
Depreciation and amortization
(20,260)
(8,339)
(2,743)
-
-
-
(31,342)
Other operating expenses
(247,662)
(183,534)
(143)
(8)
(517)
34,654
(397,210)
Operating income (loss)
51,490
12,488
15,541
(8)
(517)
-
78,994
Other income (loss)
(1,238)
-
5,317
-
4,329
Interest income (expense), net
(10,281)
(2,900)
(2,654)
-
-
(15,001)
Income before taxes
39,971
9,835
12,887
5,309
-
68,322
Income tax provision
(14,865)
(3,654)
(5,109)
(2,134)
(137)
-
(25,899)
Net income
$ 25,106
$ 6,181
$ 7,778
$3,175
$
$ -
$ 42,423
Year ended December 31, 2005
Operating revenues
$310,984
$200,533
$
$ -
$1,250
$ -
$513,370
Interdepartmental revenues
25,764
10,106
-
-
(36,323)
-
Total operating revenues
311,437
226,297
10,709
-
1,250
(36,323)
513,370
Depreciation and amortization
(19,472)
(7,937)
(1,866)
-
-
-
(29,275)
Other operating expenses
(256,987)
(202,429)
(124)
-
(278)
36,195
(423,623)
Operating income (loss)
34,978
15,931
8,719
-
(128)
60,472
Other income
-
4,871
-
4,938
Interest income (expense), net
(9,345)
(2,636)
(1,549)
-
-
(13,448)
Income (loss) before taxes
25,684
13,308
7,170
4,871
1,057
(128)
51,962
Income tax provision
(9,642)
(5,013)
(2,874)
(1,956)
(430)
(19,871)
Net income (loss)
$ 16,042
$ 8,295
$ 4,296
$ 2,915
$
$ (84)
$ 32,091
MGE (In thousands)
Year ended December 31, 2007
Electric
Gas
Non-
Regulated
Energy
Transmission
Investment
Consolidation/
Elimination
Entries
Consolidated
Total
Operating revenues
$334,488
$197,925
$ 5,181
$ -
$ -
$ 537,594
Interdepartmental revenues
21,134
14,858
-
(36,498)
-
Total operating revenues
334,994
219,059
20,039
-
(36,498)
537,594
Depreciation and amortization
(20,994)
(8,527)
(2,678)
-
-
(32,199)
Other operating expenses*
(275,652)
(201,038)
(6,025)
(2)
36,498
(446,219)
Operating income (loss)*
38,348
9,494
11,336
(2)
-
59,176
Other income (loss)
(636)
-
3,620
-
3,947
Interest expense, net
(9,860)
(2,962)
(2,509)
-
-
(15,331)
Income before minority interest
29,451
5,896
8,827
3,618
-
47,792
Minority interest, net of tax
-
-
-
-
(10,721)
(10,721)
Net income (loss)
$ 29,451
$ 5,896
$ 8,827
$3,618
$(10,721)
$ 37,071
Year ended December 31, 2006
Operating revenues
$318,912
$185,226
$ 3,408
$ -
$ -
$507,546
Interdepartmental revenues
19,135
15,019
-
(34,654)
-
Total operating revenues
319,412
204,361
18,427
-
(34,654)
507,546
Depreciation and amortization
(20,260)
(8,339)
(2,743)
-
-
(31,342)
Other operating expenses*
(263,057)
(187,096)
(5,252)
(8)
34,653
(420,760)
Operating income (loss)*
36,095
8,926
10,432
(8)
(1)
55,444
Other income (loss)
(708)
-
3,183
(23)
2,607
Interest expense, net
(10,281)
(2,900)
(2,654)
-
-
(15,835)
Income (loss) before minority interest
25,106
6,181
7,778
3,175
(24)
42,216
Minority interest, net of tax
-
-
-
-
(9,610)
(9,610)
Net income (loss)
$ 25,106
$ 6,181
$ 7,778
$3,175
$ (9,634)
$ 32,606
Year ended December 31, 2005
Operating revenues
$310,984
$200,533
$
$ -
$ -
$512,120
Interdepartmental revenues
25,764
10,106
-
(36,323)
-
Total operating revenues
311,437
226,297
10,709
-
(36,323)
512,120
Depreciation and amortization
(19,472)
(7,937)
(1,866)
-
-
(29,275)
Other operating expenses*
(266,903)
(207,519)
(2,998)
-
37,154
(440,266)
Operating income
25,062
10,841
5,845
-
42,579
Other income (loss)*
-
2,915
(890)
2,440
Interest expense, net
(9,345)
(2,636)
(1,549)
-
-
(13,530)
Income (loss) before minority interest
16,042
8,295
4,296
2,915
(59)
31,489
Minority interest, net of tax
-
-
-
-
(5,438)
(5,438)
Net income (loss)
$ 16,042
$ 8,295
$ 4,296
$2,915
$ (5,497)
$ 26,051
*Amounts are shown net of the related tax expense, consistent with the presentation on the consolidated MGE Income Statement.
The following table shows segment information for MGE Energy's and MGE's assets and capital expenditures:
25.
Quarterly Summary of Operations - MGE Energy (unaudited).
Notes:
•
The quarterly results of operations within a year may not be comparable because of seasonal and other factors.
•
The sum of earnings per share of common stock for any four quarters may vary slightly from the earnings per share of common stock for the equivalent twelve-month period due to rounding.
•
MGE Energy's operations are based primarily on its utility subsidiary MGE.
26.
Related Party Transactions - MGE Energy and MGE.
ATC
On November 21, 2002, MGE and ATC entered into an interconnection agreement related to transmission system upgrades for WCCF. MGE issued to ATC a "Notice to Proceed for the Procurement of the Equipment" for the system upgrades. MGE advanced funds for construction of transmission equipment and work done by ATC related to WCCF. Total funds advanced to ATC, including interest incurred, for this project at December 31, 2005, were $13.0 million. During 2004 funds were advanced in the amount of $2.3 million. During the first quarter of 2005, MGE received $13.0 million from ATC as full reimbursement of its costs incurred to complete the upgrade.
During 2007, 2006, and 2005, MGE recorded $18.7 million, $16.3 million, and $14.9 million, respectively for transmission services received from ATC. MGE also provides a variety of operational, maintenance, and project management work for ATC, which is reimbursed by ATC. For each of the years ended December 31, 2007, 2006, and 2005, MGE had a receivable due from ATC of $0.1 million.
WEPCO and ATC entered into an interconnection agreement related to transmission system upgrades for the Elm Road project, in which MGE Power Elm Road has an undivided 8.33% ownership interest. At December 31, 2007 and 2006, MGE Power Elm Road has a receivable from ATC totaling $2.8 million and $2.4 million, respectively, related the work done by ATC on the Elm Road interconnection project. MGE will be reimbursed for all these costs upon completion of the project.
For additional discussion on MGE's relationship with ATC, see Footnote 4.
27.
Subsequent Events- MGE Energy and MGE.
a.
Pension and Postretirement Benefit Payment.
On January 14, 2008, MGE made a cash payment of $5.4 million to the pension and postretirement plans. This contribution was made at MGE's discretion.
b.
Venture Debt Commitment.
On January 15, 2008, MGE Energy entered into an three year agreement with a venture debt fund. As a result of this agreement, MGE Energy has committed $0.5 million to this venture debt fund .
Item 9.
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.
MGE Energy and MGE
None.
Item 9A.
Item 9A. Controls and Procedures.
MGE Energy and MGE
Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures
During the fourth quarter of 2007, each registrant's management, including the principal executive officer and principal financial officer, evaluated its disclosure controls and procedures related to the recording, processing, summarization, and reporting of information in its periodic reports that it files with the SEC. These disclosure controls and procedures have been designed to ensure that material information relating to that registrant, including its subsidiaries, is accumulated and made known to that registrant's management, including its principal executive officer and its principal executive financial officer, by other employees of that registrant and its subsidiaries as appropriate to allow timely decisions regarding required disclosure, and that this information is recorded, processed, summarized, evaluated, and reported, as applicable, within the time periods specified in the SEC's rules and forms. Due to the inherent limitations of control systems, not all misstatements may be detected. These inherent limitations include the realities that judgments in decision making can be faulty and breakdowns can occur because of simple error or mistake. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. Also, the registrants do not control or manage certain of their unconsolidated entities, and thus, their access and ability to apply their procedures to those entities is more limited than is the case for their consolidated subsidiaries.
As of December 31, 2007, the principal executive officer and principal financial officer of each registrant concluded that such registrant's disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) were effective to accomplish their objectives. Each registrant intends to continually strive to improve its disclosure controls and procedures to enhance the quality of its financial reporting.
During the quarter ended December 31, 2007, there were no changes in MGE Energy or MGE's internal controls over financial reporting that materially affected, or are reasonably likely to materially affect, MGE Energy or MGE's internal control over financial reporting.
MGE Energy and MGE
Management of MGE Energy and MGE are required to assess and report on the effectiveness of its internal control over financial reporting as of December 31, 2007. As a result of that assessment, management determined that there were no material weaknesses as of December 31, 2007 and, therefore, concluded that MGE Energy and MGE's internal control over financial reporting was effective. Management's Report on Internal Control Over Financial Reporting is included in Item 8. - Financial Statements and Supplementary Data.
Item 9B.
Item 9B. Other Information.
MGE Energy
None.
PART III.
Item 10.
Item 10. Directors, Executive Officers, and Corporate Governance.
MGE Energy
The information required by Item 10 relating to directors and nominees for election as directors at MGE Energy's annual meeting of shareholders is incorporated herein by reference to the information under the heading "ELECTION OF DIRECTORS" in MGE Energy's definitive proxy statement (2008 Proxy Statement) to be filed with the SEC on or before April 14, 2008. Information relating to compliance with Section 16(a) of the Securities Exchange Act of 1934 is incorporated herein by reference to the information under the heading "BENEFICIAL OWNERSHIP - Section 16(a) Beneficial Ownership Reporting Compliance" in the 2008 Proxy Statement.
The information required by Item 10 relating to executive officers is set forth above in Item 1. Business - Executive Officers of the Registrants.
Code of Ethics
MGE Energy has adopted a Code of Ethics applicable to its directors and all of its employees, including its chief executive officer, chief financial officer, and principal accounting officer. The Code of Ethics is available on MGE Energy's web site at www.mgeenergy.com.
Item 11.
Item 11. Executive Compensation.
See Item 12.
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.
MGE Energy
The required information for Items 11 and 12 is included in the 2008 Proxy Statement under the section "EXECUTIVE COMPENSATION," not including "Compensation Committee Report," and "Company Performance," and under the section "BENEFICIAL OWNERSHIP," which is incorporated herein by reference.
MGE Energy does not have or maintain any equity compensation plans.
Item 13.
Item 13. Certain Relationships and Related Transactions, and Director Independence.
MGE Energy
None.
Item 14.
Item 14. Principal Accounting Fees and Services.
MGE Energy
The information required by Item 14 is incorporated herein by reference to the information under the heading "RATIFICATION OF PRICEWATERHOUSECOOPERS LLP AS OUR INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM" in the 2008 Proxy Statement.
MGE
MGE is a wholly owned subsidiary of MGE Energy and does not have a separate audit committee. Instead, that function is fulfilled for MGE by the MGE Energy Audit Committee. The Audit Committee approves each engagement of the independent registered public accounting firm to render any audit or non-audit services before the firm is engaged to render those services. The Chair of the Audit Committee or other designated Audit Committee member may represent the entire Audit Committee for purposes of this approval. Any services approved by the Chair or other designated Audit Committee member are reported to the full Audit Committee at the next scheduled Audit Committee meeting. No de minimis exceptions to this approval process are allowed under the Audit Committee Charter; and thus, none of the services described in the preceding table were approved pursuant to Rule 2-01(c)(7)(i)(C) of Regulation S-X.
PART IV.
Item 15.
Item 15. Exhibits and Financial Statement Schedules.
(a)
1.
Financial Statements.
MGE Energy
Report of Independent Registered Public Accounting Firm
Consolidated Statements of Income for the years ended December 31, 2007, 2006, and
Consolidated Statements of Cash Flows for the years ended December 31, 2007, 2006, and 2005
Consolidated Balance Sheets as of December 31, 2007 and 2006
Consolidated Statements of Capitalization as of December 31, 2007 and 2006
Consolidated Statements of Common Equity and Comprehensive Income as of December 31, 2007, 2006, and 2005
Notes to Consolidated Financial Statements
MGE
Report of Independent Registered Public Accounting Firm
Consolidated Statements of Income for the years ended December 31, 2007, 2006, and
Consolidated Statements of Cash Flows for the years ended December 31, 2007, 2006, and 2005
Consolidated Balance Sheets as of December 31, 2007 and 2006
Consolidated Capitalization Statement as of December 31, 2007 and 2006
Consolidated Statements of Common Equity and Comprehensive Income as of December 31, 2007, 2006, and 2005
Notes to Consolidated Financial Statements
2.
Financial Statement Schedule.
Schedule II - Valuation and Qualifying Accounts for MGE Energy, Inc. and Madison Gas and Electric Company.
All other schedules have been omitted because they are not applicable or not required, or because the required information is shown in the consolidated financial statements or notes thereto.
3.
All Exhibits Including Those Incorporated by Reference.
Exhibits. Certain of the following exhibits are incorporated herein by reference under Rule 12b-32 of the Securities Exchange Act of 1934, as amended, as indicated by the parenthetical reference. Certain other instruments which would otherwise be required to be listed below have not been so listed because such instruments do not authorize securities in an amount which exceeds 10% of the total assets of the applicable registrant and its subsidiaries on a consolidated basis and the relevant registrant agrees to furnish a copy of any such instrument to the Commission upon request. An asterisk (*) indicates a management contract or compensatory plan or arrangement.
3.1
Amended and Restated Articles of Incorporation of MGE Energy. (Exhibit 3.1 to MGE Energy's Registration Statement on Form S-4, Registration No. 333-72694.)
3.2
Amended and Restated Bylaws of MGE Energy. (Exhibit 3.2 to MGE Energy's Registration Statement on Form S-4, Registration No. 333-72694.)
3.3
Restated Articles of Incorporation of MGE as in effect at May 6, 1996. (Exhibit 3.(i) to Form 10-K for year ended December 31, 1996, File No. 0-1125.)
3.4
Amended Bylaws of MGE as in effect at August 16, 2002. (Exhibit 3.4 to Form 10-K for year ended December 31, 2002, File No. 0-1125.)
4.1
Indenture of Mortgage and Deed of Trust between MGE and Firstar Trust Company, as Trustee, dated as of January 1, 1946. (Exhibit 7-D to SEC File No. 0-1125.)
4.2
Supplemental Indenture to aforementioned Mortgage and Deed of Trust.
Supplemental Indenture
Dated as of
Exhibit No.
SEC File No.
Seventeenth
February 1, 1993
4F
Form 10-K for year ended
December 31, 1992,
File No. 0-1125
4.3
Indenture between MGE and The Bank of New York Trust Company, N.A. (as successor to Bank One, N.A.), as Trustee, dated as of September 1, 1998. (Exhibit 4B to Form 10-K for year ended December 31, 1999, File No. 0-1125.)
10.1
Credit Agreement dated as of December 21, 2005, among MGE Energy, Inc., the Lenders party thereto, and JPMorgan Chase Bank, N.A., as Administrative Agent. (Exhibit 10.5 to Form 10-K for the year ended December 31, 2005, File No. 0-1125.)
10.2
First Amendment dated as of April 25, 2006, to Credit Agreement dated as of December 21, 2005, among MGE Energy, Inc., the Lenders party thereto, and JPMorgan Chase Bank, N.A., as Administrative Agent. (Exhibit 10.1 to Form 10-Q for the quarter ended March 31, 2006, File No. 0-469965.)
10.3
Amended and Restated Credit Agreement dated as of December 21, 2005, among Madison Gas and Electric Company, the Lenders party thereto, and JPMorgan Chase Bank, N.A., as Administrative Agent. (Exhibit 10.6 to Form 10-K for the year ended December 31, 2005, File No. 0-1125.)
10.4
Line of Credit Note, dated as September 29, 2006, among Madison Gas and Electric Company, as Borrower, and JPMorgan Chase Bank, N.A., as Lender. (Exhibit 10.1 to Form 10-Q for the quarter ended September 30, 2006, File No. 0-1125.)
10.5
Distribution Agreement, dated as of November 9, 2006, by and between MGE Energy, Inc. and J.P. Morgan Securities Inc. (Exhibit 1.1 to Form 8-K dated November 9, 2006, File No. 0-49965.)
10.6
Copy of Joint Power Supply Agreement with Wisconsin Power and Light Company and Wisconsin Public Service Corporation dated February 2, 1967. (Exhibit 4.09 to Registration Statement, Registration No. 2-27308.)
10.7
Copy of Joint Power Supply Agreement (Exclusive of Exhibits) with Wisconsin Power and Light Company and Wisconsin Public Service Corporation dated July 26, 1973, amending Exhibit 5.04. (Exhibit 5.04A to Registration Statement, Registration No. 2-48781.)
10.8
Copy of revised Agreement for Construction and Operation of Columbia Generating Plant with Wisconsin Power and Light Company and Wisconsin Public Service Corporation dated July 26, 1973. (Exhibit 5.07 to Registration Statement, Registration No. 2-48781.)
10.9
Copy of Amended and Restated Agreement for Construction and Operation of Columbia Generating Plant dated January 17, 2007. (Exhibit 10.9 to Form 10-K for the year ended December 31, 2006, File No. 0-1125.)
10.10
West Campus Cogeneration Facility Engineering, Procurement and Construction Agreement, dated as of October 1, 2003, among MGE Construct LLC, as General Contractor, and the State of Wisconsin, and MGE Power West Campus, LLC, as Joint Owners. (Exhibit 10.18 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.11
West Campus Cogeneration Facility Joint Ownership Agreement, dated as of October 13, 2003, among MGE Power West Campus, LLC, The Board of Regents of the University of Wisconsin System, and the State of Wisconsin, as Joint Owners. (Exhibit 10.19 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.12
West Campus Cogeneration Facility Operation and Maintenance Agreement, dated as of October 13, 2003, among Madison Gas and Electric Company, as Operator, and the Board of Regents of the University of Wisconsin System, as Joint Owner. (Exhibit 10.20 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.13
West Campus Cogeneration Facility Lease Agreement, dated as of March 18, 2004, among MGE Power West Campus, LLC, as Lessor, and Madison Gas and Electric Company, as Lessee. (Exhibit 10.21 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.14
West Campus Cogeneration Facility Ground Lease, dated as of July 15, 2002, among MGE Power LLC, as Lessee, and the Board of Regents of the University of Wisconsin System, as Lessor. (Exhibit 10.22 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.15
West Campus Cogeneration Facility Amendment of Ground Lease, dated as of March 18, 2004, among MGE Power West Campus, LLC as Lessee, and the Board of Regents of the University of Wisconsin System, as Lessor. (Exhibit 10.23 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.16
West Campus Cogeneration Facility MGE Ground Sublease, dated as of March 18, 2004, among MGE Power West Campus, LLC as Lessee, and Madison Gas and Electric Company, as Lessor. (Exhibit 10.24 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.17
Elm Road Generating Station Common Facilities Operating and Maintenance Agreement, dated as of December 17, 2004, among Madison Gas and Electric Company, Wisconsin Electric Power Company, and Wisconsin Public Power Inc., as Lessee/Owner Parties, and Wisconsin Electric Power Company, as Operating Agent. (Exhibit 10.7 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.18
Elm Road Generating Station New Common Facilities Ownership Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC, Elm Road Generating Station Supercritical, LLC, and Wisconsin Public Power Inc., as Joint Owners. (Exhibit 10.8 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.19
Elm Road Generating Station I Ownership Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC, Elm Road Generating Station Supercritical, LLC, and Wisconsin Public Power Inc., as Joint Owners, Elm Road Services, LLC, as Project Manager, and W.E. Power LLC. (Exhibit 10.9 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.20
Elm Road Generating Station I Facility Lease Agreement, dated as of November 4, 2005, among MGE Power Elm Road, LLC, as Lessor, and Madison Gas and Electric Company, as Lessee. (Exhibit 10.10 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.21
Elm Road Generating Station I Operating and Maintenance Agreement, dated as of December 17, 2004, among Madison Gas and Electric Company, Wisconsin Electric Power Company, and Wisconsin Public Power Inc., as Lessee/ Owners, and Wisconsin Electric Power Company, as Operating Agent. (Exhibit 10.11 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.22
Elm Road Generating Station I Easement and Indemnification Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC and Wisconsin Public Power Inc., as Grantees, and Wisconsin Electric Power Company, as Grantor. (Exhibit 10.12 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.23
Elm Road Generating Station I Easement and Indemnification Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC and Madison Gas and Electric Company. (Exhibit 10.16 to Form 10-K for the year ended December 31, 2005, File No. 0-1125.)
10.24
Elm Road Generating Station II Ownership Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC, Elm Road Generating Station Supercritical, LLC, and Wisconsin Public Power Inc., as Joint Owners, Elm Road Services, LLC, as Project Manager, and W.E. Power LLC. (Exhibit 10.13 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.25
Elm Road Generating Station II Facility Lease Agreement, dated as of November 4, 2005, among MGE Power Elm Road, LLC, as Lessor, and Madison Gas and Electric Company, as Lessee. (Exhibit 10.14 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.26
Elm Road Generating Station II Operating and Maintenance Agreement, dated as of December 17, 2004, among Madison Gas and Electric Company, Wisconsin Electric Power Company, and Wisconsin Public Power Inc., as Lessee/ Owners, and Wisconsin Electric Power Company, as Operating Agent. (Exhibit 10.15 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.27
Elm Road Generating Station II Easement and Indemnification Agreement, dated as of December 17, 2004, among MGE Power Elm Road, LLC and Wisconsin Public Power Inc., as Grantees, and Wisconsin Electric Power Company, as Grantor. (Exhibit 10.16 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.28
Operating Agreement, dated as of October 28, 2005, among MGE Energy LLC, Madison Gas and Electric Company, and MGE Transco Investment LLC. (Exhibit 10.17 to Form 10-Q for the quarter ended September 30, 2005, File No. 0-1125.)
10.29
Wind Turbine Supply Agreement, dated as of September 29, 2006, among Madison Gas and Electric Company as Buyer and Vestas-American Wind Technology , Inc. As Supplier. (Exhibit 10.2 to Form 10-Q for the quarter ended September 30, 2006, File No. 0-1125.)
10.30
Warranty Agreement to the Wind Turbine Supply Agreement, dated as of September 29, 2006, among Madison Gas and Electric Company as Buyer and Vestas-American Wind Technology, Inc. As Supplier. (Exhibit 10.3 to Form 10-Q for the quarter ended September 30, 2006, File No. 0-1125.)
10.31
Service and Maintenance Agreement, dated as of September 29, 2006, among Madison Gas and Electric Company as Buyer and Vestas-American Wind Technology, Inc. As Supplier. (Exhibit 10.4 to Form 10-Q for the quarter ended September 30, 2006, File No. 0-1125.)
10.32
Asset Purchase Agreement, dated as of September 29, 2006, among Madison Gas and Electric Company as Buyer and Northern Iowa Windpower II LLC and Northern Iowa Windpower III LLC as Seller. (Exhibit 10.5 to Form 10-Q for the quarter ended September 30, 2006, File No. 0-1125.)
10.33
Substation and Transformer Shared Use Agreement and Easement Agreement, dated as of September 29, 2006, among Madison Gas and Electric Company and Northern Iowa Windpower II LLC as Joint Owners. (Exhibit 10.6 to Form 10-Q for the quarter ended September 30, 2006, File No. 0-1125.)
10.34
Management and Administration Agreement, dated as of October 13, 2006, among Madison Gas and Electric Company as Owner and Midwest Renewable Energy Resources, LLC as Manager. (Exhibit 10.7 to Form 10-Q for the quarter ended September 30, 2006, File No. 0-1125.)
10.35*
Form of Severance Agreement. (Exhibit 10F to Form 10-K for the year ended December 31, 1994, File No. 0-1125.)
10.36*
MGE Energy, Inc. 2006 Performance Unit Plan. (Exhibit 10.36 to Form 10-K for the year ended December 31, 2006, File No. 0-49965.)
Statements regarding computation of ratio of earnings to fixed charges:
12.1 MGE Energy, Inc.
12.2 Madison Gas and Electric Company
Subsidiaries of MGE Energy, Inc.
Consent of Independent Registered Public Accounting Firm
23.1
MGE Energy, Inc.
23.2
Madison Gas and Electric Company.
Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 as to the Annual Report on Form 10-K for the year ended December 31, 2007, filed by the following officers for the following companies:
31.1 Filed by Gary J. Wolter for MGE Energy, Inc.
31.2 Filed by Terry A. Hanson for MGE Energy, Inc.
31.3 Filed by Gary J. Wolter for Madison Gas and Electric Company
31.4 Filed by Terry A. Hanson for Madison Gas and Electric Company
Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) as to the Annual Report on Form 10-K for the year ended December 31, 2007, filed by the following officers for the following companies:
32.1 Filed by Gary J. Wolter for MGE Energy, Inc.
32.2 Filed by Terry A. Hanson for MGE Energy, Inc.
32.3 Filed by Gary J. Wolter for Madison Gas and Electric Company
32.4 Filed by Terry A. Hanson for Madison Gas and Electric Company
Schedule II
MGE Energy, Inc., and Madison Gas and Electric Company
Valuation and Qualifying Accounts
Signatures - MGE Energy, Inc.
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, hereunto duly authorized.
MGE Energy, Inc.
(Registrant)
Date: February 26, 2008
/s/ Gary J. Wolter
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 indicated on February 26, 2008.
/s/ Gary J. Wolter
Gary J. Wolter
Chairman, President and Chief Executive Officer and Director (Principal Executive Officer)
/s/ Terry A. Hanson
Terry A. Hanson
Vice President, Chief Financial Officer and Secretary
(Principal Financial Officer and Principal Accounting Officer)
/s/ Richard E. Blaney
Richard E. Blaney, Director
/s/ Londa J. Dewey
Londa J. Dewey, Director
/s/ F. Curtis Hastings
F. Curtis Hastings, Director
/s/ Regina M. Millner
Regina M. Millner, Director
/s/ Frederic E. Mohs
Frederic E. Mohs, Director
/s/ John R. Nevin
John R. Nevin, Director
/s/ H. Lee Swanson
H. Lee Swanson, Director
Signatures - Madison Gas and Electric Company
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, hereunto duly authorized.
Madison Gas and Electric Company
(Registrant)
Date: February 26, 2008
/s/ Gary J. Wolter
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 indicated on February 26, 2008.
/s/ Gary J. Wolter
Gary J. Wolter
Chairman, President and Chief Executive Officer and Director (Principal Executive Officer)
/s/ Terry A. Hanson
Terry A. Hanson
Vice President, Chief Financial Officer and Secretary
(Principal Financial Officer and Principal Accounting Officer)
/s/ Richard E. Blaney
Richard E. Blaney, Director
/s/ Londa J. Dewey
Londa J. Dewey, Director
/s/ F. Curtis Hastings
F. Curtis Hastings, Director
/s/ Regina M. Millner
Regina M. Millner, Director
/s/ Frederic E. Mohs
Frederic E. Mohs, Director
/s/ John R. Nevin
John R. Nevin, Director
/s/ H. Lee Swanson
H. Lee Swanson, Director