1
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D. C. 20549
FORM 10-K
X ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
----- OF THE SECURITIES EXCHANGE ACT OF 1934
For the Fiscal Year Ended December 31, 1995
Commission file number 1-1245
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WISCONSIN ELECTRIC POWER COMPANY
(Exact name of registrant as specified in its charter)
Wisconsin 39-0476280
(State or other jurisdiction of (I.R.S. Employer Identification No.)
incorporation or organization)
231 West Michigan Street, P.O. Box 2046, Milwaukee, Wisconsin 53201
(Address of principal executive offices) (Zip Code)
(414) 221-2345
(Registrant's telephone number, including area code)
------------
Securities Registered Pursuant to Section 12(b) of the Act:
Name of Each Exchange
Title of Each Class on which Registered
----------------------------------------- ---------------------
None --
Securities Registered Pursuant to Section 12(g) of the Act:
PREFERRED STOCK, 3.60% SERIES, $100 PAR VALUE
SIX PER CENT. PREFERRED STOCK, $100 PAR VALUE
(Title of Class)
----------------
Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13
or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period
that the Registrant was required to file such reports), and (2) has been subject to such filing requirements
for the past 90 days. Yes X No
----- -----
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not
contained herein, and will not be contained, to the best of Registrant's knowledge, in definitive proxy
or information statements incorporated by reference in Part III of this Form 10-K or any amendment to
this Form 10-K. X
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The aggregate market value of the voting stock of the Registrant held by non-affiliates is approximately
$16,934,000 based on the reported last sale prices on March 1, 1996 or the average bid and asked prices
of such securities on or prior to such date.
------------
Indicate the number of shares outstanding of each of the Registrant's classes of common stock, as of the
latest practicable date.
Class Outstanding at March 1, 1996
----- ----------------------------
COMMON STOCK, $10 PAR VALUE 33,289,327 Shares
Documents Incorporated by Reference
-----------------------------------
Portions of the Registrant's definitive Information Statement for its Annual Meeting of Stockholders to be
held on May 21, 1996, are incorporated by reference into Part III hereof.
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WISCONSIN ELECTRIC POWER COMPANY ("WE")
FORM 10-K ANNUAL REPORT TO THE SECURITIES AND EXCHANGE COMMISSION
FOR THE YEAR ENDED DECEMBER 31, 1995
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TABLE OF CONTENTS
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ITEM PAGE
PART I
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1. Business . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4
2. Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . 27
3. Legal Proceedings . . . . . . . . . . . . . . . . . . . . . . . 28
4. Submission of Matters to a Vote of Security Holders. . . . . . . 32
Executive Officers of the Registrant . . . . . . . . . . . . . . 32
PART II
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5. Market for Registrant's Common Equity
and Related Stockholder Matters . . . . . . . . . . . . . . . 34
6. Selected Financial Data . . . . . . . . . . . . . . . . . . . . 35
Electric Revenues, Kilowatt-Hour Sales and
Customer Statistics . . . . . . . . . . . . . . . . . . . . . 36
Gas Revenues, Therms Delivered and Customer Statistics . . . . . 36
7. Management's Discussion and Analysis of Financial
Condition and Results of Operations . . . . . . . . . . . . . 37
8. Financial Statements and Supplementary Data. . . . . . . . . . . 56
Report of Independent Accountants . . . . . . . . . . . . . . . 80
9. Changes in and Disagreements with Accountants
on Accounting and Financial Disclosure . . . . . . . . . . . . 81
PART III
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10. Directors and Executive Officers of the Registrant . . . . . . 81
11. Executive Compensation . . . . . . . . . . . . . . . . . . . . 81
12. Security Ownership of Certain Beneficial Owners
and Management . . . . . . . . . . . . . . . . . . . . . . . 81
13. Certain Relationships and Related Transactions . . . . . . . . 81
PART IV
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14. Exhibits, Financial Statement Schedules, and
Reports on Form 8-K . . . . . . . . . . . . . . . . . . . . . 82
Consent of Independent Accountants . . . . . . . . . . . . . . 87
Wisconsin Energy Company Unaudited Pro Forma
Combined Condensed Financial Information. . . . . . . . . . . 88
Signatures . . . . . . . . . . . . . . . . . . . . . . . . . . 95
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DEFINITIONS
Abbreviations and acronyms used in the text are defined below.
Abbreviations and Acronyms Term
-------------------------- ----
BTU.............................. British Thermal Units
CO2.............................. Carbon Dioxide
Concord.......................... Concord Generating Station
CPCN............................. Certificate of Public Convenience and Necessity
DNR.............................. Wisconsin Department of Natural Resources
DOE.............................. U.S. Department of Energy
DSM.............................. Demand Side Management
Dth.............................. Dekatherm
EMFs............................. Electromagnetic Fields
EPA.............................. U.S. Environmental Protection Agency
EWGs............................. Exempt Wholesale Generators
FERC............................. Federal Energy Regulatory Commission
GRI.............................. Gas Research Institute
IPP.............................. Independent Power Producer
ISFSI............................ Independent Spent Fuel Storage Installation
LS Power......................... LSP-Whitewater L.P.
MAPP............................. Mid-Continent Area Power Pool
MDNR............................. Michigan Department of Natural Resources
MDEQ............................. Michigan Department of Environmental Quality
MGP.............................. Manufactured gas plant
MPSC............................. Michigan Public Service Commission
MWh.............................. Megawatt-hour
NOX.............................. Nitrogen Oxide
NRC.............................. U.S. Nuclear Regulatory Commission
New NSP.......................... NSP (after reincorporation in Wisconsin and related changes)
NSP.............................. Northern States Power Company, a Minnesota corporation
NSP-WI........................... Northern States Power Company, a Wisconsin corporation
Paris............................ Paris Generating Station
PGA.............................. Purchased Gas Adjustment
Point Beach...................... Point Beach Nuclear Plant
Primergy......................... Primergy Corporation
PRP ............................. Potentially Responsible Party
PSCR............................. Power Supply Cost Recovery
PSCW............................. Public Service Commission of Wisconsin
PUHCA............................ Public Utility Holding Company Act of 1935
Repap............................ Repap Wisconsin, Inc.
SEC.............................. Securities and Exchange Commission
SO2.............................. Sulfur Dioxide
Trust............................ Wisconsin Electric Fuel Trust (nuclear)
UPPCO............................ Upper Peninsula Power Company
USEC............................. U.S. Enrichment Corporation
WE............................... Wisconsin Electric Power Company
WEC or the Company............... Wisconsin Energy Corporation
WEGO............................. WE Gas Operations
WN............................... Wisconsin Natural Gas Company
WSG.............................. Wisconsin Southern Gas Company, Inc.
WPPI............................. Wisconsin Public Power Inc. SYSTEM
WUMS............................. Wisconsin-Upper Michigan Systems
Yellowcake....................... Uranium Concentrates
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PART I
ITEM 1. BUSINESS
Wisconsin Electric Power Company ("WE" or the "Company") is an operating
public utility incorporated in the State of Wisconsin in 1896. Effective
January 1, 1996, Wisconsin Energy Corporation ("WEC"), WE's parent company,
merged its natural gas utility subsidiary, Wisconsin Natural Gas Company
("WN"), into WE to form a single combined utility subsidiary. Where
applicable, references to WE include WN prior to the merger. Additional
information concerning the merger may be found in Item 7. MANAGEMENT'S
DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS -
"RESULTS OF OPERATIONS - Mergers" and in Note B - "Mergers" in the NOTES TO
FINANCIAL STATEMENTS in Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
WE's operations are conducted in three business segments, the primary
operations of which are as follows:
Business Segment Operations
---------------- ----------
Electric Operations WE generates, transmits, distributes and sells
electric energy in a territory of
approximately 12,000 square miles with a
population estimated at over 2,200,000 in
southeastern (including the Milwaukee area),
east central and northern Wisconsin and in the
Upper Peninsula of Michigan.
Gas Operations The WE gas operations ("WEGO") purchases,
distributes and sells natural gas to retail
customers and transports customer-owned gas in
three distinct service areas in Wisconsin:
west and south of the City of Milwaukee, the
Appleton area and the Prairie du Chien area.
The gas service territory, which has an
estimated population of over 1,100,000, is
largely within WE's electric service area.
Steam Operations WE distributes and sells steam supplied by
WE's Valley Power Plant to space heating and
processing customers in downtown and near
southside areas of Milwaukee.
For additional financial information about business segments, see Note L -
"Information by Segments of Business" in the NOTES TO FINANCIAL STATEMENTS in
Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
MERGER AGREEMENT WITH NORTHERN STATES POWER COMPANY ("NSP")
On April 28, 1995, WEC and Northern States Power Company, a Minnesota
corporation ("NSP") entered into an Agreement and Plan of Merger, which was
amended and restated as of July 26, 1995 ("Merger Agreement"). The Merger
Agreement provides for a strategic business combination involving WEC and NSP
in a "merger-of-equals" transaction ("Transaction"). As a result, WEC will
become a registered public utility holding company under the Public Utility
Holding Company Act of 1935, as amended ("PUHCA"), and will change its name to
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ITEM 1. BUSINESS - Merger Agreement with NSP - (cont'd)
Primergy Corporation ("Primergy"). The headquarters of Primergy will be in
Minneapolis, Minnesota. The business of Primergy will consist of owning
utilities and various non-utility subsidiaries.
Primergy will be the parent company of WE (which will be renamed Wisconsin
Energy Company), of NSP (which, for regulatory reasons, will reincorporate in
Wisconsin ("New NSP")), and of the other subsidiaries of WEC and NSP. In
connection with the Transaction, Northern States Power Company, a Wisconsin
corporation ("NSP-WI"), currently a utility subsidiary of NSP, will be merged
into Wisconsin Energy Company. Prior to the merger of NSP-WI into Wisconsin
Energy Company, New NSP will acquire from NSP-WI certain gas utility assets.
Wisconsin Energy Company and New NSP will operate as the principal
subsidiaries of Primergy. The headquarters of the two utilities will remain
in their current locations, Wisconsin Energy Company's in Milwaukee and New
NSP's in Minneapolis. Based upon December 31, 1995 statistics, Wisconsin
Energy Company and New NSP will serve a total of approximately 2,350,000
electric customers and 780,000 natural gas customers, and their combined
service territory will include portions of Minnesota, Wisconsin, North Dakota,
South Dakota and the Upper Peninsula of Michigan.
Upon receipt of the necessary approval from the Federal Energy Regulatory
Commission ("FERC") and on or after the effective time of the Transaction,
Wisconsin Energy Company and New NSP will become parties to an Interchange
Agreement, whereby costs of generating capacity and transmission are shared in
a manner similar to an existing interchange agreement between NSP and NSP-WI.
The integration of the Wisconsin Energy Company and New NSP generating
capacity should increase the ability of these companies to meet demands for
electricity within the service territories each serves. It is also
anticipated that a single administrative and support system will be
established following the Transaction.
The non-utility operations of WEC are presently conducted through six active
wholly-owned subsidiaries. The non-utility operations of NSP are conducted
primarily through NRG Energy, Inc., Cenergy, Inc. and Eloigne Company.
Following the Transaction, it is anticipated that New NSP will transfer its
non-utility businesses to Primergy and that such non-utility businesses of New
NSP, along with the non-utility businesses of WEC, will be conducted through
one or more subsidiaries of Primergy that are not subsidiaries of Wisconsin
Energy Company or New NSP.
WEC is currently exempt from the registration and other requirements of PUHCA,
other than from Section 9(a)(2) thereof, pursuant to an order of the
Securities and Exchange Commission ("SEC"). SEC approval under PUHCA is
required in connection with the Transaction.
The PUHCA exemption under which WEC currently operates will not be available
to Primergy after consummation of the Transaction. Accordingly, upon
consummation of the Transaction, Primergy must register as a holding company.
PUHCA imposes numerous restrictions on the operations of a registered holding
company and its subsidiaries and affiliates. Subject to limited exceptions,
SEC approval is required under PUHCA for a registered holding company or any
of its subsidiaries to: (i) issue securities, (ii) acquire utility assets from
a third person, (iii) acquire the stock of another public utility, (iv) amend
its articles of incorporation or (v) acquire stock, extend credit, pay
dividends, lend money or invest in any manner in any other businesses. SEC
approval under PUHCA also will be required for certain proposed transactions
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ITEM 1. BUSINESS - Merger Agreement with NSP - (cont'd)
relating to the Transaction. As part of the SEC approval process, PUHCA also
limits the ability of registered holding companies to engage in non-utility
ventures and regulates holding company system service companies and the
rendering of services by holding company affiliates to the system's utilities.
The SEC may require, as a condition to its approval of the Transaction, that
WEC and NSP divest their gas utility properties and possibly certain non-
utility ventures within a reasonable time after the Transaction is
consummated. In a few cases, the SEC has allowed the retention of such
properties or deferred the question of divestiture for a substantial period of
time. In those cases in which divestiture has taken place, the SEC has
usually allowed enough time to complete the divestiture so as to allow the
applicant to avoid a "fire sale" of the divested assets. WEC and NSP believe
strong policy reasons and prior SEC decisions exist which support their
retaining their existing gas utility properties and non-utility ventures, or,
alternatively, which support deferring the question of divestiture for a
substantial period of time. Accordingly, WEC and NSP will request in their
merger application with the SEC that WEC and NSP be allowed to retain, or in
the alternative, that the question of divestiture be deferred with respect to,
WEC's and NSP's existing gas utility properties and non-utility ventures.
Also, regulatory authorities may require the restructuring of transmission
system operations or administration. WEC currently cannot determine if such
restructuring will be required. In addition, Wisconsin State law limits the
total assets of non-utility affiliates of Primergy, which could affect the
amount of non-utility operations. See Item 1. BUSINESS - "NON-UTILITY
OPERATIONS" below.
Subject to the qualifications expressed below, WEC and NSP believe that
synergies from the Transaction will generate substantial cost savings to
Primergy, which would not be available absent the Transaction. Preliminary
estimates by the managements of WEC and NSP indicate that the Transaction
could result in potential net cost savings (that is, after taking into account
the costs incurred to achieve such savings) of approximately $2 billion during
the ten-year period from 1997 through 2006 assuming that the Transaction is
consummated at the beginning of 1997. Achieved savings in costs are expected
to inure to the benefit of both shareholders and customers. The treatment of
the benefits and cost savings will depend on the results of regulatory
proceedings in the various jurisdictions in which WEC and NSP operate their
businesses.
The analyses employed in order to develop estimates of potential savings as a
result of the Transaction were necessarily based upon various assumptions that
involve judgements with respect to, among other things, future national and
regional economic and competitive conditions, inflation rates, regulatory
treatment, weather conditions, financial market conditions, future business
decisions and other uncertainties, all of which are difficult to predict and
many of which are beyond the control of WEC and NSP. Accordingly, while WEC
and NSP believe that such assumptions are reasonable for purposes of the
development of estimates of potential savings, there can be no assurance that
such assumptions will approximate actual experience or that such savings will
be realized. The parties have proposed certain utility rate reductions and
rate freezes in connection with the Transaction. See Item 7. MANAGEMENT'S
DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS -
"RESULTS OF OPERATIONS - Mergers."
On September 13, 1995, the stockholders of WEC and NSP voted to approve the
merger. The Merger Agreement is subject to various conditions including
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ITEM 1. BUSINESS - Merger Agreement with NSP - (cont'd)
approval by all applicable regulatory authorities. Subject to obtaining all
requisite approvals, WEC and NSP anticipate completing the Transaction by
January 1, 1997.
The future operations and financial position of WE will be significantly
affected by the Transaction. Unaudited pro forma combined condensed financial
information for Wisconsin Energy Company at December 31, 1995 and for the
twelve months then ended is included in this report following Item 14.
EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K. Additional
information may be found in Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - "RESULTS OF OPERATIONS -
Mergers" and in Note B - "Mergers" in the NOTES TO FINANCIAL STATEMENTS in
Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
ELECTRIC UTILITY OPERATIONS
Electric energy sales by WE in 1995, to all classes of customers, totaled
approximately 27.3 billion kilowatt-hours, a 1.4% increase over 1994. On
July 31, 1995, WE reached a new all-time electric peak demand of 5,368
megawatts during a period of unusually hot and humid weather. The previous
record peak demand prior to the summer of 1995 of 4,950 megawatts was set on
June 14, 1994. Electric energy sales are impacted by seasonal factors and
varying weather conditions from year-to-year.
There were 955,616 electric customers at December 31, 1995, an increase of
1.1% since December 31, 1994. For further information by customer class, see
"Electric Revenues, Kilowatt-Hour Sales and Customer Statistics" in Item 6.
SELECTED FINANCIAL DATA.
In 1995, WE's net generation amounted to approximately 26.7 billion kilowatt-
hours. Generation was supplemented with approximately 2.3 billion kilowatt-
hours purchased from neighboring utilities and, to a minor extent, from other
sources. The dependable capability of WE's generating stations was 5,619
megawatts in August 1995 as more fully described in Item 2. PROPERTIES.
Paris Generating Station: During 1995, WE placed in service four units of
approximately 300 megawatts of capacity at its Paris Generating Station
("Paris"). This natural gas-fired combustion turbine facility, located near
Union Grove, Wisconsin, is designed to meet peak demand requirements. Capital
costs of the Paris facility will total approximately $105 million. For
additional information, see Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - "LIQUIDITY AND CAPITAL
RESOURCES - Investing Activities."
The supply of natural gas to operate Paris and WE's Concord Generating Station
("Concord"), a natural gas-fired combustion turbine facility located near
Watertown, Wisconsin, is delivered by the WEGO. See Item 1. BUSINESS -
"SOURCES OF GENERATION - Natural Gas (for Electric Generation)" below.
LS Power Generation Facility: In accordance with a PSCW order issued in
November 1993, after completing a capacity-related competitive bidding
process, WE signed a long-term agreement to purchase the electricity that
would be generated from a 215 megawatt cogeneration facility planned to be
constructed by an unaffiliated independent power producer ("IPP"), LSP-
Whitewater L.P. ("LS Power"). The agreement is contingent upon the facility
being completed and going into operation, which at this time is planned for
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ITEM 1. BUSINESS - Electric Utility Operations - (cont'd)
mid-1997. For additional information, see Item 7. MANAGEMENT'S DISCUSSION AND
ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - "LIQUIDITY AND
CAPITAL RESOURCES - Capital Requirements 1996-2000."
PSCW Advance Plan 7: In January 1994, WE filed with the PSCW its long-term
load and supply plan as part of the Advance Plan 7 Docket. In the Advance
Plan process, the regulated electric utilities located in Wisconsin file, for
planning purposes, long-term forecasts of future resource requirements along
with plans to meet those requirements, including the planned implementation of
energy management and conservation programs ("demand-side savings"). In
addition to specifying the expectations of conservation and load management
programs, the plan filed with the PSCW indicated a need for additional peaking
and intermediate load capacity during the 20-year planning period. WE does
not anticipate needing additional base load generation until after 2010. The
PSCW approved WE's Advance Plan 7 in December 1995. For additional
information regarding Advance Plans, see Item 1. BUSINESS - "REGULATION" below
and Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS - "LIQUIDITY AND CAPITAL RESOURCES - Capital
Requirements 1996-2000."
In Advance Plan 7, WE estimated peak demand in the year 2005 to be about 5,270
megawatts excluding the requirements of the Wisconsin Public Power Inc. System
("WPPI"), WE's largest municipal power agency customer. This estimate
assumes, among other things, moderate growth in the economy and normal
weather. This estimate does not, however, reflect any potential modifications
to the current regulatory environment. Investments in demand-side management
("DSM") programs have reduced and delayed the need to add new generating
capacity but have not eliminated the need entirely. Purchases of power from
other utilities and transmission system upgrades will also combine to help
delay the need to install some new generating capacity in the future. WE
plans to make continued expenditures for conservation-related programs during
this period. For additional information about WPPI, see Item 1. BUSINESS -
"Sales to Wholesale Customers" below.
The addition of new generating units requires approval of the PSCW following a
two-stage bidding process, which could influence whether WE would construct
such facilities or purchase the required power. The United States
Environmental Protection Agency ("EPA") and the Wisconsin Department of
Natural Resources ("DNR") also must approve new generating units. All
proposed generating facilities will meet or exceed the applicable federal and
state environmental requirements. For further information regarding future
capacity additions, see Item 1. BUSINESS - "REGULATION" below.
For information regarding estimated costs of WE's construction program for the
five years ending December 31, 2000, see Item 7. MANAGEMENT'S DISCUSSION AND
ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - "LIQUIDITY AND
CAPITAL RESOURCES - Capital Requirements 1996-2000." All estimates of
construction expenditures exclude Allowance For Funds Used During
Construction. For additional information regarding matters related to
Allowance for Funds Used During Construction, see Note E - "Allowance for
Funds Used During Construction" in the NOTES TO FINANCIAL STATEMENTS in
Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
Milwaukee County Power Plant: In December 1995, WE signed an agreement with
Milwaukee County to purchase the Milwaukee County Power Plant located in
Wauwatosa, Wisconsin. The 11 megawatt power plant provides steam, chilled
water and electricity for the Milwaukee Regional Medical Center and several
other large customers located on the Milwaukee County grounds. WE had
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ITEM 1. BUSINESS - Electric Utility Operations - (cont'd)
previously obtained approval from the PSCW for the purchase of the electric
generation and distribution facilities and acquired them in December 1995 with
a capital expenditure of $7 million. As part of the agreement, WE will also
acquire in 1996 the steam facilities and a non-utility affiliate of WEC will
acquire the chilled water facilities from Milwaukee County. Purchase of the
steam and chilled water portions of the plant is contingent upon PSCW approval
to acquire the steam facilities and upon the five major customers signing ten-
year steam and chilled water service agreements. See Item 1. BUSINESS -
"STEAM UTILITY OPERATIONS" as well as Item 7. MANAGEMENT'S DISCUSSION AND
ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - "LIQUIDITY AND
CAPITAL RESOURCES - Capital Requirements 1996-2000."
PSCW Electric Utility Investigation: The PSCW has conducted an investigation
into the state of the electric utility industry in Wisconsin, particularly its
institutional structure and regulatory regime, in order to evaluate what
changes would be beneficial for Wisconsin. The PSCW stated that this
investigation may result in profound and fundamental changes to the nature and
regulation of the electric utility industry in Wisconsin. For additional
information and related matters, see Item 1. BUSINESS - "REGULATION" below and
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS - "RESULTS OF OPERATIONS - Rates and Regulatory
Matters."
Wisconsin Electric Revitalization: In response to increasing competitive
pressures in the markets for electricity and natural gas, WE implemented a
revitalization process to increase efficiencies and improve customer service
by reengineering and restructuring the organization. The new structures
consolidated many business functions and simplified work processes. Due to
productivity improvements from the Revitalization program, staffing levels at
WE have been reduced during 1994 and 1995; 403 employees retired under an
early retirement option and 726 employees enrolled in severance packages. See
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS - "RESULTS OF OPERATIONS - Wisconsin Electric
Revitalization" and Note K - "Benefits Other Than Pensions" in the NOTES TO
FINANCIAL STATEMENTS in Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTAL DATA.
SOURCES OF GENERATION
The table below indicates sources of energy generation by WE for the year
ended December 31:
==============================================================================
1993 1994 1995 1996*
------ ------ ------ ------
Coal 67.0% 69.0% 70.3% 71.9%
Nuclear 30.8 29.0 26.9 25.2
Hydro-electric 1.7 1.4 1.6 1.5
Natural Gas 0.4 0.5 1.1 1.3
Oil 0.1 0.1 0.1 0.1
------ ------ ------ ------
TOTAL 100.0% 100.0% 100.0% 100.0%
==============================================================================
* Estimated assuming that there are no unforeseen contingencies such as
unscheduled maintenance or repairs. See Item 1. BUSINESS - "SOURCES OF
GENERATION - Nuclear" and Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - "RESULTS OF OPERATIONS -
Capital Requirements 1996-2000" for discussion of matters related to Point
Beach Nuclear Plant.
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ITEM 1. BUSINESS - Sources of Generation - (cont'd)
WE's average total fuel costs per million BTU's by fuel type for the year
ended December 31 are shown below:
==============================================================================
1993 1994 1995
------ ------ ------
Coal $ 1.26 $ 1.26 $ 1.28
Nuclear 0.39 0.39 0.43
Natural Gas 3.02 2.54 2.21
Oil 4.94 4.33 5.32
==============================================================================
Coal
WE diversifies its coal sources by purchasing from Northern Appalachia, the
Southern Powder River Basin (Wyoming) and the Raton Basin (New Mexico) mining
districts for the power plants in Wisconsin, and from the Uinta Region
(Colorado), central Appalachia and western mines for the Presque Isle Power
Plant in Michigan.
Approximately 75% of WE's 1996 coal requirements are expected to be delivered
by WE-owned unit trains. The unit trains will transport coal for the Oak
Creek and Pleasant Prairie Power Plants from Pennsylvania, New Mexico and
Wyoming mines. Coal from Pennsylvania mines is also transported via rail to
Lake Erie transfer docks and delivered to the Valley and Port Washington Power
Plants by lake vessels. Montana coal for Presque Isle is transported via rail
to Superior, Wisconsin, placed in dock storage and reloaded into lake vessels
for plant delivery. The Presque Isle central Appalachian origin and Colorado
origin coal is shipped via rail to Lake Erie and Lake Michigan (Chicago) coal
transfer docks, respectively, for lake vessel delivery to the plant. WE's
1996 coal requirements, projected to be 10.0 million tons, are 97% under
contract. WE does not anticipate any problem in procuring its remaining 1996
requirements through short-term or spot purchases and inventory adjustments.
Pleasant Prairie Power Plant: All of the estimated 1996 coal requirements at
this plant are presently covered by three long-term contracts.
Oak Creek Power Plant: All of the estimated 1996 coal requirements for this
plant are covered by one long-term contract and two short-term contracts. A
significant coal cost decrease is anticipated with the blending of lower cost
Wyoming sub-bituminous coal with bituminous coals.
Presque Isle Power Plant: This plant has six generating units designed to
burn bituminous coal and three other units designed to burn sub-bituminous
coal. The units burning sub-bituminous coal are supplied by one long-term
contract and two medium-term contracts, the annual volumes of which are
anticipated to be adequate to cover coal requirements through 1996.
Bituminous coal is generally purchased through one-year contracts from central
Appalachia and under a five-year contract for the Colorado origin coal.
Edgewater 5 Generating Unit: Coal for this unit, in which WE has a 25%
interest, is purchased by Wisconsin Power and Light Company, a non-affiliated
utility, which is the majority owner of the facility.
Valley and Port Washington Power Plants: These plants are both supplied
through a long-term contract that, in combination with coal supplied to WE's
other Wisconsin plants, allows the plants to meet the requirements of the
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ITEM 1. BUSINESS - Sources of Generation - (cont'd)
Wisconsin acid rain law. In the event of further air quality emission
requirements affecting these plants, the contract can be terminated without
liability.
The periods and annual tonnage amounts for WE's principal coal contracts are
as follows:
==============================================================================
Contract Period Annual Tonnage
--------------- --------------
Nov. 1987 to Dec. 1997 500,000(A)
Jan. 1980 to Dec. 2006 2,000,000
Jul. 1983 to Dec. 2002 1,000,000
Apr. 1990 to Nov. 1996 375,000(B)
Jan. 1992 to Dec. 2005 2,200,000
Oct. 1992 to Sep. 2007 800,000
Sep. 1994 to Aug. 1999 500,000
==============================================================================
(A) The contract can be extended if the total volume has not been
purchased by the respective termination dates.
(B) Annual volume can be increased to meet requirements for the Port
Washington and Valley Power Plants above the 375,000 ton volume
indicated herein.
For information regarding emission restrictions, see Item 1. BUSINESS -
"ENVIRONMENTAL COMPLIANCE" below.
Nuclear
WE purchases uranium concentrates ("yellowcake") and contracts for its
conversion, enrichment and fabrication. WE maintains title to the nuclear
fuel until the fabricated fuel assemblies are delivered to the Point Beach
Nuclear Plant ("Point Beach"), whereupon it is sold to and leased back from
the Wisconsin Electric Fuel Trust ("Trust"). See Note F - "Nuclear
Operations" in the NOTES TO FINANCIAL STATEMENTS in Item 8. FINANCIAL
STATEMENTS AND SUPPLEMENTARY DATA.
Uranium Requirements: WE requires approximately 450,000 pounds of yellowcake
annually for its two units at Point Beach. Uranium requirements through 1997
will be provided from a combination of existing contracts with Malapai
Resources Company (of Arizona); Energy Resources of Australia, Ltd.; and Nukem
Inc. (U.S.). WE may exercise flexibilities in these contracts and purchase
certain quantities of uranium on the spot-market, should market conditions
prove favorable. WE believes that adequate supplies of uranium concentrates
will be available to satisfy current and future operating requirements.
Under a contract with Nuexco Trading Corporation, WE was to receive 200,000
pounds of uranium concentrates on specified delivery dates in 1995 at
conversion facilities in the United States or Canada in exchange for the
transfer to Nuexco of an identical quantity of concentrates held by WE at the
conversion facilities of Comurhex in France. However, Nuexco is in default
under the contract and has filed for bankruptcy law protection. Upon
completion of review of various options available for use of the concentrates
located at Comurhex, WE decided to sell this material. A sales contract was
executed between WE and a uranium broker in December 1995.
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12
ITEM 1. BUSINESS - Sources of Generation - (cont'd)
Conversion: WE has a conversion contract with the Cameco Corporation, to
provide for up to 100 percent of conversion requirements for the Point Beach
reactors from 1996 through 1999. Cameco is a Canadian based corporation
located in Saskatoon, Saskatchewan, and is a major producer of uranium
concentrates.
Enrichment: WE currently has a Utility Services Contract with the United
States Department of Energy ("DOE") for 70% of the enrichment services
required for the operation of both of the Point Beach units. The contract can
provide enrichment services for the entire operating life of each unit. For a
discussion of litigation involving the Utility Services Contract, see Item 3.
LEGAL PROCEEDINGS - "OTHER LITIGATION - Uranium Enrichment Charges".
Responsibility for administering this contract and for enrichment services was
transferred from the DOE to U.S. Enrichment Corporation ("USEC") under the
Energy Policy Act of 1992. In March 1992, WE entered into an agreement with
Global Nuclear Services and Supply Limited, an international supplier of
enrichment services, for the remaining 30% of enrichment service requirements.
Fabrication: Fabrication of fuel assemblies from enriched uranium for Point
Beach is covered under a contract with Westinghouse Electric Corporation for
the balance of the plant's current operating license. During 1995, an
agreement was reached between WE and Westinghouse to supply WE with a new fuel
design beginning in the fall 1997. The new fuel design is expected to provide
additional safety margin, cost savings and reduce the number of discharged
spent fuel assemblies over the remaining operating license.
Spent Fuel Storage and Disposal: WE currently has the capability to store
certain amounts of spent nuclear fuel at Point Beach. Previous modifications
to the storage facilities at Point Beach had made it possible to accommodate
all spent fuel expected to be discharged from the reactors through 1995 while
maintaining the capability for one full core off-load. In accordance with the
provisions of the Nuclear Waste Policy Act of 1982, which requires the DOE to
provide for the disposal of spent fuel from all U.S. nuclear plants, WE
entered into a disposal contract providing for deliveries of spent fuel to the
DOE for ultimate disposal commencing in January 1998. It is anticipated that
the DOE will be unable to accept spent fuel by the 1998 timeframe as
contracted.
In November of 1991, WE filed an application with the PSCW for authority to
construct and operate an Independent Spent Fuel Storage Installation
("ISFSI"). The ISFSI provides interim dry cask storage until the DOE begins
to remove spent fuel from Point Beach in 1998 in accordance with the terms of
the contract it has with WE. Public hearings on the proposed project were
held during October 1994. On February 13, 1995, WE received a Certificate of
Authority from the PSCW to construct and operate the ISFSI for 12 storage
casks, which will handle the storage requirements until 1998. Should the DOE
be unable to begin taking ownership of and removing the spent fuel in 1998, WE
will need to construct additional casks and will seek PSCW approval to do so.
Construction of the ISFSI was completed in June 1995 and the first cask,
containing 24 spent fuel assemblies, was loaded and moved to the ISFSI during
December 1995. Transfer of additional spent fuel to the ISFSI has been
temporarily suspended by WE pending further action by the PSCW as described
below.
In March 1995 separate petitions were filed by intervenors in Dane County
Circuit Court and Fond du Lac County Circuit Court. The two petitions were
ultimately combined into one petition in Dane County Circuit Court ("Court").
The Dane County petition sought reversal of the order and a remand to the PSCW
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13
ITEM 1. BUSINESS - Sources of Generation - (cont'd)
directing it to deny WE's request for authorization to construct the dry cask
facility, or in the alternative, to correct the alleged errors in the PSCW's
order. On December 22, 1995, the Court issued a decision vacating and
remanding the February 1995 order of the PSCW, stating that the Environmental
Impact Statement prepared by the PSCW for this project was inadequate in two
respects. First, it did not adequately analyze the environmental impacts from
storage of spent fuel for a sufficient duration; second, it did not
sufficiently evaluate the alternative of employing a combination of renewable
energy sources and conservation in lieu of continued operation of Point Beach
beyond 1998. The Court also held that the PSCW failed to make the findings of
fact and conclusions of law, based on the record, demonstrating that it
properly considered the priorities of conservation, renewable and other energy
sources over nuclear sources to the extent cost effective, technically
feasible and environmentally sound. The PSCW issued two Supplemental
Environmental Impact Statements which address the deficiencies found by the
Court and held related hearings in February and March 1996. See Item 1.
BUSINESS - "SOURCES OF GENERATION - Point Beach Unit 2 Steam Generators" below
for related discussion and cross-references to additional information in this
report.
Point Beach Nuclear Plant: Point Beach provided 26.9% of WE's net generation
in 1995. The plant has two generating units which had a combined dependable
capability of 973 megawatts in August 1995 and which together constituted
17.3% of WE's dependable generating capability. As a result of degradation of
some of the tubes within the Unit 2 steam generators, the power level of Unit
2 has been administratively reduced by 10% to provide operating reliability
until the steam generators can be replaced, which is expected to occur in the
fall of 1996. See Item 1. BUSINESS - "SOURCES OF GENERATION - Point Beach
Unit 2 Steam Generators" below. The United States Nuclear Regulatory
Commission ("NRC") licenses for Point Beach Units 1 and 2 expire October 5,
2010 and March 8, 2013, respectively.
The NRC has, at various times, directed that certain inspections,
modifications and changes in operating practices be made at all nuclear
plants. At Point Beach, such inspections have been made and necessary changes
to equipment and in operating practices have either been completed or are
expected to be completed within the time schedules permitted by the NRC or
within approved extensions thereof. Good performance of Point Beach was
recognized by the Institute of Nuclear Power Operations ("INPO") with the
awarding of an INPO 1 rating to Point Beach in November 1995.
WE has initiated certain plant betterment projects at Point Beach that are
judged to be appropriate and beneficial. Construction is progressing on the
addition of two safety-related emergency diesel powered electrical generators
with installation to be completed in 1996.
Point Beach Unit 2 Steam Generators: On October 1, 1992, WE filed an
application with the PSCW for the replacement of the Unit 2 steam generators,
which would allow for the unit's operation until the expiration of its
operating license in 2013. This project is estimated to cost $96 million.
(In 1984 WE replaced the Unit 1 steam generators.) In an Interim Order dated
February 13, 1995, the PSCW deferred the decision on the steam generator
replacements until after the refueling outage in September 1995. The PSCW
directed WE to make suitable arrangements with the fabricator of the new steam
generators to allow the fabrication, delivery and replacement to proceed
promptly if authorized by the PSCW as a result of further investigation. The
reasonable costs of such arrangements to maintain a place in line with the
- 13 -
14
ITEM 1. BUSINESS - Sources of Generation - (cont'd)
fabricator will be afforded rate recovery. Work on the Unit 2 replacement
steam generators has continued such that delivery in July of 1996 can occur in
order to meet the schedule requirements for a fall 1996 replacement. In early
February 1996, the PSCW conducted hearings on a Supplemental Environmental
Impact Statement concerning the Unit 2 steam generator replacement and the
need for such replacement taking into account the information gained from
inspections conducted during the fall 1995 refueling and maintenance outage.
WE anticipates that the PSCW will issue a combined final order on replacement
of the Unit 2 steam generators and the remanded dry cask storage matters
discussed above in May 1996. Failure by the PSCW to approve the steam
generator replacements and resolve the remanded issues could jeopardize the
continued operation of Point Beach and materially affect WE's financial
position and results of operations due to the need to replace the lost
generating capacity. WE would likely seek regulatory relief to minimize such
impact. For additional information, see Item 7. MANAGEMENT'S DISCUSSION AND
ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - "LIQUIDITY AND
CAPITAL RESOURCES - Capital Requirements 1996-2000" and Note F - "Nuclear
Operations" in the NOTES TO FINANCIAL STATEMENTS in Item 8. FINANCIAL
STATEMENTS AND SUPPLEMENTARY DATA.
Decommissioning Fund: Pursuant to a 1985 PSCW order, amended in 1994, WE
provides for costs associated with the eventual decommissioning of Point Beach
through the use of an external trust fund. Payments to this fund, together
with investment earnings, brought the balance in the trust fund on
December 31, 1995 to approximately $275 million. For additional information
regarding decommissioning see Note F - "Nuclear Operations" in the NOTES TO
FINANCIAL STATEMENTS in Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
Nuclear Plant Insurance: For information regarding matters pertaining to
nuclear plant insurance, see Note F - "Nuclear Operations" in the NOTES TO
FINANCIAL STATEMENTS in Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
Hydroelectric
WE has various licenses from the FERC for its hydroelectric generating
facilities that expire during the period 1998 to 2004. In February 1996, WE
filed a final application for its largest hydro facility, Big Quinnesec Falls,
which has a license expiring in 1998. During 1995, FERC issued 30 and 40 year
licenses to the Pine and Brule Hydroelectric projects, respectively. The
Draft Environmental Impact Statement for the White Rapids and Chalk Hill
Hydroelectric Projects was published by FERC in November 1995. These two
projects continue to operate under annual licenses. The three hydro
facilities, Oconto Falls, Sturgeon and Weyauwega, with a total of 2.5
megawatts installed capacity, that WE decided not to relicense in 1993 are
still being operated by WE under annual licenses until FERC determines their
disposition. WE continues to consult with the U.S. Fish and Wildlife
Service, DNR, Michigan Department of Natural Resources ("MDNR"; now the
Michigan Department of Environmental Quality ("MDEQ")) and the National Park
Service in conjunction with the licensing process. Hydroelectric facilities
provided approximately 1.6% of WE's total energy generation in 1995.
Natural Gas (for Electric Generation)
Concord, Paris and the Oak Creek combustion turbine use natural gas as their
primary fuel, with Number 2 fuel oil as backup. Natural gas for Concord and
the Oak Creek gas turbines is purchased directly from the WEGO at tariff
- 14 -
15
ITEM 1. BUSINESS - Sources of Generation - (cont'd)
rates. Gas for Paris is purchased on the spot market - from gas marketers
and/or producers - and delivered on the WEGO local distribution system. A
balancing and storage agreement with ANR Pipeline facilitates the variable gas
usage pattern of Paris.
Natural gas for boiler ignition and flame stabilization purposes for the
Pleasant Prairie, Oak Creek, and Valley Power Plants is purchased under an
agency agreement with a gas marketing company. The agent purchases natural
gas and arranges for interstate pipeline transportation to the local gas
distribution utility. The local gas distribution utilities then transport
WE's gas to each plant under interruptible tariffs. WEGO is the distribution
utility for Pleasant Prairie and Oak Creek. Wisconsin Gas Company, a non-
affiliated company, is the distribution utility for the Valley Power Plant.
Oil
Fuel oil is used for the combustion turbines at Point Beach, Germantown and
Port Washington Power Plants. It is also used for boiler ignition and flame
stabilization at the Presque Isle Power Plant and as backup for ignition for
Pleasant Prairie and as a backup fuel for the natural gas fired gas turbines,
as discussed above. Fuel oil requirements are purchased under partnering
agreements with suppliers that assist WE with inventory tracking and oil
market price trends.
Interconnections with Other Utilities
WE's system is interconnected at various locations with the systems of Madison
Gas and Electric Company, Wisconsin Power and Light Company, Wisconsin Public
Service Corporation, Commonwealth Edison Company ("Commonwealth Edison"), NSP
and Upper Peninsula Power Company ("UPPCO"). These interconnections provide
for interchange of power to assure system reliability as well as facilitating
access to generating capacity and the transfer of energy for economic
purposes.
WE is a member of Wisconsin-Upper Michigan Systems ("WUMS"), a coordinating
group which includes four other electric companies in Wisconsin and Upper
Michigan. WUMS, in turn, is a member of Mid-America Interconnected Network
("MAIN"), which is one of nine regional members of the North American Electric
Reliability Council. Membership in these groups permits better utilization of
reserve generating capacity and coordination of long-range system planning and
day-to-day operations.
In March 1994, WE executed a transmission service agreement with Commonwealth
Edison that allows WE to purchase energy from southern Illinois and Indiana
suppliers, using the Commonwealth Edison transmission system to import such
energy into Wisconsin.
A transmission service agreement has been executed to allow WE to reserve
capacity and import energy from members of the Mid-Continent Area Power Pool
("MAPP"), a group consisting of electric utilities generally located west of
Wisconsin including NSP. Considerable non-firm energy is expected to be
purchased from MAPP members over the next several years.
In February 1996, WE and five other Midwest utilities announced that they had
agreed to pursue the development of an independent organization, the Midwest
Independent System Operator ("ISO"), which would be responsible for ensuring
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16
ITEM 1. BUSINESS - Sources of Generation - (cont'd)
nondiscriminatory open transmission access and the planning and security of
the combined bulk transmission systems of the utilities. In addition to WE,
the utilities signing a memorandum of understanding are American Electric
Power Co., Centerior Energy Corp., Cinergy Corp., Detroit Edison Co. and
Northern Indiana Public Service Co.. The other transmission owners of the
East Central Area Reliability Council ("ECAR") and MAIN will be invited to
participate in the development of the Midwest ISO. Plans for the Midwest ISO
are expected to be filed with the FERC in late 1996 and would be implemented
in stages after approval.
Sales to Wholesale Customers
WE currently provides wholesale electric energy to five municipally owned
systems, three rural cooperatives, two municipal joint action agencies and one
isolated system of an investor-owned utility in Wisconsin, Illinois, and the
Upper Peninsula of Michigan under rates approved by the FERC. Sales to these
wholesale customers accounted for 5.0% of total kilowatt-hour sales in 1995.
Under two agreements, service is being provided subject to a seven-year notice
of cancellation from the Wisconsin Public Power Inc. System ("WPPI"). WE also
has an eight-year power supply agreement with the Badger Power Marketing
Authority ("BPMA"). Sales to the BPMA and WPPI combined are expected to
account for approximately one half of the wholesale sales for 1996.
Service to UPPCO, under a 65 megawatt agreement which expires on
December 31, 1997, accounted for 20% of 1995 wholesale sales. In October
1993, UPPCO announced that it had reached an agreement in principle with NSP
to purchase up to 90 megawatts of base-load electric energy beginning in 1998.
WE expects to apply the 65 megawatts of capacity toward the electric energy
needs of new customers and toward the overall increase in system supply needs
anticipated by 1998.
During 1995, sales to wholesale customers declined 5.6% from 1994, largely the
result of reductions in sales to WPPI. WPPI has been reducing its purchases
from WE subsequent to acquiring generation capacity in 1990. Sales to WPPI
during 1993, 1994 and 1995 were approximately 944,000 megawatt-hours ("Mwh"),
725,000 Mwh and 627,000 Mwh, respectively. Further reductions are expected as
WPPI installs additional capacity. These sales reductions are not expected to
have a significant effect on future earnings. Under the provisions of a long-
term agreement, WE will continue to provide transmission services to WPPI.
WE's existing FERC tariffs also provide for transmission service to its
wholesale customers. During 1995, WE had nine customers taking transmission
service. For further information see Item 1. BUSINESS - "REGULATION" below.
In October 1992, the Energy Policy Act was signed into law. Passage of this
law has removed encumbrances and facilitates the entry of power producers and
power marketers into the already competitive bulk power market. Notable among
its provisions are the creation of a new class of energy producer called
Exempt Wholesale Generators ("EWGs"), who are exempt from the requirements of
PUHCA, and the rights that the Energy Policy Act provides them and utilities
to request a FERC order directing the provision of transmission service if
denied transmission access from utilities. The transmission aspects of this
law are expected to have little impact on WE since it has had open access
transmission tariffs on file with the FERC since 1980.
During 1995, WE reached agreement on new contracts of five or ten years in
length with four wholesale customers accounting for a total of 61.4 MW. Each
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17
ITEM 1. BUSINESS - Sources of Generation - (cont'd)
contract contained substantial discounts from previous rates. UPPCO, a fifth
8 MW wholesale customer, opted to obtain power supplies from another utility
for its Iron River System. Two other wholesale customers, accounting for a
total of 18 MW, have not yet made decisions on their choice of power supply.
WE is actively pursuing wholesale customers who are currently supplied by
other utilities.
In December 1995, WEC and NSP entered into a settlement agreement with certain
municipal Wisconsin intervenors that ended the latters' participation in the
FERC and state proceedings with respect to the Transaction. The settlement
agreement, which provides for certain rate reductions on power sales and
transmission services, is pending FERC action. See Item 1. BUSINESS - "MERGER
AGREEMENT WITH NORTHERN STATES POWER COMPANY" above for additional information
about the Merger Agreement with NSP.
The electric utility industry continues to become increasingly competitive.
Some municipal utilities are approaching competing utilities in a search for
lower energy prices. Additionally, some large industrial customers are
seeking regulatory changes that could permit retail wheeling to allow them to
seek proposals for energy from alternate suppliers. IPPs are also exploring
cogeneration projects which would provide process steam to customers in WE's
service territory and sell electricity to WE. Consequently, electric
wholesale and large retail customers of WE or other non-affiliated utilities
may determine, from time to time, to switch energy suppliers, purchase
interests in existing power plants or build new generating capacity, either
directly or through joint ventures with third parties. The advent of EWGs can
be expected to accelerate this practice. For additional information, see Item
7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS - "LIQUIDITY AND CAPITAL RESOURCES - Capital Requirements 1996-
2000."
GAS UTILITY OPERATIONS
Effective January 1, 1996, WEC merged its natural gas utility subsidiary,
Wisconsin Natural Gas Company ("WN"), into WE to form a single combined
utility subsidiary. In 1995, WE and WN obtained approval of the merger by the
PSCW as well as consent of the Michigan Public Service Commission ("MPSC") for
WE to assume WN's liabilities. The merger, approved by the stockholders of WE
in December 1994, is expected to improve customer service and reduce future
operating costs. Where applicable, references to WE include WN prior to the
merger.
Effective January 1, 1994, Wisconsin Southern Gas Company, Inc. ("WSG") was
acquired by WEC through a statutory merger of WSG into WN. WE continues to
use the acquired facilities of WSG for the distribution and transportation of
natural gas. For additional information, see Item 7. MANAGEMENT'S DISCUSSION
AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - "RESULTS OF
OPERATIONS - Mergers."
Total gas therms delivered by WE, including customer-owned gas transported,
increased 9.3% in 1995 compared to 1994, reflecting primarily colder winter
weather during 1995, which increased heating load, and warmer summer weather
during 1995, which increased deliveries to electric peak generation stations.
During 1995, approximately 6% of total deliveries were on interruptible rates.
WE's maximum daily send-out in 1995 was 630,823 Dths. A dekatherm ("Dth") is
- 17 -
18
ITEM 1. BUSINESS - Gas Utility Operations - (cont'd)
equivalent to ten therms or one million British Thermal Units ("BTU"). Sales
of gas fluctuate with the heating cycle of the year and are also impacted by
varying weather conditions from year-to-year.
The WEGO has entered into more than 45 gas service contracts for supply,
pipeline capacity, underground storage and balancing services. Contracts vary
in term from less than one year to ten years. Gas supply contracts contain
pricing options that allow pricing at market rates or the ability to fix
future prices for varying terms which the WEGO can exercise to manage the risk
of substantial market price fluctuations. The gas from these contracts is
used to meet customer requirements on a daily basis and to fill storage during
the warm months to be withdrawn from storage during the heating season in
order to meet system gas demands.
The use of storage increases the load factor of supply contracts and allows
the WEGO to take advantage of seasonal price differentials. The WEGO has
eight firm gas storage agreements that allow daily withdrawals of 313,608 Dths
and an annual capacity of 23 million Dths. The initial terms of these
contracts vary with the last one expiring in October 2003. This storage
effectively replaces storage used by the pipeline companies to provide gas
sales service to the WEGO in the pre-FERC Order 636 environment. Gas stored
at these facilities is purchased by the WEGO from a number of suppliers.
The WEGO has 12 transportation contracts, the last of which expires in 2003,
that it uses to meet daily customer requirements and to inject and withdraw
from gas storage. In each case, subject to certain provisions, the WEGO can
extend the terms of these contracts at the time the agreements would otherwise
expire.
The WEGO also has three contracts for salt dome storage that provide gas
supply backup in the event of well freeze-off or other loss of supply.
The WEGO transports gas for its customers who purchase gas directly from other
suppliers. Transported gas accounted for approximately 32% of total therms
delivered during 1995, 30% during 1994 and 31% during 1993.
There were 357,030 natural gas customers at December 31, 1995, an increase of
approximately 2.9% since December 31, 1994. For further information by
customer class, see "Gas Revenues, Therms Delivered and Customer Statistics"
in Item 6. SELECTED FINANCIAL DATA.
The WEGO delivers natural gas to WE's Concord and Paris Combustion Turbine
Power Plants. Deliveries to these peaking power plants are at rates approved
by the PSCW. See Item 1. BUSINESS - "SOURCES OF GENERATION - Natural Gas (for
Electric Generation)" above.
In 1995, the PSCW issued WE a certificate for construction of a gas pipeline
to provide gas transportation service to LS Power's proposed Whitewater
cogeneration facility. For additional information, see Item 1. BUSINESS -
"ELECTRIC UTILITY OPERATIONS" above.
SALES TO LARGE CUSTOMERS
WE provides utility service to a diversified base of industrial customers.
Major industries served by the electric operations include the iron ore mining
industry, the paper industry, the machinery production industry, the foundry
industry and the food products industry. The Empire and Tilden iron ore
- 18 -
19
ITEM 1. BUSINESS - Sales to Large Customers - (cont'd)
mines, the two largest electric customers of WE, accounted for 4.5% and 3.9%,
respectively, of total electric kilowatt-hour sales in 1995. Sales to the
mines were 0.5% lower in 1995 compared to 1994. In January 1996, new power
purchase agreements were executed with both mines which extend the term of the
agreements by five years, through December 31, 2002. See Item 7.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS - "RESULTS OF OPERATIONS - Electric Revenues, Gross Margins and
Sales." Major industries served by the WEGO include the paper industry, the
food products industry and the fabricated metal products industry. During
1995, WE's electric operations was the largest gas customer using 2.4% of
total therm deliveries. No single retail customer of the gas utility
accounted for more than 2.1% of total gas therms sold and transported in 1995.
STEAM UTILITY OPERATIONS
WE operates a district steam system in Downtown Milwaukee and the near
southside of Downtown Milwaukee. Steam is used by 473 customers for
processing, space heating, domestic hot water and humidification. Annual
sales of steam fluctuate from year to year based on system growth and
variations in normalized weather conditions. Steam is supplied to the system
from WE's Valley Power Plant, a coal-fired cogeneration facility.
The steam system consists of approximately 30 miles of both high pressure and
low pressure steam piping, 3.8 miles of walkable tunnels and other pressure
regulating equipment. Steam sales in 1995 were 2.53 billion pounds of steam
as compared to 2.39 billion pounds sold in 1994, an increase of 5.8%.
Milwaukee County Power Plant: WE has entered into an agreement with Milwaukee
County to acquire in 1996 the steam production and distribution facilities of
the Milwaukee County Power Plant located on the Milwaukee County Grounds in
Wauwatosa, Wisconsin. WE plans to integrate these facilities into its current
steam utility operations. This acquisition is contingent upon approval of the
PSCW and upon the five major customers signing ten-year steam service
agreements. See Item 1. BUSINESS - "ELECTRIC UTILITY OPERATIONS" above and
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS - "LIQUIDITY AND CAPITAL RESOURCES - Capital
Requirements 1996-2000."
REGULATION
WE is subject to the regulation of the PSCW as to retail electric, gas and
steam rates in Wisconsin, standards of service, issuance of securities,
construction of new facilities, transactions with affiliates, levels of short-
term debt obligations, billing practices and various other matters. WE is
also subject to the regulation of the MPSC as to the various matters
associated with retail electric service in Michigan as noted above except as
to issuance of securities, construction of certain new facilities, levels of
short-term debt obligations and advance approval of transactions with
affiliates. WE, with respect to hydro-electric facilities, wholesale power
service, electric transmission, gas transportation and accounting, is subject
to FERC regulation. Operation and construction relating to WE's Point Beach
facilities are subject to regulation by the NRC. WE's operations are also
subject to regulations of the EPA, the DNR and the MDEQ.
The PSCW is authorized to direct expenditures for promoting conservation if it
determines that the programs are in the public interest. Rate orders have
- 19 -
20
ITEM 1. BUSINESS - Regulation - (cont'd)
consistently included provisions for substantial conservation programs
initiated by WE. For additional information, see Note A - "Summary of
Significant Accounting Policies" in the NOTES TO FINANCIAL STATEMENTS in
Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
WE is subject to a power plant siting law in Wisconsin which requires that
electric utilities file updated long-term forecasts and plans (called "Advance
Plans") for the location, size and type of future large generating plants and
high voltage transmission lines about every two years for PSCW approval after
public hearings. Generally, the law provides that the PSCW may not authorize
the construction of any large generating plants or high voltage transmission
lines unless they are in substantial compliance with the most recently
approved plan. The law also prohibits WE from acquiring any interest in land
for such plants or transmission lines by condemnation until construction
authorization has been received. Advance Plan orders are based on a review of
the utilities' long-term planning options. However, separate project-specific
PSCW approval is required for the construction of generating facilities and
transmission lines.
WE employs a least-cost integrated planning process, which examines a full
range of supply and demand side options to meet its customers' electric needs,
such as the renovation of existing power plants, promotion of cost-effective
conservation and load management options, development of renewable energy
sources, purchased power and construction of new company-owned generation
facilities.
For additional information regarding Advance Plans, see Item 7. MANAGEMENT'S
DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS -
"LIQUIDITY AND CAPITAL RESOURCES - Capital Requirements 1996-2000."
In 1994, the PSCW ordered the state's utilities to competitively bid all new
generation needs in excess of 12 megawatts to be built in Wisconsin. The two-
stage process established by the PSCW consists of: (1) an all-parties
(including utilities) bidding procedure for fossil-fueled and renewable
generation projects and (2) the conventional Certificate of Public Convenience
and Necessity ("CPCN") procedure for the winner or winners. For additional
information regarding the CPCN process, see Item 7. MANAGEMENT'S DISCUSSION
AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - "LIQUIDITY AND
CAPITAL RESOURCES - Capital Requirements 1996-2000."
In 1992, the PSCW ordered that utilities should include a cost of $15 per ton
of carbon dioxide ("CO2") when comparing resource planning options (both
supply and demand-side) to account for the economic risk of future greenhouse
gas regulation. Appeals through 1993 and 1994 did not substantially change
the order. Recent supply and DSM plans included the greenhouse gas adder.
There are only minor differences in supply and DSM plans prepared with and
without the greenhouse gas adder.
PSCW Electric Utility Industry Investigation: The PSCW has conducted an
investigation into the state of the electric utility industry in Wisconsin,
particularly its institutional structure and regulatory regime, in order to
evaluate what changes would be beneficial for Wisconsin. In early 1995, the
PSCW formed an Electric Advisory Committee (the "Committee") comprised of
representatives from the utility, independent power and merchant businesses as
well as environmental and consumer advocates. The Committee met throughout
the year and discussed all aspects of the business to determine where the
introduction of competition would benefit consumers. The PSCW used the input
- 20 -
21
ITEM 1. BUSINESS - Regulation - (cont'd)
from the Committee to develop their proposal for restructuring of the
industry. The PSCW's proposal would permit all consumers to choose their
electricity provider as well as a competitive generation business. The
transmission and distribution portions of the business would remain regulated.
Several work groups and studies were recommended in the proposal to resolve
various issues that will allow for full retail competition by the year 2001.
WE will work throughout 1996 participating in these work groups and studies.
The restructuring envisioned in the proposal is similar to WE's view of
industry restructuring where all electric utility functions are separated into
two major categories - natural monopolies and competitive entities. The
natural monopolies are functions where a single entity can provide the lowest
cost (the transmission and distribution functions). The competitive entities
are functions where competition can provide the lowest cost (the generation
and energy merchant functions).
In WE's model, the re-regulated natural monopolies are the transmission and
distribution functions. Re-regulation of these entities would involve some
form of price cap and performance-standard operation rules. In the new
structure, the FERC would regulate the transmission systems through a regional
transmission group to ensure open access, comparable pricing, comparable
service and adequate cost recovery. The PSCW would regulate the distribution
function for reasonable price, reliability, public safety and customer
satisfaction.
The competitive entities in the WE model are the generation, customer service
and energy merchant functions. In the restructured electric utility industry,
utilities would unbundle costs into the individual components of generation,
transmission, distribution and service.
PSCW Natural Gas Utility Industry Investigation: The PSCW continued a generic
investigation of the natural gas industry in Wisconsin and addressed the
extent to which traditional regulation should be replaced with a different
approach. In conjunction with this generic investigation, the PSCW staff is
reviewing the use of the current purchased gas adjustment ("PGA") mechanism
which is designed to pass on to gas customers increases or decreases in the
cost of natural gas purchased for resale. A separate docket has been
established to review the PGA. WE is participating in these PSCW
investigations.
For additional information regarding the PSCW electric and gas utility
industry investigations, see Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - "RESULTS OF OPERATIONS - Rates
and Regulatory Matters."
RATE MATTERS
See Item 3. LEGAL PROCEEDINGS - "RATE MATTERS" and Item 7. MANAGEMENT'S
DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS -
"RESULTS OF OPERATIONS - Rates and Regulatory Matters" for a discussion of
rate matters, including recent rate changes and a discussion of the tariffs
and procedures with respect to recovery of changes in the costs of fuel,
purchased power and gas purchased for resale.
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22
ITEM 1. BUSINESS - (cont'd)
ENERGY EFFICIENCY
Utility involvement in energy efficiency is an area in which there may be
significant changes in the future as a result of the PSCW electric utility
industry investigation mentioned earlier. There was general agreement on the
Committee to begin to move responsibility for energy efficiency away from
utilities and toward competitive market forces.
WE has begun to move in this direction by reducing the areas in which it
provides direct customer rebates. For industrial and commercial electric and
natural gas customers, WE continues to provide energy evaluations identifying
cost-effective customer saving opportunities, as well as below market rate
financing for the purchase of energy efficiency equipment. In 1995, WE hired
a contractor to obtain energy efficiency among smaller customers, in part to
help develop the market for energy efficiency among these customers. The
contractor offers incentives for electric and natural gas customers to
encourage the purchase of energy efficient equipment and the removal of older
inefficient appliances from the system.
Efficient use of energy is not limited to reduced consumption. Time-of-use
rates for certain electric customers promote the shifting of electricity usage
to those times when electric generating facilities are not fully utilized.
Interruptible and curtailable rates, along with an energy cooperative-managed
load curtailment program, are offered to certain industrial customers to
control peak demand. Direct load control of central air conditioners is
available to most residential customers.
ENVIRONMENTAL COMPLIANCE
Compliance with federal, state and local environmental protection requirements
resulted in capital expenditures by WEC's utility subsidiary of approximately
$31 million in 1995. Expenditures incurred during 1995 included costs
associated with the replacement of the precipitators at Valley Power Plant,
the construction of the ISFSI at Point Beach and the installation of pollution
abatement facilities at WE's power plants, as well as the installation of
underground distribution lines and environmental studies associated with power
plants. Such expenditures are budgeted at approximately $15 million for 1996.
Operation, maintenance and depreciation expenses of WE's fly ash removal
equipment and other environmental protection systems are estimated to have
been $41 million in 1995. Other environmental costs, primarily for
environmental studies, amounted to $200,000 in 1995.
Solid Waste Landfills
WE provides for the disposal of non-ash related solid wastes and hazardous
wastes through licensed independent contractors, but federal statutory
provisions impose joint and several liability on the generators of waste for
certain cleanup costs. Remediation-related activity pertaining to specific
sites is discussed below.
Muskego Sanitary Landfill: In 1992, WE was informed by the EPA that it was
included in a group of approximately 50 potentially responsible parties
("PRPs") against which the EPA will issue orders requiring that the PRPs clean
up the Muskego Sanitary Landfill (located in Southeastern Waukesha County,
Wisconsin). On January 14, 1993, WE notified EPA that it was proceeding, with
other PRPs, to comply with the order. The first step toward remediation has
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ITEM 1. BUSINESS - Environmental Compliance - (cont'd)
been identified, with the WE portion of the $16.8 million effort identified as
$115,000 (paid in 1994). Remedial actions for the second step (Groundwater
Operable Unit Remedy) are being evaluated, with EPA recommending a limited
pump and treat option, estimated to cost $7.4 million. Costs will be
allocated among the PRPs based on their waste contribution to the site. WE
has been identified as one of the small waste contributors required to
contribute to the groundwater cleanup.
Maxey Flats Nuclear Disposal Site: In 1986, WE was advised by EPA that it is
one of a number of PRPs for cleanup at this low-level radioactive waste site
located in Morehead, Kentucky. The amount of waste contributed by WE was
significantly less than one percent of the total. Under the terms of a
consent decree agreed to by all parties, WE was to pay the amount of $164,000
(minus a small credit for an amount previously paid) as its share of the
settlement fund for site cleanup costs. This settlement was to be completed
in 1995, but has been held up by a lawsuit filed by the unions concerning the
amount of work on the cleanup to be done by union labor. The potential impact
on WE would be a limited increase in the settlement if additional labor costs
result from the lawsuit.
Manistique River/Harbor Area: WE received a request for information or PRP
letter from EPA on March 12, 1993. The letter states that the river/harbor
has PCB contamination. EPA has requested information regarding company PCB
and oil filled equipment management in the Manistique River drainage basin.
WE responded to this request on April 22, 1993. An additional information
request from EPA was responded to on January 4, 1995. WE has no reason to
believe that it is responsible in total or in part for the PCB contamination
in the Manistique River/harbor area. WE has learned through newspaper
articles that the EPA announced a preliminary plan to dredge most of the PCB-
contaminated sediments, with only limited capping along the breakwater. The
two identified PRPs, Manistique Papers and Edison Sault Electric Company, have
advocated installation of a permanent cap.
Kenosha Iron and Metal: WE received a request for information or PRP letter
from EPA on December 9, 1994. The letter requested information regarding any
involvement WE's Pleasant Prairie Power Plant may have had with this operation
in Kenosha, Wisconsin. A response to EPA was sent December 29, 1994,
indicating that WE had no reason to believe that the power plant or WE did any
business with Kenosha Iron and Metal. No response from EPA has been received
since this response.
Marina Cliffs Barrel Dump Site: WE received a special notice letter and
information request on March 25, 1994 from the DNR. The letter described a
release of hazardous substances at a former barrel reclamation facility and
landfill site, located in the City of South Milwaukee, Wisconsin, and
requested information on any business dealings WE may have had with this
former operation. This request for information was responded to on
April 26, 1994. An additional request for information or PRP letter, was
received on March 24, 1995. This request was responded to by WE in April
1995. Since that time a number of follow-up contacts have been made with EPA.
WE has no reason to believe that it is responsible for the contamination
problems at this site. While WE continues to believe it has no responsibility
at this site, the EPA, which has undertaken remediation activities at the
site, has refused to offer WE a buyout option. As a result, WE has joined a
group of PRPs who will fund the cleanup. No known cleanup schedule has been
set or remediation costs identified.
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24
ITEM 1. BUSINESS - Environmental Compliance - (cont'd)
ETSM Property: Iron cyanide bearing wastes were found both on property owned
by WE (ETSM facility), located in the City of West Allis, Wisconsin, and
adjacent landowners. The wastes were removed and properly disposed, with WE's
share of the cleanup at about $100,000. Adjacent landowners believe WE to be
the source of the material; however, records do not support that allegation.
WE has received a notice sent by one of the property owners, of its intent to
sue WE under the Resource Conservation and Recovery Act of 1976.
City of West Allis: The City of West Allis, Wisconsin discovered iron cyanide
bearing wastes on a parcel of property owned by the city at 113th St. and
Greenfield Ave. The source of the waste is believed to be process waste
hauled to the site from a former manufactured gas plant. The City of West
Allis alleges that WE was the source of this material and is pursuing action
against WE to remediate the site. This matter is pending. There is no reason
to believe that WE nor WN was the source of or involved in the disposal of the
iron cyanide bearing wastes on this property.
Lenz Oil: A request for information or PRP letter was received from EPA on
March 25, 1994. WSG was identified as the PRP because of used oil sent to the
Lenz Oil facility located in Lemont, Illinois. WSG was acquired by WEC on
January 1, 1994. A response was filed with EPA. No known cleanup schedule
has been set or remediation costs identified.
Boundary Road Landfill: WE was contacted by Waste Management, Inc. ("WMI") in
October 1995 requesting voluntary participation in the cleanup of its former
landfill. The landfill, formerly known as the Lauer Landfill, is a Superfund
site located in the Village of Menomonee Falls, Wisconsin. WMI is alleging
that waste from some of WE's service centers was disposed of at this site and
is now contributing to the environmental problems at the site. WE met with
WMI on February 12, 1996 to discuss the situation. No known cleanup schedule
has been set or remediation costs identified. This matter is pending.
Lake Geneva Service Center: The property, in Lake Geneva, Wisconsin, was
acquired as part of the acquisition of WSG. A groundwater problem was
identified by WSG reportedly caused by past disposal practices. In 1995, the
extent of contamination was defined, and a remediation system was designed and
installed. Approximately $200,000 was spent in 1995. Remaining remediation
costs are estimated to be approximately $150,000.
Ash Landfills
WE aggressively seeks environmentally acceptable, beneficial uses of its
combustion byproducts. However, ash materials have been, and to some degree,
continue to be disposed of in company-owned, licensed landfills. Some early
designed and constructed landfills may allow the release of low levels of
constituents resulting in the need for various levels of remediation. Where
WE has become aware of these conditions, efforts have been expended to define
the nature and extent of any release, and work has been performed to address
these conditions. These costs are included in the environmental operating and
maintenance costs for WE. Sites currently undergoing remediation include:
Presque Isle Landfill: WE entered into a consent order with the MDNR (now the
MDEQ) regarding conditions existing at an ash landfill site acquired by WE
when it purchased the Presque Isle Power Plant in 1988. WE's groundwater
monitoring program at the site detected elevated levels of certain substances
at the oldest portion of the landfill. WE has reconstructed, closed and
capped the landfill to prevent further leachate from entering the groundwater
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25
ITEM 1. BUSINESS - Environmental Compliance - (cont'd)
at an approximate cost of $2.6 million. A Remedial Action Plan was submitted
to the MDEQ in 1995 that includes limited groundwater monitoring to further
document the improvement in groundwater quality that has occurred at the site.
The cost to implement the Remedial Action Plan is estimated to not exceed
$100,000.
Highway 59 Landfill: In 1989, a sulfate plume was detected in the groundwater
beneath a WE-owned former ash landfill located in the Town of Waukesha,
Wisconsin. After notifying the DNR, WE initiated a five-year expanded
monitoring program. In response to a request from the DNR, WE prepared an
environmental contamination assessment of the landfill and submitted the
report to the DNR in July 1995. WE believes that any remediation plan
developed, approved and implemented for this site would not have a material
adverse effect on its financial condition.
Manufactured Gas Sites
WE's natural gas business unit is investigating the remediation of a number of
former manufactured gas plant ("MGP") sites. Operation at these MGP sites
ceased over 40 years ago. Limited remediation activities occurred at a number
of these sites during the 1980's, with removal of waste materials known to be
present at the time. In 1995, WE presented a plan to investigate and further
remediate sites to the DNR. During 1995, WE conducted site investigations at
four MGP sites and partial remediation activities were conducted at one site.
Approximately $1.6 million has been spent through December 31, 1995 for such
activities. Remediation costs to be incurred through the year 2000 have been
estimated to be $12 million, but the total costs are uncertain pending results
of further site specific investigations and the selection of site specific
remedial actions. In its September 11, 1995 letter order, the PSCW allowed WE
to defer MGP site remediation costs with final rate treatment of such costs to
be determined in future rate cases. As of December 31, 1995, WE has recorded
an accrued liability of $1.6 million for MGP site remediation and a related
deferred regulatory asset of $3.2 million. WE expects to accrue additional
MGP site remediation liabilities during 1996 as site specific investigations
are completed and site specific remedial actions are identified. WE will
seek rate recovery of these costs and does not anticipate that there will be a
material adverse effect on its net income or financial condition.
Air Quality - Acid Rain Legislation
In 1986, the Wisconsin Legislature passed legislation establishing new sulfur
dioxide ("SO2") limitations applicable to Wisconsin's five major electric
utilities, including WE. The law requires each of the five major electric
utilities to meet a 1.20 lb SO2 per million BTU corporate average annual
emission rate limit beginning in 1993. Prior to 1993, Wisconsin law limited
the total annual SO2 emissions from the five major electric utilities to
500,000 tons per year. During 1995, approximately 177,000 tons of SO2 were
emitted by such utilities, equivalent to an annual average emission rate of
0.88 lbs SO2 per million BTU.
WE's compliance plan to meet the SO2 limitations under Wisconsin's acid rain
law includes the increased use of low-sulfur coal at certain power plant
units. Some changes to existing power plant equipment were made to
accommodate the use of low-sulfur coals.
The 1990 amendments to the Federal Clean Air Act mandate significant
nationwide reductions in air emissions. Most significant to the country's
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26
ITEM 1. BUSINESS - Environmental Compliance - (cont'd)
electric utility companies are the "acid rain" provisions of the amendments
which are scheduled to limit SO2 and nitrogen oxide ("NOX") emissions in
phases. Phase I became effective in 1995 and Phase II will take effect in
2000. Phase I requirements had minimal impact on the Company because of
actions taken to meet the above-mentioned Wisconsin acid rain law. Phase II
requirements, together with separate ozone nonattainment provisions of the
Clean Air Act which may call for additional NOX reductions, however, will
necessitate the implementation of a compliance strategy which is not expected
to materially impact rates. Since a portion of the regulations that have been
issued by the EPA are not complete or are not yet final, the rate impact is
subject to change and will be reevaluated as needed.
For additional information regarding the impact of the Clean Air Act
Amendments, including estimates of the cost of compliance, see Item 7.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS - "LIQUIDITY AND CAPITAL RESOURCES - Environmental Issues."
OTHER
WE is authorized to provide electric and gas service in designated territories
in the state of Wisconsin, as established by indeterminate permits,
certificates of public convenience and necessity, or boundary agreements with
other utilities. WE provides electric service in certain territories in the
state of Michigan pursuant to franchises granted by municipalities.
Research and development expenditures of WE amounted to $6,427,000 in 1995,
$8,063,000 in 1994 and $8,629,000 in 1993. Such expenditures were primarily
for improvement of service and abatement of air and water pollution. Research
and development activities include work done by employees, consultants and
contractors, plus sponsorship of research by industry associations. In
addition to the foregoing amounts, the WEGO paid $1,033,000 in 1995, $766,000
in 1994 and $1,300,000 in 1993 for support of the Gas Research Institute
("GRI"). The GRI surcharge, currently assessed on all gas deliveries, is
calculated on pipeline utilization.
At December 31, 1995, WE employed 4,492 persons, of which 95 were part-time.
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ITEM 2. PROPERTIES
WE owns the following generating stations with 1995 capabilities as indicated:
==============================================================================
Dependable
No. of Capability In
Generating Megawatts (1)
Units at -----------------------
December August December
Name Fuel 1995 1995 1995
- ---- ---- ---------- ------- --------
Steam Plants:
Point Beach Nuclear 2 973 947
Oak Creek Coal 4 1,135 1,141
Presque Isle (2) Coal 9 612 612
Pleasant Prairie Coal 2 1,200 1,210
Port Washington Coal 4 322 324
Valley Coal 2 267 227
Edgewater (3) Coal 1 98 98
-- ----- -----
TOTAL STEAM 24 4,607 4,559
Hydro Plants (16 in number) 38 75 75
Germantown Combustion
Turbines Oil 4 212 252
Concord Combustion
Turbines Gas/Oil 4 332 376
Paris Combustion
Turbines (4) Gas/Oil 4 332 376
Other Combustion
Turbines & Diesel Gas/Oil 4 61 74
-- ----- -----
TOTAL SYSTEM 78 5,619 5,712
==============================================================================
(1) Dependable capability is the net power output under average operating
conditions with equipment in an average state of repair as of a given
month in a given year. Changing seasonal conditions are responsible
for the different capabilities reported for the winter and summer
periods in the above table. The values were established by test and
may change slightly from year to year.
(2) UPPCO, a non-affiliated utility, staffs and operates the Presque Isle
Power Plant under an operating agreement with WE which extends through
December 31, 1997.
(3) WE has a 25% interest in Edgewater 5 Generating Unit, which is operated by
Wisconsin Power and Light Company, a non-affiliated utility.
(4) During the second quarter of 1995, four units, or approximately 360
megawatts of additional peaking combustion turbine generation capacity,
were placed in service at WE's Paris Generating Station.
At December 31, 1995, the electric transmission and distribution system had
2,761 miles of transmission circuits, of which 639 miles were operating at 345
kilovolts, 123 miles at 230 kilovolts, 1,605 miles at 138 kilovolts, and 394
miles at voltage levels less than 138 kilovolts. At December 31, 1995, WE was
operating 23,004 pole miles of overhead distribution lines and 14,428 miles of
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ITEM 2. PROPERTIES - (cont'd)
underground distribution cable, as well as 360 distribution substations and
222,294 line transformers.
As of December 31, 1995, the gas distribution system includes approximately
7,040 miles of mains connected at 18 gate stations to the pipeline
transmission systems of ANR Pipeline Company, Natural Gas Pipeline Company of
America and Northern Natural Pipeline Company. WE has a liquefied natural gas
storage plant which converts and stores in liquefied form natural gas received
during periods of low consumption. The liquefied natural gas storage plant
has a send-out capability of 70,000 Dths per day. WE also has propane tanks
for peaking purposes. These tanks will provide approximately 7,000 Dths of
supply to the system.
WE owns various office buildings and service centers throughout its service
area. The principal properties of WE are owned in fee except that the major
portion of electric transmission and distribution lines and steam distribution
mains and gas distribution mains and services are located, for the most part,
on or in streets and highways and on land owned by others. Substantially all
utility property is subject to first mortgage liens.
ITEM 3. LEGAL PROCEEDINGS
ENVIRONMENTAL MATTERS
WE is subject to federal, state and certain local laws and regulations
governing the environmental aspects of its operations. WE believes that, with
immaterial exceptions, its existing facilities are in compliance with
applicable environmental requirements.
Stephenson Building: On September 21, 1994, Crown Life Insurance Company sued
WE in the United States District Court for the Eastern District of Wisconsin,
seeking contribution and damages from WE under various federal and state
claims for the unspecified costs of removing asbestos from boilers and piping
in a building in downtown Milwaukee owned by Crown Life. WE sold that
equipment and piping to a former building owner in 1970. WE is defending this
lawsuit.
See Item 1. BUSINESS - "ENVIRONMENTAL COMPLIANCE" for a discussion of matters
related to certain solid waste and ash landfills and manufactured gas plant
sites.
RATE MATTERS
Wisconsin Retail Jurisdiction
Fuel Cost Adjustment Procedure: WE's electric retail rates in Wisconsin do
not contain an automatic fuel adjustment clause, but can be adjusted by the
PSCW if actual cumulative fuel and purchased power costs, when compared to the
costs projected in the retail electric rate proceeding, deviate from a
prescribed range and are expected to continue to be above or below the
authorized annual range of 3%. WE steam rates also contain a provision to
adjust rates to reflect varying fuel costs for all customers except for a
large volume contract representing approximately 13% of steam sales in 1995.
WE believes that it has the ability to maintain low fuel costs through
efficient management of its power supply system and fuel procurement
practices. Therefore, WE has proposed, in its 1997 Test Year filing with the
PSCW, the elimination of the retail electric fuel cost adjustment procedure.
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ITEM 3. LEGAL PROCEEDINGS - Rate Matters - (cont'd)
1995 Fuel Cost Adjustment: Effective August 4, 1994, the PSCW authorized WE
to reduce Wisconsin retail electric rates, through the use of a fuel
adjustment credit, to reflect lower fuel and purchased power expenses. The
adjustment reduced Wisconsin retail electric revenue by approximately $16.7
million through December 31, 1995. Effective January 1, 1996, the fuel
adjustment credit was removed from Wisconsin retail electric rates. Under
WE's proposal in the 1997 Test Year filing to eliminate the fuel cost
adjustment credit, the level of fuel expense currently included in rates will
continue until rates are revised by the PSCW in a rate case.
Purchased Gas Adjustment Tariffs: Sales of natural gas are subject to
adjustment tariffs designed to pass on to gas customers increases or decreases
in the cost of natural gas purchased for resale. For additional information,
see Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS - "RESULTS OF OPERATIONS - Rates and Regulatory
Matters."
1995 Test Year: In 1993 the PSCW discontinued the practice of conducting
annual rate case proceedings, replacing it with a new schedule which calls for
future biennial rate cases. As a result, no electric, gas or steam filings
were made with respect to the 1995 test year.
1996 Test Year: On May 1, 1995, WE filed with the PSCW required data related
to the 1996 test year. This was an abbreviated filing since no increase in
rates was requested. At the PSCW's open meeting on August 21, 1995, the PSCW
determined that Wisconsin retail rates for 1996 should be decreased from
existing levels. In a letter order dated September 11, 1995, the PSCW
directed WE to implement rate decreases for Wisconsin retail electric, gas and
steam customers of $33.383 million or 2.75%, $8.298 million or 2.6% and $0.790
million or 5.1%, respectively, on an annualized basis effective
January 1, 1996. The decrease is based upon a regulatory return on common
equity of 11.3%, down from 12.3% authorized since 1993.
1997 Test Year: On January 16, 1996, WE filed specific financial data with
the PSCW related to the 1997 test year showing an $82.2 million revenue
deficiency for its utility operations. The dollar impacts and percentage
increases requested for Wisconsin retail electric, gas and steam customers are
$77.0 million or 6.2%, $4.3 million or 1.4% and $0.9 million or 6.4%,
respectively, on an annualized basis. On March 15, 1996, WE filed testimony
and exhibits with the PSCW related to the 1997 test year. The PSCW had
determined that it required a special full review of WE's rates for the 1997
test year in connection with consideration of the application for approval of
the proposed merger of WEC and NSP. For additional information regarding the
merger of WEC and NSP, see Item 1. BUSINESS - "MERGER AGREEMENT WITH NORTHERN
STATES POWER COMPANY", Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - "RESULTS OF OPERATIONS -
Mergers" and Note B - "Mergers" in the NOTES TO FINANCIAL STATEMENTS in
Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
Wholesale Electric Jurisdiction
Fuel and Purchased Power Adjustment Tariffs: Some customers served under WE's
wholesale rates are subject to an automatic fuel adjustment provision to
reflect varying fuel and purchased power costs. Wholesale sales to municipals
and cooperatives represented approximately 5% of total electric sales in 1995.
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30
ITEM 3. LEGAL PROCEEDINGS - Rate Matters - (cont'd)
Michigan Retail Electric Jurisdiction
1996 Test Year: Effective January 1, 1996, the MPSC authorized an annualized
rate decrease of $1.13 million or 3.3% for WE's non-mine retail electric
customers. Excluding sales to the two mine customers, which are separately
regulated by the MPSC, retail electric sales in Michigan account for
approximately 2% of WE's total kilowatt-hour sales.
Power Supply Cost Recovery Clause: In the past, rates were adjusted to
reflect varying fuel and purchased power costs through a power supply cost
recovery ("PSCR") clause in WE's tariffs. Such PSCR clause provided for,
among other things, an annual filing of a PSCR plan and, after notice and an
opportunity for hearing, the development of PSCR factors to be applied to
customers' bills during the period covered by the PSCR plan to allow WE to
recover its costs of fuel and purchased power transactions, as estimated in
its annual filing. The amounts so collected were subject to a reconciliation
proceeding conducted by the MPSC at the end of the period covered by the plan
for recovery of any undercollections of actual costs or for refund or credit
of any amounts in excess of its actual costs in such period. On
November 30, 1994, the MPSC approved the proposed PSCR credit factor of
$.00535 per kilowatt-hour for the year 1995. Effective December 15, 1995, the
MPSC authorized suspension of the PSCR clause for a five-year period. The
existing PSCR credit factor of $.00535 per kilowatt-hour was rolled into the
energy rate.
FERC Order 636 Transition Costs
As a result of the FERC's Order 636, pipeline companies are no longer in the
merchant business and are billing transition costs, such as Gas Supply
Realignment and stranded capacity costs, to their customers. Due to the
netting of refunds against liabilities in 1995, the net remaining transition
costs to be billed to WE are currently estimated to be $2.0 million. This
estimate includes the amount attributable to WSG, which was merged into WN
effective January 1, 1994. The PSCW is allowing local gas distribution
companies to pass these costs on to their customers through the purchased gas
adjustment mechanism.
For additional information see Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - "RESULTS OF OPERATIONS - Rates
and Regulatory Matters."
Stray Voltage
In March 1996, technical hearings were concluded in a PSCW proceeding to
further evaluate the results of stray voltage research that has been completed
since 1989 and to update, if necessary, PSCW policies regarding stray voltage
that were included in a 1989 PSCW order. WE expects the PSCW to issue an
updated order on stray voltage in April 1996 but does not anticipate that it
will have a significant impact on WE's financial position or results of
operations.
OTHER LITIGATION
Spent Fuel Storage and Disposal: See Item 1. BUSINESS - "SOURCES OF
GENERATION - Nuclear" for information concerning the PSCW's approval of WE's
application to utilize dry cask storage for spent nuclear fuel generated at
Point Beach Nuclear Plant and pending legal proceedings with respect to the
PSCW's decision.
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ITEM 3. LEGAL PROCEEDINGS - Other Litigation - (cont'd)
Pittsburg & Midway Case: In a matter brought before the FERC, in July 1993,
WE filed an initial brief supporting its right to retain coal reclamation
costs collected through the wholesale fuel adjustment clause in 1986 that it
believes were prudently incurred in a settlement with the Pittsburg & Midway
Coal Mining Company. Of the total costs involved, the portion recovered
through the wholesale fuel clause amounts to approximately $750,000. This
filing was made in response to a FERC audit staff determination that WE should
have applied for a waiver of the FERC's fuel clause regulations in order to
attempt to pass through the wholesale portion of the settlement costs. On
December 13, 1995, the administrative law judge issued an initial decision
that WE was required to refund the portion of such costs collected from its
wholesale customers. The administrative law judge's initial decision found in
favor of WE with respect to the prudence of the administration of the coal
contracts. The matter is pending before the full commission.
In November 1993, the FERC rejected WE's request to be allowed to recover, in
wholesale rates in the future, the amount which may have to be refunded to
customers in the event of an unfavorable ruling in the pending fuel adjustment
clause proceeding concerning the Pittsburg & Midway reclamation charges. In
January 1994, WE filed an appeal with the U.S. Court of Appeals for the
District of Columbia Circuit regarding this rejection. The matter is pending.
Electromagnetic Fields: Claims are being made or threatened with increasing
frequency against electric utilities across the country for bodily injury,
disease or other damages allegedly caused or aggravated by exposure to
electromagnetic fields ("EMFs") associated with electric transmission and
distribution lines. Results of scientific studies conducted to date do not
establish the existence of a causal connection between EMFs and any adverse
health effects. WE believes that its facilities are constructed and operated
in accordance with all applicable legal requirements and standards. WE does
not believe that any claims thus far made or threatened against it in
connection with EMFs will result in any substantial liability on the part of
WE.
Uranium Enrichment Charges: On February 9, 1995, WE and ten other utilities
filed an action against the USEC in the U.S. Court of Federal Claims
challenging the final decision of the USEC contracting officer in November
1994 which denied claims of the utilities for damages by reason of overcharges
for uranium enrichment services provided under Utility Services Contracts
between July 1, 1993 and September 30, 1994. The damages sought by WE total
$3.3 million. The matter is pending.
Personal Injury Suit: On October 1, 1994, a jury returned a $2.85 million
verdict against WN, which was merged into WE effective January 1, 1996, in a
case in the Circuit Court for Milwaukee County, involving a gas pipe fire
which injured the plaintiff. On December 23, 1994, WN resolved the litigation
between itself and plaintiff with a payment of $2.55 million to plaintiff, of
which $550,000 was covered by WN's general liability insurer. The contract
with the construction company that installed the gas pipe provides for
indemnification of WN. On September 8, 1995, WN commenced an action for such
indemnification in Milwaukee County Circuit Court against the construction
company and its insurers. The matter is pending.
- 31 -
32
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matters were submitted to a vote of WE's security holders during the fourth
quarter of the fiscal year covered by this report.
EXECUTIVE OFFICERS OF THE REGISTRANT
The names, ages at December 31, 1995 and positions of the executive officers
of WE are listed below along with their business experience during the past
five years. All officers are appointed for one year terms or until their
respective successors are duly chosen. There are no family relationships
among these officers, nor is there any agreement or understanding between any
officer and any other person pursuant to which the officer was selected.
Current Position(s) and
Business Experience
Name and Age During Past Five Years
- ---------------------- ----------------------
Richard A. Abdoo, 51 Chairman of the Board, President and Chief
Executive Officer of WEC since 1991; Executive
Vice President, 1990 to 1991; Director of WEC
since 1988.
Chairman of the Board and Chief Executive Officer
of WE since 1990; Director of WE since 1989.
Chairman of the Board and Chief Executive Officer
of WN, a former subsidiary of WEC that was
merged into WE on January 1, 1996, from 1990
through 1995; Director of WN from 1989 through
1995.
Richard R. Grigg, Jr., 47 Vice President of WEC since January 1995; Director
of WEC since May 1995.
President and Chief Operating Officer of WE since
January 1995; Group Executive and Vice
President, June to December 1994; Vice
President, 1990 to June 1994; Director of WE
since 1994.
President and Chief Operating Officer of WN during
1995; Director of WN during 1995.
David K. Porter, 52 Senior Vice President of WE since 1989; Director of
WE since 1989.
Vice President of WN from 1989 through 1995;
Director of WN from 1988 through 1995.
Calvin H. Baker, 52 Treasurer and Chief Financial Officer of WEC
since March 1996.
Chief Financial Officer of WE since March 1996;
Vice President-Finance of WE since 1994; Vice
President-Marketing, 1992 through 1993; Vice
President-Finance 1991 to 1992.
Senior Vice President, Financial Services
Corporation of New York City (provider of
direct loan programs and industrial
development projects in New York City),
1989 to 1991.
- 32 -
33
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
Executive Officers of the Registrant - (cont'd)
Current Position(s) and
Business Experience
Name and Age During Past Five Years
- ---------------------- ----------------------
Ann Marie Brady, 43 Secretary of WEC since March 1996; Assistant
Secretary of WEC from 1989 to March 1996.
Vice President-External Affairs of WE since
March 1996; Secretary of WE since 1994;
Assistant Secretary, 1989 through 1993.
Secretary of WN, 1993 through 1995; Assistant
Secretary, 1989 through 1993.
Francis Brzezinski, 44 Vice President of WEC since 1990.
Vice President-Business Development of WE
since 1994.
President and Chief Operating Officer of Wispark
Corp., Wisvest Corp., and Witech Corp.
since 1990.
Charles T. Govin, Jr., 49 Vice President - Gas Operations of WE since
January 1996.
Vice President of WN, September 1994 to December
1995; General Manager of WN during 1994 and
1995; Director of Administrative Services of
WN, 1991 to 1993; Director of WN, June to
December 1995.
Anne K. Klisurich, 48 Controller of WEC since June 1995; Accounting
Manager of WEC, 1987 to 1994.
Controller of WE since 1994.
Controller of WN from 1994 through 1995.
Kristine M. Krause, 41 Vice President - Fossil Operations of WE since
1994; Manager of Valley Power Plant and Steam
Services, 1992 to 1994; Manager of Technical &
Administrative Services, 1991 to 1992; General
Superintendent - Technical Services & Control,
1990 to 1991.
Robert E. Link, 44 Vice President - Nuclear Power of WE since 1992;
Vice President - Marketing, 1991 to 1992;
Assistant Vice President - Marketing, 1990 to
1991.
Kristine A. Rappe, 39 Vice President - Customer Services (formerly Sales,
Service and Marketing) of WE since 1994;
Regional Manager of Customer Operations - Fox
Valley Region, 1991 to 1994; Assistant Regional
Manager of Customer Operations - Fox Valley
Region during 1991; Manager - Marketing
Department, 1990 to 1991.
- 33 -
34
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND
RELATED STOCKHOLDER MATTERS
The amount of cash dividends declared on WE's Common Stock during the two most
recent fiscal years are set forth below. Dividends were paid to WE's sole
common stockholder, WEC.
==============================================================================
Quarter Total Dividend *
- ------------------------------------------------------------------------------
1994 1 $ 36,325,000
2 $ 38,208,667
3 $ 38,208,667
4 $ 38,208,667
- ------------------------------------------------------------------------------
1995 1 $ 38,208,667
2 $ 40,455,444
3 $ 40,455,444
4 $ 40,455,444
==============================================================================
* Includes dividends paid by WN in 1994 and 1995.
- 34 -
35
ITEM 6. SELECTED FINANCIAL DATA
WISCONSIN ELECTRIC POWER COMPANY ***
SELECTED FINANCIAL DATA
===============================================================================================
Year Ended December 31 1995 1994 1993** 1992** 1991**
- ---------------------- ---------- ---------- ---------- ---------- ----------
(Thousands of Dollars)
Earnings available
for common stockholder $ 239,465 $ 180,403* $ 187,703 $ 170,034 $ 188,554
Operating revenues
Electric $1,437,480 $1,403,562 $1,347,844 $1,298,723 $1,292,809
Gas 318,262 324,349 331,301 283,699 273,803
Steam 14,742 14,281 14,090 13,093 12,986
---------- ---------- ---------- ---------- ----------
Total operating revenues $1,770,484 $1,742,192 $1,693,235 $1,595,515 $1,579,598
========== ========== ========== ========== ==========
Total assets $4,318,924 $4,202,193 $4,078,973 $3,623,838 $3,366,063
Long-term debt and preferred stock-
redemption required $1,325,169 $1,257,776 $1,274,476 $1,280,012 $1,171,017
- -----------------------------------------------------------------------------------------------
Sales and Customers
Electric
Megawatt-hours sold 27,283,869 26,911,363 25,685,436 24,747,581 25,016,247
Customers (End of year) 955,616 944,855 932,285 919,466 907,871
Gas
Therms delivered (Thousands) 886,729 811,219 809,348 772,036 767,071
Customers (End of year) 357,030 347,080 336,571 327,247 317,891
Steam
Pounds sold (Millions) 2,532 2,395 2,376 2,284 2,282
Customers (End of year) 473 471 459 472 468
===============================================================================================
QUARTERLY FINANCIAL DATA
===============================================================================================
(Thousands of Dollars)
- -----------------------------------------------------------------------------------------------
March June
Three Months Ended 1995 1994 1995 1994
- ------------------ --------- --------- --------- ---------
Total operating revenues $ 471,122 $ 509,681 $ 405,093 $ 400,340
Operating income 84,572 43,436* 72,848 63,854
Earnings available
for common stockholder 62,121 22,712* 51,249 42,885
- -----------------------------------------------------------------------------------------------
- -----------------------------------------------------------------------------------------------
September December
Three Months Ended 1995 1994 1995 1994
- ------------------ --------- --------- --------- ---------
Total operating revenues $ 426,413 $ 400,512 $ 467,856 $ 431,659
Operating income 80,704 71,248 90,897 84,735
Earnings available
for common stockholder 58,679 50,796 67,416 64,010
===============================================================================================
<FN>
Quarterly results of operations are not directly comparable because of seasonal and other factors.
See MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.
Earnings and dividends per share are not provided as all of WE's common stock is held by WEC.
* Includes nonrecurring $73.9 million charge in 1994 ($45 million net of tax) related to WE's
Revitalization program.
** Restated to reflect the merger of Wisconsin Southern Gas Company, Inc. ("WSG") into Wisconsin
Natural Gas Company ("WN") effective on January 1, 1994.
*** Where applicable, prior year financial and statistical information has been restated to
include WN at historical values.
- 35 -
36
Electric Revenues, Kilowatt-Hour Sales and Customer Statistics
Year Ended December 31 1995 1994 1993 1992 1991
- ---------------------- ---------- ---------- ---------- ---------- ----------
Operating Revenues ($000)
Residential $ 507,416 $ 484,627 $ 472,903 $ 441,240 $ 444,542
Small commercial and industrial 423,039 406,043 386,736 372,213 363,906
Large commercial and industrial 401,794 398,179 380,482 381,083 372,768
Other retail 13,505 13,750 13,975 15,245 15,368
Resale - municipals 55,813 55,508 57,039 62,787 71,382
---------- ---------- ---------- ---------- ----------
Total retail and municipals 1,401,567 1,358,107 1,311,135 1,272,568 1,267,966
Resale - public utilities 24,811 31,295 25,879 18,080 18,476
---------- ---------- ---------- ---------- ----------
Total revenue from sales 1,426,378 1,389,402 1,337,014 1,290,648 1,286,442
Other operating revenue 11,102 14,160 10,830 8,075 6,367
---------- ---------- ---------- ---------- ----------
Total Operating Revenues $1,437,480 $1,403,562 $1,347,844 $1,298,723 $1,292,809
========== ========== ========== ========== ==========
Kilowatt-hour Sales (Millions)
Residential 7,043 6,670 6,551 6,230 6,567
Small commercial and industrial 7,047 6,699 6,358 6,155 6,153
Large commercial and industrial 10,640 10,472 9,771 9,702 9,462
Other retail 182 189 196 217 226
Resale - municipals 1,369 1,415 1,580 1,779 1,935
---------- ---------- ---------- ---------- ----------
Total retail and municipals 26,281 25,445 24,456 24,083 24,343
Resale - public utilities 1,003 1,466 1,229 665 673
---------- ---------- ---------- ---------- ----------
Total Sales 27,284 26,911 25,685 24,748 25,016
========== ========== ========== ========== ==========
Number of Customers - Average
Residential 857,924 846,745 835,685 824,544 814,078
Small commercial and industrial 90,386 88,765 87,351 85,990 84,540
Large commercial and industrial 679 674 675 670 664
Other 1,821 1,811 1,831 1,945 1,980
---------- ---------- ---------- ---------- ----------
Total 950,810 937,995 925,542 913,149 901,262
========== ========== ========== ========== ==========
Gas Revenues, Therms Delivered and Customer Statistics
Year Ended December 31 1995 1994 1993** 1992** 1991**
- ---------------------- ---------- ---------- ---------- ---------- ----------
Operating Revenues ($000)
Residential $ 194,226 $ 200,824 $ 199,509 $ 175,824 $ 170,827
Commercial and Industrial 94,482 102,496 102,425 82,853 77,031
Interruptible and other 12,763 15,338 12,858 9,406 9,959
---------- ---------- ---------- ---------- ----------
Total revenues from sales 301,471 318,658 314,792 268,083 257,817
Other operating revenue 16,791 5,691 16,509 15,616 15,986
---------- ---------- ---------- ---------- ----------
Total Operating Revenues $ 318,262 $ 324,349 $ 331,301 $ 283,699 $ 273,803
========== ========== ========== ========== ==========
Therms Delivered (Thousands)
Residential 345,140 323,913 322,444 309,968 308,980
Commercial and Industrial 207,358 199,206 202,549 183,588 176,707
Interruptible and other 50,646 47,467 34,608 24,710 26,442
---------- ---------- ---------- ---------- ----------
Total Sales 603,144 570,586 559,601 518,266 512,129
Transportation of Customer
Owned Gas 283,585 240,633 249,747 253,770 254,942
---------- ---------- ---------- ---------- ----------
Total Delivered 886,729 811,219 809,348 772,036 767,071
========== ========== ========== ========== ==========
Number of Customers - Average
Residential 321,643 311,288 302,355 293,437 284,728
Commercial and Industrial 29,287 28,506 27,871 27,291 26,536
Interruptible and other 361 340 356 376 404
---------- ---------- ---------- ---------- ----------
Total 351,291 340,134 330,582 321,104 311,668
========== ========== ========== ========== ==========
Degree Days (Milwaukee)
Heating (Normal 7,020) 6,825 6,431 6,775 6,723 6,416
Cooling (Normal 650) 953 877 651 364 1,056
** Restated to reflect the merger of WSG into WN effective on January 1, 1994.
- 36 -
37
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS
Effective January 1, 1996, Wisconsin Energy Corporation ("WEC"), Wisconsin
Electric Power Company's ("WE" or the "Company") parent company, merged its
natural gas utility subsidiary, Wisconsin Natural Gas Company ("WN"), into WE
to form a single combined utility subsidiary. Where applicable, references to
WE include WN prior to the merger and financial and statistical information
has been restated to include WN at historical values. Additional information
concerning the merger may be found below under "RESULTS OF OPERATIONS -
Mergers" and in Note B - "Mergers" in the NOTES TO FINANCIAL STATEMENTS.
As previously reported, WEC has entered into an agreement with Northern States
Power Company, a Minnesota corporation ("NSP"), which provides for a strategic
business combination involving the two companies in a "merger-of-equals"
transaction. The future operations and financial position of WE will be
significantly affected by the proposed merger. Consummation of the proposed
merger is subject to a number of conditions, including obtaining all required
regulatory approvals. Additional information concerning such agreement and
proposed transaction may be found below under "RESULTS OF OPERATIONS -
Mergers" and in Note B - "Mergers" in the NOTES TO FINANCIAL STATEMENTS
(including unaudited pro forma financial information).
RESULTS OF OPERATIONS
Earnings
1995 Compared to 1994: Earnings Available for Common Stockholder ("Earnings")
of WE increased to $239 million in 1995 compared to $180 million in 1994, an
increase of 32.8%. Earnings during 1994 reflect a nonrecurring charge of
approximately $73.9 million ($45 million net of tax) associated with the
organizational restructuring program at WE.
The 1994 nonrecurring charge primarily included the costs of early retirement
and severance packages which were elements of a revitalization program
("Revitalization") designed to better position the Company in a changing
energy marketplace. The Company has recovered the 1994 nonrecurring charge in
avoided labor costs that would have been charged to Other Operations and
Maintenance expense during 1994 and 1995.
Excluding the Revitalization charge, 1995 Earnings were 6.2% greater than 1994
Earnings of $225 million. The increase in 1995 Earnings reflects 1.4% higher
electric sales, 9.3% higher gas deliveries and a 3.1% decrease in Other
Operation and Maintenance expenses. Electric sales grew primarily as a result
of warmer summer weather during 1995. Gas deliveries increased due to
increased deliveries to Interruptible and Transportation customers and to
colder weather during the fourth quarter of 1995. Additional economic
activity in WE's service area also contributed to the increase in electric
sales and gas deliveries. The reduction in Other Operation and Maintenance
expenses primarily reflects payroll-related savings and efficiencies gained
through WE's Revitalization program.
1993 Through 1995: Earnings increased at a compound annual rate of 12.9% from
$188 million in 1993 to $239 million in 1995. The increase in Earnings
primarily resulted from corresponding growth in electric sales and therm
deliveries and a decline in Other Operation and Maintenance expense.
- 37 -
38
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Wisconsin Electric Revitalization
In response to increasing competitive pressures in the markets for electricity
and natural gas, WE implemented Revitalization in 1994 to increase
efficiencies and improve customer service by reengineering and restructuring
the organization. The new structure consolidated many business functions and
simplified work processes. See Note K - "Benefits Other Than Pensions" in the
NOTES TO FINANCIAL STATEMENTS.
Mergers
Wisconsin Natural Gas Company: As part of Revitalization, WEC has merged WN
into WE. The merger, which was effective January 1, 1996, is expected to
improve customer service and reduce operating costs. The accounting treatment
for this merger was similar to that which would result from a pooling of
interests. Accordingly, WE's prior year financial and statistical information
has been restated to include WN at historical values.
Wisconsin Southern Gas Company, Inc.: Effective January 1, 1994, WEC acquired
Wisconsin Southern Gas Company, Inc. ("WSG") through a statutory merger of WSG
into WN in which all of WSG's common stock was converted into common stock of
WEC. WSG was a gas utility engaged in the purchase, distribution,
transportation and sale of natural gas primarily in an area of southeastern
Wisconsin which was contiguous to WN's service territory. WSG was merged into
WN using the pooling of interests method of accounting. Accordingly, prior
years' financial and statistical information was restated to include WSG at
historical values.
Northern States Power Company: On April 28, 1995, WEC and NSP entered into an
Agreement and Plan of Merger, which was amended and restated as of
July 26, 1995 ("Merger Agreement"). The Merger Agreement provides for a
strategic business combination involving WEC and NSP in a "merger-of-equals"
transaction ("Transaction"). As a result, WEC will become a registered public
utility holding company under the Public Utility Holding Company Act of 1935,
as amended ("PUHCA"), and will change its name to Primergy Corporation
("Primergy"). Primergy will be the parent company of WE (which will be
renamed Wisconsin Energy Company), of NSP (which, for regulatory reasons, will
reincorporate in Wisconsin ("New NSP")), and of the other subsidiaries of WEC
and NSP. In connection with the Transaction, Northern States Power Company, a
Wisconsin corporation ("NSP-WI"), currently a utility subsidiary of NSP, will
be merged into Wisconsin Energy Company. Prior to the merger of NSP-WI into
Wisconsin Energy Company, New NSP will acquire from NSP-WI certain gas utility
assets. The Transaction is intended to be tax free for income tax purposes
and to be accounted for as a pooling of interests.
On September 13, 1995, stockholders of WEC and NSP voted to approve the
Transaction. Under the provisions of the Merger Agreement, each share of WEC
and NSP common stock will become 1.0 and 1.626 shares of Primergy common
stock, respectively, following the proposed Transaction.
As a result of the Transaction, the Company anticipates cost savings of
approximately $2 billion over a ten year period, net of transaction costs and
costs to achieve the savings of approximately $30 million and $122 million,
respectively. WE and NSP have proposed, in their filings with the numerous
state jurisdictions to which they are subject, a reduction of approximately
1.5% in retail electric rates beginning on or about January 1997 (assuming
- 38 -
39
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Mergers - (cont'd)
that the Transaction is then consummated) and a rate freeze through the year
2000, subject to certain exceptions regarding matters beyond WE's or NSP's
control. For the same periods and subject to the same types of exceptions, WE
and NSP-WI have proposed a $4.2 million reduction in retail gas rates on an
annualized basis in Wisconsin and Michigan and a rate freeze through the year
2000. Similarly, NSP anticipates proposing in 1996 a 1.25% rate reduction for
retail gas customers in North Dakota and four and two year rate freezes in
North Dakota and Minnesota, respectively, effective following consummation of
the Transaction. Subject to the same types of exceptions noted above, WE and
NSP have agreed to a freeze in their electric wholesale rates for a four year
period subsequent to the Transaction. In December 1995, WEC and NSP entered
into a settlement agreement with certain municipal Wisconsin intervenors that
ended the latters' participation in the FERC and state merger proceedings.
The settlement agreement, which provides for certain rate reductions on power
sales and transmission services, is pending FERC action. The state filings
include a request for deferred accounting treatment and rate recovery of costs
incurred associated with the Transaction. As of December 31, 1995, WEC has
deferred $8.1 million of costs associated with the Transaction as a component
of Deferred Charges and Other Assets-Other.
The Merger Agreement is subject to various conditions including approval by
all applicable regulatory authorities. In July 1995, WEC and NSP filed an
application and supporting testimony with the FERC seeking approval of the
Merger Agreement. In August 1995, WEC and NSP made similar filings with
regulatory agencies in the states where WEC and NSP provide utility services
and in which such filings are required. Applications for license amendments
and approvals relating to the Merger Agreement were filed with the Nuclear
Regulatory Commission ("NRC") in the fall of 1995. The FERC has put the
merger application on an accelerated schedule, ordering the administrative law
judge's initial decision by August 30, 1996 and briefs on exception by
September 30, 1996. In March 1996, the Public Service Commission of Wisconsin
("PSCW") requested that the FERC broaden the scope of the merger application
hearing to evaluate whether the proposed Transaction will impair effective
state oversight of retail rates. The matter is pending. Not all of the
regulatory agencies have established a timetable for their decision.
During 1995, WEC and NSP received a ruling from the Internal Revenue Service
indicating that the proposed successive merger transactions defined in the
Merger Agreement would not prevent the treatment of the Transaction as a tax-
free reorganization under applicable tax law if each transaction independently
so qualified. In 1996, WEC and NSP will file an application with the
Securities and Exchange Commission ("SEC") for authority to form Primergy
under the requirements of PUHCA as well as required notifications with the
Federal Trade Commission and the Department of Justice under the Hart-Scott-
Rodino Antitrust Improvements Act of 1976, as amended. Subject to obtaining
all requisite approvals, WEC and NSP anticipate completing the Transaction by
January 1, 1997.
The SEC may require, as a condition to its approval of the Transaction, that
WEC and NSP divest their gas utility properties and possibly certain non-
utility ventures within a reasonable time after the Transaction is
consummated. In a few cases, the SEC has allowed the retention of such
properties or deferred the question of divestiture for a substantial period of
time. In those cases in which divestiture has taken place, the SEC has
- 39 -
40
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Mergers - (cont'd)
usually allowed enough time to complete the divestiture so as to allow the
applicant to avoid a "fire sale" of the divested assets. WEC and NSP believe
strong policy reasons and prior SEC decisions exist which support their
retaining their existing gas utility properties and non-utility ventures, or,
alternatively, which support deferring the question of divestiture for a
substantial period of time; accordingly, WEC and NSP will request in their
merger application with the SEC that WEC and NSP be allowed to retain, or, in
the alternative, that the question of divestiture be deferred with respect to,
WEC's and NSP's existing gas utility properties and non-utility ventures.
Regulatory authorities may also require the restructuring of transmission
system operations or administration. WEC and NSP currently cannot determine
if such restructuring will be required. In addition, Wisconsin State law
limits the total assets of non-utility affiliates of Primergy, which could
affect the amount of non-regulated operations.
Electric Revenues, Gross Margins and Sales
1995 Compared to 1994: Despite an annualized $16 million or 1.3% Wisconsin
retail electric fuel adjustment rate decrease that became effective on
August 4, 1994, total Electric Operating Revenues increased by 2.4% from
$1,404 million in 1994 to $1,437 million in 1995 due to increased 1995
electric sales. The gross margin on Electric Operating Revenues (Electric
Operating Revenues less Fuel and Purchased Power expenses) increased by 1.6%
from $1,075 million in 1994 to $1,092 million in 1995. The gross margin grew
because the increased electric sales were primarily to Residential and Small
Commercial/Industrial customers who contribute higher margins to earnings than
other customer classes.
==============================================================================
Electric Gross Margin ($000) 1995 1994 % Change
- ---------------------------- ---------- ---------- --------
Electric Operating Revenues $1,437,480 $1,403,562 2.4
Fuel & Purchased Power 345,387 328,485 5.1
---------- ----------
Gross Margin $1,092,093 $1,075,077 1.6
==============================================================================
Total electric sales, detailed below by customer class, increased by 1.4% to
approximately 27,284,000 megawatt-hours in 1995 compared to 26,911,000
megawatt-hours in 1994. Electric sales were positively impacted by
substantially warmer summer weather conditions during 1995, resulting in
increased use of electricity for air conditioning and other cooling purposes.
As measured by cooling degree days, the 1995 cooling season (June through
August) was 27.7% warmer than the same period in 1994. During the summer of
1995, WE experienced eight days of electric peak demands greater than the
previous record which had been set in June 1994. The increase in electric
sales also reflects colder winter weather during the fourth quarter of 1995
and a moderate increase in economic activity in WE's service area.
- 40 -
41
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Electric Revenues, Gross Margins and Sales - (cont'd)
==============================================================================
Electric Sales (Megawatt-hours) 1995 1994 % Change
- ------------------------------- ---------- ---------- --------
Residential 7,042,691 6,670,081 5.6
Small Commercial/Industrial 7,047,277 6,699,073 5.2
Large Commercial/Industrial 10,639,782 10,471,869 1.6
Other 1,550,937 1,603,741 (3.3)
---------- ----------
Total Retail and Municipal 26,280,687 25,444,764 3.3
Resale-Utilities 1,003,182 1,466,599 (31.6)
---------- ----------
Total Sales 27,283,869 26,911,363 1.4
==============================================================================
The warmer 1995 summer weather increased sales primarily to Residential and
Small Commercial/Industrial customers. These customers are more sensitive to
weather variations than other customer classes. The average number of
customers in the Residential and Small Commercial/Industrial customer classes
grew by 1.3% and 1.8% or from 846,745 and 88,765, respectively, in 1994 to
857,924 and 90,386 in 1995.
Electric energy sales to the Empire and Tilden iron ore mines, WE's two
largest customers, decreased by 0.5% to 2,296,000 megawatt-hours in 1995
compared to 2,308,000 megawatt-hours in 1994. Excluding the mines, sales to
Large Commercial/Industrial customers increased 2.2%.
The 3.3% reduction in 1995 sales to the Other customer class is largely the
result of reductions in sales to WPPI, WE's largest municipal power agency
customer. WPPI has been reducing its purchases from WE subsequent to
acquiring generating capacity in 1990, 1993 and 1996. Since that time, WPPI
has expanded the use of its existing generating facilities and has installed
additional capacity, further reducing its reliance on energy purchases from
WE. These sales reductions did not have a significant effect on earnings.
The market for electric wholesale customers (included in the Other customer
class) is increasingly competitive. WE is in the process of renegotiating or
has renegotiated long-term power sales contracts with most of its municipal
wholesale customers. While WE anticipates retaining most of these customers
over the long-term, WE expects that municipal wholesale revenues will begin to
decline starting in 1996 as a result of lower margins included in the
renegotiated contracts. WE is actively seeking to obtain new municipal
wholesale customers to increase sales in this customer class.
Resale of energy to other utilities declined 31.6% in 1995. This decline can
in part be attributed to unplanned or longer than expected outages at two of
WE's least cost generating facilities during 1995 and to increased retail
customer load as a result of the warmer summer weather, both of which reduced
the opportunity to sell electric energy to other utilities. Additionally,
Upper Peninsula Power Company has permanently reduced the amount of energy
that it is purchasing from WE for resale. These sales reductions did not have
a significant effect on earnings.
- 41 -
42
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Electric Revenues, Gross Margins and Sales - (cont'd)
1993 Through 1995: Total Electric Operating Revenues increased at a compound
annual growth rate of 3.3% or from approximately $1,348 million in 1993 to
$1,437 million in 1995 due to increased electric sales. Total electric sales
grew from 25,685,000 megawatt-hours in 1993 to 27,284,000 megawatt-hours in
1995, a compound annual increase of 3.1%. These increases reflect, among
other things, more favorable weather conditions in 1995 and a moderate
increase in economic activity in WE's service area. The gross margin on
Electric Operating Revenues increased at a compound annual rate of 3.0% from
approximately $1,030 million in 1993 to $1,092 million in 1995. This was due
to increased electric sales to Residential and Small Commercial/Industrial
customers who contribute higher margins to earnings than other customer
classes.
From 1993 through 1995, sales to Residential and Small Commercial/Industrial
customers increased at compound annual rates of 3.7% and 5.3% or from
6,551,000 and 6,358,000 megawatt-hours, respectively, in 1993 to 7,043,000 and
7,047,000 megawatt-hours in 1995. This increase was due primarily to warm
summer weather in 1994 and 1995. The average number of Residential and Small
Commercial/Industrial customers has increased at compound annual rates of 1.3%
and 1.7%, respectively, during this period.
Large Commercial/Industrial sales increased from 9,771,000 megawatt-hours in
1993 to 10,640,000 megawatt-hours in 1995, a compound annual increase of 4.3%
attributable in part to a five-week long mine strike during the third quarter
of 1993 which reduced 1993 sales. WE's contracts with the mines require the
payment of a demand charge regardless of power usage which partially offset
the impact on 1993 revenues of lost sales. Sales to the mines represented
8.4%, 8.6% and 7.8% of total electric sales during 1995, 1994 and 1993,
respectively.
For the three year period ending with 1995, sales to the Other customer class
declined from 1,776,000 megawatt-hours in 1993 to 1,551,000 megawatt-hours in
1995, a compound annual decrease of 6.6% resulting from the decreased sales to
WPPI noted above. Sales for Resale to other utilities declined from 1,229,000
megawatt-hours in 1993 to 1,003,000 megawatt-hours in 1995, a compound annual
decrease of 9.7% resulting from the decreased opportunity sales and the
reduction in purchases by Upper Peninsula Power Company described above.
In addition to the results of higher total electric sales, the compound annual
increase in Electric Operating Revenues since 1993 includes the impacts of
rate changes which were effective during 1993 and 1994 as shown below in
"Rates and Regulatory Matters."
Gas Revenues, Gross Margins and Sales
1995 Compared to 1994: Despite an increase in 1995 total gas deliveries,
total Gas Operating Revenues decreased by 1.9% or from $324 million in 1994 to
$318 million in 1995 as a result of a reduction in the cost of gas which is
recovered through the purchased gas adjustment clause. The gross margin on
Gas Operating Revenues (Gas Operating Revenues less Cost of Gas Sold)
increased by 3.7% or from $125 million in 1994 to $129 million in 1995. The
gross margin grew because of increased therm sales to Residential and
Commercial customers who contribute higher margins to earnings than other
customer classes.
- 42 -
43
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Gas Revenues, Gross Margins and Sales - (cont'd)
==============================================================================
Gas Gross Margin ($000) 1995 1994 % Change
- ----------------------- ---------- ---------- --------
Gas Operating Revenues $ 318,262 $ 324,349 (1.9)
Cost of Gas Sold 188,764 199,511 (5.4)
---------- ----------
Gross Margin $ 129,498 $ 124,838 3.7
==============================================================================
Total natural gas therms delivered, detailed below by customer class,
increased by 9.3% or from 811,219 thousand therms in 1994 to 886,729 thousand
therms in 1995, due in part to the effects of weather. Colder weather during
the fourth quarter of 1995 contributed to net increased deliveries for the
year. As measured by heating degree days, the fourth quarter was 43.1% colder
than the same period in 1994. The increase in therms delivered also reflects
the warmer summer weather conditions noted above, which increased therm
deliveries to electric peak generating stations described below, and a
moderate increase in economic activity in WE's service area.
==============================================================================
Therms Delivered - Thousands 1995 1994 % Change
- ---------------------------- ---------- ---------- --------
Residential 345,140 323,913 6.6
Commercial/Industrial 207,358 199,206 4.1
Interruptible 50,646 47,467 6.7
---------- ----------
Total Sales 603,144 570,586 5.7
Transported Customer Owned Gas 283,585 240,633 17.8
---------- ----------
Total Gas Delivered 886,729 811,219 9.3
==============================================================================
The colder fourth quarter of 1995 weather increased sales to Residential and
Commercial customers. These customers are more sensitive to weather
variations as a result of heating requirements than other customer classes.
The average number of Residential and Commercial/Industrial customers
increased by 3.3% and 2.7% or from 311,288 and 28,506, respectively, in 1994
to 321,643 and 29,287 in 1995.
During 1995, therm deliveries to Interruptible and Transportation customers
increased by 6.7% and 17.8%, respectively. WE attributes these increases in
part to increased electric generation peaking requirements of its Concord
("Concord") and Paris ("Paris") Generating Stations, especially given the
warmer weather during the summer of 1995. All of the gas fired generating
units at Concord and Paris were in operation by the end of the second quarter
of 1995 while only the generating units at Concord were in operation by the
end of the second quarter of 1994. Deliveries to the Concord and Paris
peaking power plants are at rates approved by the PSCW.
WE transports gas for customers who purchase gas directly from other
suppliers. Rates charged for transportation services are designed to recover
the same margin as natural gas sold directly by WE.
- 43 -
44
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Gas Revenues, Gross Margins and Sales - (cont'd)
WE arranges for its own gas supply under contracts with terms of various
lengths. Changes in the cost of natural gas purchased at market prices are
passed through to customers via WE's purchased gas adjustment clause.
1993 Through 1995: While total Gas Operating Revenues decreased at a compound
annual rate of 2.0% or from $331 million in 1993 to $318 million in 1995, the
gross margin on Gas Operating Revenues increased at a compound annual rate of
5.1% or from $117 million in 1993 to $129 million in 1995. Total therms
delivered increased from 809,348 thousand therms in 1993 to 886,729 thousand
therms in 1995, or at a compound annual rate of 4.7%. Despite an annualized
$9 million or 3.3% rate increase that became effective September 2, 1993 and
the increased therm deliveries, Gas Operating Revenues declined due to a
reduction in the cost of gas which is passed through to customers via the
purchased gas adjustment clause. Gross margin grew as a result of increased
therm sales to Residential and Commercial customers who contribute higher
margins to earnings than other customer classes. Total therm deliveries
increased in part due to favorable weather conditions and moderate economic
growth in WE's service territory from 1993 through 1995.
From 1993 through 1995, therm sales to Residential and Commercial/Industrial
customers increased at compound annual rates of 3.5% and 1.2% or from 322,444
thousand and 202,549 thousand therms, respectively, in 1993 to 345,140
thousand and 207,358 thousand therms in 1995. The average number of
Residential and Commercial/Industrial customers increased at compound annual
rates of 3.1% and 2.5%, respectively, during this period. Therm deliveries to
Interruptible and to Transportation customers increased at compound annual
rates of 21.0% and 6.6% or from 34,608 thousand and 249,747 thousand therms,
respectively, in 1993 to 50,646 thousand and 283,585 thousand therms in 1995.
These gas deliveries increased in part due to the increased electric
generation peaking requirements of Paris and Concord noted above. Therms of
Transported Customer Owned Gas accounted for 32.0%, 29.7% and 30.9% of WE's
total therms delivered during 1995, 1994 and 1993, respectively.
Operating Expenses
1995 Compared to 1994: Excluding Depreciation expense, total operating taxes
and the nonrecurring 1994 Revitalization charge, total Operating Expenses
decreased 0.9% in 1995, reflecting a reduction of approximately $16 million or
3.1% in Other Operation and Maintenance expenses attributable to payroll-
related savings and efficiencies gained through WE's Revitalization program.
Such reductions were partially offset by higher costs related to increased
generation, the availability of Paris and unscheduled or longer than expected
outages at two of WE's most efficient power plants.
Fuel expense increased by approximately $18 million or 6.2% while Purchased
Power expense declined approximately $1 million or 1.9% in 1995. Fuel expense
rose as a result of higher electric sales. Purchased Power expense fell as a
result of decreased marginal generating costs at three of WE's fossil plants
and the newly installed peaking capacity at Paris. Lower generating costs at
the fossil plants were due to decreased per unit fuel costs and the benefits
of Revitalization, allowing WE to substitute generation for power purchases.
The addition of Paris in 1995 allowed WE to eliminate firm power purchase
- 44 -
45
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Operating Expenses - (cont'd)
contracts that contained fixed demand charges. The unscheduled or longer than
expected outages in 1995 noted above, however, offset most of the decrease in
Purchased Power expense as WE purchased nonfirm replacement energy on the spot
market.
Despite the increase in therm deliveries during 1995 noted above, Cost of Gas
Sold decreased by approximately $11 million or 5.4% in 1995 as a result of a
decrease in the average cost per therm sold.
From 1994 to 1995, total operating taxes increased $41 million or 41.4% due to
lower taxable income in 1994 caused by the nonrecurring Revitalization charge.
Deferred Income Taxes - Net increased $22 million or 88.7% primarily due to
tax matters related to the timing of payments made in connection with WE's
Revitalization program.
1993 Through 1995: Since 1993, total Operating Expenses excluding
Depreciation expense, total operating taxes and the nonrecurring 1994
Revitalization charge have decreased at a compound annual rate of 2.1% or from
$1,088 million in 1993 to $1,042 million in 1995. Other Operation and
Maintenance expenses decreased from $555 million in 1993 to approximately $508
million in 1995, a compound annual decrease of 4.4% largely due to the
Revitalization related work force reductions and efficiency gains referred to
above as well as to lower expenditures made in connection with power plant
renovation work as certain major maintenance programs were completed in 1994.
These decreases have been partially offset by expenses associated with the
implementation of Revitalization and increases in conservation-related
expenses associated with improving the efficiency of customers' energy usage.
Fuel expense increased at a compound annual rate of 7.4% or from $263 million
in 1993 to approximately $304 million in 1995, primarily due to increased
electric sales. Purchased Power expense decreased at a compound annual rate
of 12.7% or from $55 million in 1993 to approximately $42 million in 1995 due
to the decreased marginal generating costs at three of WE's fossil plants
noted above and to additional peak generating capacity placed in service at
Concord and Paris in 1994 and 1995, respectively. A 6.1% compound annual
decrease in the Cost of Gas Sold from $214 million in 1993 to approximately
$189 million in 1995 is attributable to a decrease in the average cost per
therm sold. Depreciation expense has increased at a compound annual rate of
4.9% from $167 million in 1993 to $184 million in 1995 as a result of higher
depreciable plant balances. During this period, total operating income taxes
and Deferred Income Taxes-Net have been affected by tax matters related to
Revitalization as noted above and by a prior period reclassification between
current and deferred income taxes.
Other Items
Other Interest Charges increased by $4 million between 1995 and 1994 and by
approximately $4 million between 1994 and 1993, reflecting increased average
short-term debt balances.
New Pronouncements: In 1995, the Financial Accounting Standards Board
("FASB") issued Statement of Financial Accounting Standards No. 121,
Accounting for the Impairment of Long-Lived Assets ("FAS 121"). FAS 121
- 45 -
46
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Other Items - (cont'd)
requires that long-lived assets be reviewed for impairment whenever events or
changes in circumstances indicate that the carrying amount of an asset may not
be recoverable. The Company will adopt FAS 121 prospectively in 1996. It is
anticipated that adoption will not have a material effect on the Company's net
income or financial position.
In February 1996, FASB released for comment an exposure draft of a Proposed
Statement of Financial Accounting Standards ("FAS"), Accounting for Certain
Liabilities Related to Closure or Removal of Long-Lived Assets. The proposed
FAS, if issued, would require WE to recognize as a liability the present value
of the estimated future total costs associated with closure or removal of
certain long-lived assets and to correspondingly capitalize those costs. The
capitalized costs would be depreciated to expense over the useful life of the
asset. The proposed statement would become effective in 1997. This proposed
FAS would apply to decommissioning costs for Point Beach Nuclear Plant ("Point
Beach") and would result in WE recording a decommissioning liability and
corresponding asset as required by the pronouncement. Currently, nuclear
decommissioning costs are accrued as depreciation expense over the expected
service lives of the two units at Point Beach based on an external sinking
fund method. Any changes in depreciation expense due to differing assumptions
between the proposed FAS and those currently required by the PSCW are not
expected to be material and would most likely be deferrable and recoverable in
rates. For additional information on the costs of decommissioning Point
Beach, see Note F - "Nuclear Operations" in the NOTES TO FINANCIAL STATEMENTS.
Effects of Inflation: With expectations of low-to-moderate inflation, the
Company does not believe the impact of inflation will have a material effect
on its future results of operations.
Electric Sales and Gas Deliveries Outlook
Assuming moderate growth in the economy of its service territory and normal
weather, WE presently anticipates total electric kilowatt-hour sales to grow
at a compound annual rate of approximately 1.1% over the five-year period
ending December 31, 2000. WE forecasts total therm deliveries of natural gas
to grow at a compound annual rate of approximately 2.1% over the same five-
year period. These forecasts are subject to a number of variables, including
among others the economy, weather and the restructuring of the electric and
gas utility industries, which may affect the actual growth in sales. These
estimates do not reflect the operations of NSP, which will become a part of
Primergy after consummation of the Transaction. See "RESULTS OF OPERATIONS -
Mergers" above.
Rates and Regulatory Matters
The table below summarizes the projected annual revenue impact of recent rate
changes authorized by regulatory commissions for the electric, natural gas and
steam utilities of the Company based on the sales projections utilized by
those commissions in setting rates. The PSCW regulates Wisconsin retail
electric, steam and natural gas rates, while the FERC regulates wholesale
power and electric transmission and gas transportation service rates. The
Michigan Public Service Commission ("MPSC") regulates retail electric rates in
Michigan. The PSCW has discontinued the practice of conducting annual rate
case proceedings, replacing it with a new schedule which calls for future rate
cases to be conducted once every two years.
- 46 -
47
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Rates and Regulatory Matters - (cont'd)
In support of its goal to become the lowest-cost energy provider in the region
and in light of the operating cost reductions expected from the reengineering
process discussed above, WE did not seek an increase in rates for 1994 or
1995.
==============================================================================
Revenue Percent
Increase Change in Effective
Service (Decrease) Rates Date
- ------------------------- ------------ --------- ---------
(Thousands)
Retail electric, WI $ (33,383) (2.8) 01/01/96
Retail electric, MI (1,128) (3.3) 01/01/96
Retail gas (8,298) (2.6) 01/01/96
Steam heating (790) (5.1) 01/01/96
Fuel electric, WI (16,179)* (1.3) 08/04/94
Fuel electric, WI (8,596)** (0.9) 11/05/93
Retail gas 9,172 3.3 09/02/93
Retail electric, MI 1,366 4.3 07/09/93
Wholesale electric 6,000 10.6 06/09/93
Retail electric, WI 26,655 2.3 02/17/93
Steam heating 505 3.5 02/17/93
==============================================================================
* The 8/4/94 fuel credit was eliminated 1/1/96 by PSCW Order.
** The 11/5/93 fuel credit was eliminated 1/1/94 by PSCW Order.
Under the Wisconsin retail electric fuel cost adjustment procedure, retail
electric rates may be adjusted, on a prospective basis, if cumulative fuel and
purchased power costs, when compared to the costs projected in the retail
electric rate proceeding, deviate from a prescribed range and are expected to
continue to be above or below that range. WE believes that it has the ability
to maintain low fuel costs through efficient management of its power supply
system and fuel procurement practices. Therefore, WE has proposed the
elimination of the retail electric fuel cost adjustment procedure in its 1997
Test Year filing with the PSCW. On December 15, 1995, the MPSC approved the
suspension of the Power Supply Cost Recovery Clause (fuel adjustment
procedure) for a five-year period for Michigan retail electric customers. In
the case of natural gas costs, differences between the test year estimate and
the actual cost of purchased gas are accounted for through a purchased gas
adjustment clause.
1996 Test Year: In a letter order dated September 11, 1995, the PSCW directed
WE to implement rate decreases for Wisconsin retail electric, gas and steam
customers of $33.383 million or 2.75%, $8.298 million or 2.6% and $0.790
million or 5.1%, respectively, on an annualized basis effective January 1,
1996. The decrease is based on a regulatory return on common equity of 11.3%,
down from 12.3% authorized since 1993. Also effective January 1, 1996, the
MPSC authorized WE to implement a rate decrease for Michigan non-mine retail
electric customers of $1.128 million or 3.3% on an annualized basis.
1997 Test Year: On January 16, 1996, WE filed specific financial data with
the PSCW related to the 1997 test year showing an $82.2 million revenue
- 47 -
48
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Rates and Regulatory Matters - (cont'd)
deficiency for its utility operations. The dollar impacts and percentage
increases requested for Wisconsin retail electric, gas and steam customers are
$77.0 million or 6.2%, $4.3 million or 1.4% and $0.9 million or 6.4%,
respectively, on an annualized basis. On March 15, 1996, WE filed testimony
and exhibits with the PSCW related to the 1997 test year. The PSCW had
determined that it required a special full review of WE's rates for the 1997
test year in connection with consideration of the application for approval of
the proposed merger of WEC and NSP.
Neither the 1996 nor 1997 Test Year changes reflect the proposed retail
electric and gas rate reductions and freezes nor the wholesale rate reductions
and freezes related to the proposed merger with NSP. See "RESULTS OF
OPERATIONS - Mergers" above for a separate discussion of rate actions related
to the proposed Transaction.
PSCW Electric Utility Industry Investigation: The PSCW has conducted an
investigation into the electric utility industry in Wisconsin, particularly
its institutional structure and regulatory regime, in order to evaluate what
changes would be beneficial for Wisconsin. The PSCW stated that this
investigation may result in profound and fundamental changes to the nature and
regulation of the electric utility industry in Wisconsin. In January 1995,
the PSCW established an advisory committee, including WE, to examine all
aspects of the electric utility industry and to suggest which functions should
be performed in a competitive market. The PSCW decided on December 12, 1995
the general direction of utility regulation in Wisconsin. This proposed
restructuring of the industry would permit all consumers to choose their
electricity provider by the year 2001 and it would establish a competitive
generation business. The transmission and distribution functions would remain
regulated. In a February 22, 1996 Report to the Wisconsin Legislature, the
PSCW identified a 32 step workplan that it would follow for Electric Utility
Restructuring in Wisconsin. In the plan, the PSCW indicated that during 1996
it will begin activities on 12 of these steps, some of which would seek
changes in applicable administrative rules under its jurisdiction, including
affiliated interest standards and quality of service standards. The PSCW
expects to present an electric utility restructuring proposal to the Wisconsin
State Legislature in 1997. In its February 22, 1996 report, the PSCW stated
that the implementation timetable for its plan is subject to change depending
on the pace of resolution of the specific restructuring steps and on external
events.
PSCW Natural Gas Utility Industry Investigation: The PSCW also continued a
generic investigation of the natural gas industry in Wisconsin and addressed
the extent to which traditional regulation should be replaced with a different
approach. In conjunction with this generic investigation, the PSCW staff is
reviewing the use of the current purchased gas adjustment ("PGA") mechanism
which is designed to pass on to gas customers increases or decreases in the
cost of natural gas purchased for resale. A separate docket has been
established to review the PGA. WE is participating in these PSCW
investigations.
In June 1995, WE filed with the PSCW a proposal to replace the current PGA
mechanism with a new market-based pricing mechanism. The proposed gas pricing
mechanism would link gas commodity prices to market indices and incorporate
- 48 -
49
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Rates and Regulatory Matters - (cont'd)
all other gas supply costs such as transportation and storage, under a price
cap. The price cap would be designed to provide balanced financial incentives
and risks for WE based upon performance standards, while ensuring a reliable
gas supply for consumers. In July 1995, the PSCW decided to analyze and
review this proposal as part of the generic docket established to review the
PGA. The matter is pending.
FERC Open Access Transmission NOPR: In March 1995, the FERC issued a Notice
of Proposed Rulemaking ("NOPR") on Open Access Non-Discriminatory Transmission
Services by Public Utilities. The NOPR's goal is to create a more competitive
wholesale electric power market. In the proposed rulemaking, FERC would
require all electric utilities that own or control transmission facilities to
file non-discriminatory open access transmission tariffs available to
wholesale sellers and buyers of electric energy, to take service under the
tariffs for their own wholesale sales and purchases of electric energy and to
provide utilities the opportunity to recover legitimate and verifiable
stranded costs on the federal and state levels. WE advocates open access to
transmission facilities as a necessary step in the competitive restructuring
of the electric utility industry and does not believe that the issuance of a
final rule by FERC will have a negative material impact on the Company's
financial position or results of operations. WE expects FERC to finalize and
issue its open access transmission rules in the second quarter of 1996.
Regulatory Accounting: WE operates under electric utility rates which are
subject to the approval of the PSCW, MPSC and FERC, and natural gas and steam
utility rates that are subject to the approval of the PSCW (see "Rates and
Regulatory Matters" above). Such rates are designed to recover the cost of
service and provide a reasonable return to investors. Developing competitive
pressures in the utility industry may result in future utility rates which are
based upon factors other than the traditional original cost of investment. In
such a situation, continued deferral of certain regulatory asset and liability
amounts on the utility's books may no longer be appropriate as allowed under
Statement of Financial Accounting Standards No. 71, Accounting for the Effects
of Certain Types of Regulation. At this time, WE is unable to predict whether
any adjustments to regulatory assets and liabilities will occur in the future.
See Note A - "Summary of Significant Accounting Policies" in the NOTES TO
FINANCIAL STATEMENTS.
LIQUIDITY AND CAPITAL RESOURCES
Investing Activities
WE invested $1.035 billion in its businesses during the three years ended
December 31, 1995. The investments made during this three-year period include
construction expenditures for new or improved facilities totaling $855
million, purchases of nuclear fuel of approximately $70 million, net
capitalized conservation expenditures of approximately $54 million and
payments to an external trust for the eventual decommissioning of WE's Point
Beach Nuclear Plant totaling $32 million.
Paris Generating Station: During 1995, WE placed in service four units, or
approximately 300 megawatts of capacity, at its Paris Generating Station.
This natural gas-fired combustion turbine facility, located near Union Grove,
- 49 -
50
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Investing Activities - (cont'd)
Wisconsin, is designed to meet peak demand requirements. Capital expenditures
of $10 million, $54 million and $28 million were made during 1995, 1994 and
1993, respectively, for construction of this facility. The capital costs of
the Paris facility will total approximately $105 million.
Concord Generating Station: During 1994, WE placed in service the last two
units, or approximately 150 megawatts of capacity, at its Concord Generating
Station. This four unit 300 megawatt natural gas-fired combustion turbine
facility, located near Watertown, Wisconsin, is designed to meet peak demand
requirements. The first two units were completed in 1993. Capital
expenditures of $3 million, $6 million and $35 million were made during 1995,
1994 and 1993, respectively, for construction of this facility. The capital
costs of the Concord facility will total approximately $107 million.
Port Washington Power Plant Renovation: Additionally during 1994, WE
completed the $107 million renovation project at its Port Washington Power
Plant. The renovation work, which began in September 1991, included the
installation of additional emission control equipment. Expenditures totaling
$12 million and $36 million were made during 1994 and 1993, respectively.
Cash Provided by Operating and Financing Activities
During the three years ended December 31, 1995, cash provided by operating
activities totaled $1.252 billion. During this period, internal sources of
funds, after the payment of dividends to WEC, provided approximately 84% of
the Company's capital requirements.
Financing activities during the three-year period ended December 31, 1995
included the issuance of approximately $611 million of long-term debt,
principally to refinance higher coupon debt and the purchase or redemption of
approximately $71 million of preferred stock. No preferred stock was issued
during this period. Additionally, during the three-year period ended
December 31, 1995, the Company retired a total of $502 million of long-term
debt and increased short-term debt by $28 million. Dividends on the Company's
common stock were approximately $160 million, $151 million and $75 million
during 1995, 1994 and 1993, respectively.
In December 1995, WE issued $100 million of unsecured One Hundred Year 6 7/8%
Debentures due 2095. Proceeds of the issue were added to WE's general funds
and were applied to the repayment of short-term borrowings.
In August 1995, WE called for optional redemption $98.35 million aggregate
principal amount of fixed rate tax exempt bonds issued by three political
jurisdictions on WE's behalf that were secured by issues of WE's First
Mortgage Bonds with terms corresponding to the tax exempt bonds called for
redemption. During September and October 1995, the three political
jurisdictions issued $98.35 million aggregate principal amount of new tax
exempt bonds on behalf of WE, collateralized by unsecured variable rate
promissory notes issued by WE, maturing between March 1, 2006 and September 1,
2030, with terms corresponding to the respective issues of the refunding tax
exempt bonds. The proceeds were used to finance the optional redemptions.
The WE First Mortgage Bonds, which collateralized the redeemed tax exempt
bonds, have been canceled.
- 50 -
51
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Cash Provided by Operating and Financing Activities - (cont'd)
During 1993, WE issued five new series of First Mortgage Bonds aggregating
$350 million in principal amount, the proceeds of which were used to redeem
$284.3 million principal amount of four outstanding series of First Mortgage
Bonds and 626,500 shares of WE's 6.75% Series Preferred Stock. These
refunding transactions are expected to result in significant savings over the
lives of the new debt issues. Depending on market conditions and other
factors, additional debt refundings may occur.
The Merger Agreement, entered into by WEC and NSP, provides for restrictions
on certain transactions by both the Company and NSP, including the issuance of
debt and equity securities. While WE does not currently plan to enter into
transactions that would not comply with these restrictions, circumstances may
arise to make such transactions necessary. Under such circumstances, NSP
would need to agree to consent to any such change in the Merger Agreement.
Capital Structure
The Company's capitalization at December 31 was as follows:
==============================================================================
1995 1994
------ ------
Common Equity 52.1% 50.4%
Preferred Stock 1.0 0.9
Long-Term Debt
(including current maturities) 42.3 41.0
Short-Term Debt 4.6 7.7
------ ------
100.0% 100.0%
==============================================================================
Compared to the utility industry in general, WE has maintained a relatively
high ratio of common equity to total capitalization and low debt and preferred
stock ratios. This conservative capital structure, along with strong bond
ratings and internal cash generation has provided, and should continue to
provide, the Company with access to the capital markets when necessary to
finance the anticipated growth in the Company's utility business. WE
currently has senior secured debt ratings of AA+ by Standard & Poor's
Corporation ("S&P"), Duff & Phelps Inc. and Fitch Investors Service Inc.
("Fitch") and Aa2 by Moody's Investors Service ("Moody's").
Following announcement of the Transaction, on May 1, 1995 S&P reported that it
was placing on CreditWatch with negative implications its AA+ senior secured
debt and AA+ preferred stock ratings of WE. S&P stated that if the
Transaction is completed, the likely credit rating for the senior secured debt
of WE is expected to be AA or AA-. As part of its rating process, S&P intends
to review the financial and operating plans of the merged utilities. Also on
May 1, 1995, citing WE's continued operation as a separate utility subsidiary
after the Transaction, its strength within its rating category and its strong
capital structure, Moody's confirmed its Aa2 first mortgage bond rating of WE.
On December 5, 1995, Fitch changed WE's credit trend from "stable" to
"declining" based upon its analysis of cash flow trends versus its standards
for an AA+ rating.
At year-end 1995, WE had approximately $109 million of unused lines of bank
credit and $20 million of cash and cash equivalents.
- 51 -
52
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Capital Requirements 1996-2000
The estimated capital requirements for WE for the years 1996-2000 are outlined
in the table below. Compared to the Company's Annual Report on Form 10-K for
the year ended December 31, 1994, the table below no longer reflects
conservation expenditures. Effective January 1, 1995, WE began expensing
conservation expenditures currently. Through 1995, capitalized conservation
investments were amortized to Operating Expense over a ten-year amortization
period. Effective January 1, 1996, WE began amortizing the remaining
capitalized conservation investment to operating expense over a five-year
amortization period.
The capital requirements table below does not reflect the impact of the
proposed Transaction with NSP. See "RESULTS OF OPERATIONS - Mergers" above.
==============================================================================
1996 1997 1998 1999 2000
---- ---- ---- ---- ----
(Millions of Dollars)
Construction $228 $189 $181 $183 $215
Bond Maturities and
Refinancings 30 166 61 93 2
Changes in Fuel
Inventories 3 13 4 (5) 11
Decommissioning Trust
Payments 31 33 35 38 40
---- ---- ---- ---- ----
Total $292 $401 $281 $309 $268
==============================================================================
LS Power Generation Facility: In 1993, a competitive bidding process
conducted by the PSCW resulted in the selection of a proposal submitted by an
unaffiliated independent power producer, LSP-Whitewater L.P. ("LS Power"), to
construct a generation facility to meet a portion of WE's anticipated increase
in system supply needs. WE subsequently signed a long-term agreement to
purchase electricity from the proposed facility. The agreement is contingent
upon the facility being completed and placed into operation, which at this
time is planned for mid-1997.
PSCW Advance Plan 7: In January 1994, a coordinated state-wide plan for
meeting future electricity needs of Wisconsin customers was filed with the
PSCW in the Advance Plan 7 Docket. In the Advance Plan process, WE, in
conjunction with the other regulated electric utilities located in Wisconsin,
files long-term forecasts of resource requirements, such as the need for
generation and transmission facilities, along with plans to meet those
requirements, including the use of energy management and conservation. The
PSCW approved WE's Advance Plan 7 filing in December 1995.
In order to reliably meet its forecasted growth in demand, WE employs a least-
cost integrated planning process which includes renovation of existing power
plants, promotion of cost-effective conservation and load management options,
development of renewable energy sources, purchases of power and construction
of new company-owned generation facilities.
- 52 -
53
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Capital Requirements 1996-2000 - (cont'd)
Investments in demand-side management programs have reduced and delayed the
need to add new generating capacity but have not eliminated the need entirely.
Purchases of power from other utilities and transmission system upgrades will
also combine to help delay the need to install some new generating capacity in
the future.
Finally, WE's Advance Plan 7 filing indicated a need for additional peaking
capacity after the turn of the century, along with an anticipated need for
additional intermediate-load capacity during the 2000 to 2010 time period. WE
does not anticipate needing additional base load generation until after 2010.
The addition of new generating units requires approval of the PSCW following a
two-stage bidding process, which could influence whether WE would construct
such facilities or purchase the required power. The United States
Environmental Protection Agency and the Wisconsin Department of Natural
Resources ("DNR") also must approve new generating units. All generating
facilities proposed by WE will meet or exceed the applicable federal and state
environmental requirements.
Kimberly Cogeneration Facility: Prior to the 1993 selection of the LS Power
generation facility by the PSCW, WE had proposed to construct its own 220
megawatt cogeneration facility in Kimberly, Wisconsin, which was intended to
provide process steam to Repap Wisconsin, Inc. ("Repap") starting in mid-1994.
In the PSCW Order, the WE project was selected as the second place conditional
project if the LS Power project did not proceed. WE had made expenditures for
the Kimberly facility of approximately $65.8 million associated with the
procurement of three combustion turbines, one steam turbine and three heat
recovery boilers in order to achieve the in-service dates as agreed to in a
steam service contract with Repap.
The Company is currently reviewing its options regarding its Kimberly
Cogeneration Facility equipment (the "Equipment"). The Equipment is of a
technology of natural gas-fired combined cycle generation equipment that is
marketed worldwide. The Company is investigating opportunities to sell the
Equipment or to use it in another power project and is currently evaluating
potential sales opportunities and/or power projects involving the Equipment.
At this time, the Company does not believe that disposition of the Equipment
will have a material adverse effect on its financial condition. However,
there is a possibility that WE may need to recognize an impairment of the
Equipment in the future should the projects noted above not occur and should
no other viable sales opportunities and/or power projects involving the
Equipment be identified.
Point Beach Unit 2 Steam Generators and Dry Cask Storage Facility: WE
operates two 500 megawatt generating units at Point Beach. During 1995, Point
Beach accounted for 26.9% of WE's net electric generation. The current
operating licenses for the two units at Point Beach expire in 2010 and 2013
for Units 1 and 2, respectively.
In October 1992, WE filed an application with the PSCW for replacement of the
Point Beach Unit 2 steam generators. As a result of degradation of some of
the tubes within the Unit 2 steam generators, the unit has been operating at
approximately 90% of its capacity since its return to service after its annual
- 53 -
54
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Capital Requirements 1996-2000 - (cont'd)
refueling outage in the fall of 1995. In February 1995, the PSCW deferred a
decision on the replacement of the steam generators in part to gather more
information during the fall 1995 refueling outage. An evaluation of
information gathered during this outage was included in a Supplemental
Environmental Impact Statement ("SEIS") prepared by the PSCW that shows the
replacement of the Unit 2 steam generators to be the most cost-effective
option when compared to all credible alternatives. Considering the rate of
tube degradation in the steam generators, there is a likelihood that WE would
not be able to restart Unit 2 following the fall 1996 outage without
replacement of the steam generators. In its SEIS, the PSCW estimates that
failure to replace the Unit 2 steam generators would cost WE customers up to
$494 million over the next 25 years to replace lost generation when compared
to the current estimated cost of replacement of $96 million.
In a related matter, WE received a Certificate of Authority from the PSCW in
February 1995 to construct and operate an Independent Spent Fuel Storage
Installation ("ISFSI"). The ISFSI will provide interim dry cask storage of
spent fuel from Point Beach using a system that was certified by the NRC after
a four-year technical review. Construction was completed in June 1995 with
associated capital costs of $8.5 million. WE loaded the first cask with spent
fuel in December 1995. On December 22, 1995, the Dane County Circuit Court
("Court") issued a decision vacating and remanding the February 1995 order of
the PSCW on procedural grounds, stating that the Environmental Impact
Statement prepared by the PSCW for this project was inadequate in two
respects. Transfer of additional spent fuel to the ISFSI has been temporarily
suspended by WE pending the PSCW's further action.
The PSCW has issued two SEIS's which address steam generator issues and the
inadequacies found by the Court with the original Environmental Impact
Statement for the ISFSI project. The PSCW held related hearings on these
matters in February and March 1996. WE anticipates that the PSCW will issue a
combined final order on replacement of the Unit 2 steam generators and the
remanded dry cask storage matters in May 1996. Failure by the PSCW to approve
the steam generator replacement and resolve the remanded issues could
jeopardize the continued operation of Point Beach and materially affect WE's
financial position and results of operations. WE would likely seek regulatory
relief to minimize the replacement power costs resulting from lost generating
capacity.
The ISFSI was necessary because the spent fuel pool inside the plant is
nearly full. The dry storage facility will be used until the United States
Department of Energy ("DOE") takes ownership of and removes the spent fuel.
While WE as well as other operators of nuclear power facilities in the United
States have a contract mandated by federal law that calls for the DOE to begin
accepting fuel in 1998, the DOE is not in a position to meet its commitment.
If this commitment is not met, WE will need to construct additional casks and
will seek PSCW approval to do so.
Milwaukee County Power Plant: In December 1995, WE signed an agreement with
Milwaukee County to purchase the Milwaukee County Power Plant located in
Wauwatosa, Wisconsin. The 11 megawatt power plant provides steam, chilled
water and electricity for the Milwaukee Regional Medical Center and several
other large customers located on the Milwaukee County grounds. WE had
- 54 -
55
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Capital Requirements 1996-2000 - (cont'd)
previously obtained approval from the PSCW for the purchase of the electric
generation and distribution facilities and acquired them in December 1995 with
a capital expenditure of $7 million. WE will integrate the electric
facilities into its current electric utility operations. In February 1996, WE
filed an application with the PSCW for a Certificate of Authority to acquire
and place in operation the steam production and distribution facilities.
Capital costs for the steam facilities will be $20 million. WE anticipates
PSCW approval of the acquisition by mid-1996 and will integrate the steam
facilities into its current steam utility operations. In conjunction with the
steam facility acquisition anticipated in mid-1996, WEC will acquire and
operate the chilled water facility as a non-regulated business. Purchase of
the steam and chilled water portions of the plant is contingent upon PSCW
approval to acquire the steam facilities and upon the five major customers
signing ten-year steam and chilled water service agreements.
Capital Resources
During the five-year period ending December 31, 2000, WE expects internal
sources of funds from operations, after dividends to WEC, to provide about 87%
of the utility capital requirements. The remaining utility cash requirements
are expected to be met through short-term borrowings and the issuance of
intermediate or long-term debt. The specific form, amount and timing of debt
securities which may be issued have not yet been determined and will depend,
to a large extent, on market conditions and other factors. The anticipated
capital resources during this period do not reflect the impact of the proposed
merger with NSP. See "RESULTS OF OPERATIONS - Mergers" above.
Environmental Issues
Clean Air Act: The 1990 Amendments to the Clean Air Act mandate significant
nation-wide reductions in SO2 and NOx emissions to address acid rain and
ground level ozone control requirements.
In 1994, WE completed the installation of continuous emission monitors at all
of its facilities and installed low NOx burners on one boiler at its Oak Creek
Power Plant and two boilers at its Valley Power Plant. These actions, along
with the burning of low sulfur coal and the installation of low NOx burners on
other boilers at Oak Creek and Valley Power Plants in early 1995, meet the
requirements that became effective January 1, 1995. To date, approximately
$45.3 million has been spent on compliance with the 1990 amendments to the
Clean Air Act.
WE elected to voluntarily bring the Valley and Port Washington Power Plants
under jurisdiction of the NOx and SO2 requirements of the Clean Air Act
amendments of 1990, five years earlier than mandated. This was possible
because these units meet the more stringent phase II emissions standards
today.
WE projects a surplus of SO2 emission allowances and is seeking additional
allowances available as a result of energy conservation programs. As an
integral component of its least-cost plan, WE is active in SO2 allowance
trading. Revenue from the sale of allowances is being used to offset future
potential rate increases.
- 55 -
56
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS - (cont'd)
Environmental Issues - (cont'd)
Additional fuel switching and the installation of NOx controls at various
power plants will be required to meet the second phase of reduction
requirements that become effective January 1, 2000. These costs, along with
additional operating expenses, are not expected to exceed $40.3 million based
on today's costs.
Manufactured Gas Plant Sites: WE's natural gas business unit is investigating
the remediation of a number of former manufactured gas plant ("MGP") sites.
Operations at these MGP sites ceased over 40 years ago. Limited remediation
activities occurred at a number of these sites during the 1980's, with removal
of waste materials known to be present at that time. In 1995, WE presented a
plan to investigate and further remediate sites to the DNR. During 1995, WE
conducted site investigations at four sites and partial remediation activities
were conducted at one site. Approximately $1.6 million has been spent through
December 31, 1995 for such activities. Remediation costs to be incurred
through the year 2000 have been estimated to be $12 million, but the total
costs are uncertain pending the results of further site specific
investigations and the selection of site specific remedial actions. In its
September 11, 1995 letter order, the PSCW allowed WE to defer MGP site
remediation costs with final rate treatment of such costs to be determined in
future rate cases. As of December 31, 1995, WE has recorded an accrued
liability of $1.6 million for MGP site remediation and a related deferred
regulatory asset of $3.2 million. WE expects to accrue additional MGP site
remediation liabilities during 1996 as site specific investigations are
completed and site specific remedial actions are identified. WE will seek
rate recovery for these costs and does not anticipate that there will be a
material adverse effect on its net income or financial position.
Ash Landfill Sites: WE aggressively seeks environmentally acceptable,
beneficial uses of its combustion byproducts. However, ash materials have
been, and to some degree, continue to be disposed in company-owned, licensed
landfills. Some early designed and constructed landfills may allow the
release of low levels of constituents resulting in the need for various levels
of remediation. Where WE has become aware of these conditions, efforts have
been expended to define the nature and extent of any release, and work has
been performed to address these conditions. These costs are included in the
environmental operating and maintenance costs of WE.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The "Consolidated Quarterly Financial Data" in SELECTED FINANCIAL DATA is
incorporated herein by reference.
- 56 -
57
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA - (cont'd)
WISCONSIN ELECTRIC POWER COMPANY
INCOME STATEMENT
Year Ended December 31
1995 1994 1993
---------- ---------- ----------
(Thousands of Dollars)
Operating Revenues
Electric $1,437,480 $1,403,562 $1,347,844
Gas 318,262 324,349 331,301
Steam 14,742 14,281 14,090
---------- ---------- ----------
Total Operating Revenues 1,770,484 1,742,192 1,693,235
Operating Expenses
Fuel (Note F) 303,553 285,862 263,385
Purchased power 41,834 42,623 54,880
Cost of gas sold 188,764 199,511 214,132
Other operation expenses 395,242 399,011 399,135
Maintenance 112,400 124,602 156,085
Revitalization (Note K) - 73,900 -
Depreciation (Note C) 183,876 177,614 167,066
Taxes other than income taxes 74,765 76,035 74,653
Federal income tax (Note D) 119,939 104,725 74,463
State income tax (Note D) 28,405 24,756 15,530
Deferred income taxes - net (Note D) (2,833) (25,095) 13,096
Investment tax credit - net (Note D) (4,482) (4,625) (4,626)
---------- ---------- ----------
Total Operating Expenses 1,441,463 1,478,919 1,427,799
Operating Income 329,021 263,273 265,436
Other Income and Deductions
Interest income 12,850 11,715 13,753
Allowance for other funds used during
construction (Note E) 3,650 4,985 8,457
Miscellaneous - net 5,677 10,727 9,568
Federal income tax (Note D) (535) (1,504) (1,832)
State income tax (Note D) (370) (589) (832)
---------- ---------- ----------
Total Other Income and Deductions 21,272 25,334 29,114
Income Before Interest Charges 350,293 288,607 294,550
Interest Charges
Long-term debt 99,727 102,059 103,262
Other interest 11,960 7,610 3,945
Allowance for borrowed funds used
during construction (Note E) (2,062) (2,816) (4,737)
---------- ---------- ----------
Total Interest Charges 109,625 106,853 102,470
---------- ---------- ----------
Net Income 240,668 181,754 192,080
Preferred Stock Dividend Requirement 1,203 1,351 4,377
---------- ---------- ----------
Earnings Available for Common
Stockholder $ 239,465 $ 180,403 $ 187,703
========== ========== ==========
<FN>
Note: Earnings and dividends per share of common stock are not applicable because all of the
company's common stock is owned by Wisconsin Energy Corporation.
The notes are an integral part of the financial statements.
- 57 -
58
WISCONSIN ELECTRIC POWER COMPANY
STATEMENT OF CASH FLOWS
Year Ended December 31
1995 1994 1993
-------- -------- --------
(Thousands of Dollars)
Operating Activities
Net income $240,668 $181,754 $192,080
Reconciliation to cash
Depreciation 183,876 177,614 167,066
Revitalization - net (5,404) 43,860 -
Nuclear fuel expense - amortization 22,324 21,437 21,366
Conservation expense - amortization 21,870 20,910 15,254
Debt premium, discount & expense -
amortization 12,652 14,368 13,617
Deferred income taxes - net (2,833) (25,095) 13,096
Investment tax credit - net (4,482) (4,625) (4,626)
Allowance for other funds used
during construction (3,650) (4,985) (8,457)
Change in - Accounts receivable (32,639) 7,684 (17,952)
Inventories 5,233 11,455 (11,186)
Accounts payable 16,650 (20,683) 7,864
Other current assets (4,068) (9,878) 1,039
Other current liabilities 17,097 9,980 19,273
Other (29,204) (13,123) (5,606)
-------- -------- --------
Cash Provided by Operating Activities 438,090 410,673 402,828
Investing Activities
Construction expenditures (248,867) (271,448) (334,932)
Allowance for borrowed funds used
during construction (2,062) (2,816) (4,737)
Nuclear fuel (23,454) (26,351) (20,016)
Nuclear decommissioning trust (10,861) (10,138) (11,371)
Conservation investments - net 2,130 (20,823) (35,252)
Other (4,511) (10,205) 612
-------- -------- --------
Cash Used in Investing Activities (287,625) (341,781) (405,696)
Financing Activities
Sale of long-term debt 217,453 32,474 361,049
Retirement of long-term debt (134,172) (35,069) (332,862)
Change in short-term debt (91,811) 49,294 71,004
Stockholder capital contribution 30,000 30,000 10,000
Retirement of preferred stock - (5,250) (65,504)
Dividends on stock - common (159,576) (150,951) (74,771)
- preferred (1,203) (1,381) (4,729)
Other - - 135
-------- -------- --------
Cash Used in Financing Activities (139,309) (80,883) (35,678)
-------- -------- --------
Change in Cash and Cash Equivalents $ 11,156 $(11,991) $(38,546)
======== ======== ========
Supplemental information disclosures
Cash Paid For
Interest (net of amount capitalized) $ 99,352 $ 93,383 $ 85,299
Income taxes 149,224 148,552 101,216
<FN>
The notes are an integral part of the financial statements.
- 58 -
59
WISCONSIN ELECTRIC POWER COMPANY
BALANCE SHEET
December 31
ASSETS
1995 1994
---------- ----------
(Thousands of Dollars)
Utility Plant
Electric $4,531,404 $4,304,925
Gas 489,739 467,732
Steam 40,078 40,103
---------- ----------
5,061,221 4,812,760
Accumulated provision for depreciation (2,288,080) (2,134,469)
---------- ----------
2,773,141 2,678,291
Construction work in progress 78,153 205,835
Nuclear fuel - net (Note F) 59,260 56,606
---------- ----------
Net Utility Plant 2,910,554 2,940,732
Other Property and Investments
Nuclear decommissioning trust fund (Note F) 275,125 226,805
Conservation investments 115,523 138,489
Other 36,979 32,974
---------- ----------
Total Other Property and Investments 427,627 398,268
Current Assets
Cash and cash equivalents 19,550 8,394
Accounts receivable, net of allowance for
doubtful accounts - $13,400 and $12,078 144,476 111,837
Accrued utility revenues 140,201 128,107
Fossil fuel (at average cost) 83,366 88,587
Materials and supplies (at average cost) 70,347 70,359
Prepayments 55,147 61,160
Other assets 4,637 6,650
---------- ----------
Total Current Assets 517,724 475,094
Deferred Charges and Other Assets
Accumulated deferred income taxes (Note D) 136,581 137,931
Deferred regulatory assets (Note A) 193,757 197,103
Other 132,681 53,065
---------- ----------
Total Deferred Charges and Other Assets 463,019 388,099
---------- ----------
Total Assets $4,318,924 $4,202,193
========== ==========
<FN>
The notes are an integral part of the financial statements.
- 59 -
60
WISCONSIN ELECTRIC POWER COMPANY
BALANCE SHEET
December 31
CAPITALIZATION and LIABILITIES
1995 1994
---------- ----------
(Thousands of Dollars)
Capitalization (See Capitalization Statement)
Common stock equity $1,696,565 $1,586,676
Preferred stock 30,451 30,451
Long-term debt (Note H) 1,325,169 1,257,776
---------- ----------
Total Capitalization 3,052,185 2,874,903
Current Liabilities
Long-term debt due currently (Note H) 51,419 32,136
Notes payable (Note I) 150,694 242,505
Accounts payable 107,115 90,465
Payroll and vacation accrued 26,699 26,507
Taxes accrued - income and other 18,378 20,589
Interest accrued 21,617 23,254
Other 48,762 28,009
---------- ----------
Total Current Liabilities 424,684 463,465
Deferred Credits and Other Liabilities
Accumulated deferred income taxes (Note D) 479,828 472,746
Accumulated deferred investment tax credits 89,672 94,154
Deferred regulatory liabilities (Note A) 167,483 171,599
Other 105,072 125,326
---------- ----------
Total Deferred Credits and Other
Liabilities 842,055 863,825
Commitments and Contingencies (Note N)
---------- ----------
Total Capitalization and Liabilities $4,318,924 $4,202,193
========== ==========
<FN>
The notes are an integral part of the financial statements.
- 60 -
61
WISCONSIN ELECTRIC POWER COMPANY
CAPITALIZATION STATEMENT
December 31
1995 1994
---------- ----------
(Thousands of Dollars)
Common Stock Equity (See Common Stock Equity Statement)
Common stock - $10 par value; authorized 65,000,000 shares;
outstanding - 33,289,327 shares $ 332,893 $ 332,893
Other paid in capital 280,689 250,689
Retained earnings 1,082,983 1,003,094
---------- ----------
Total Common Stock Equity 1,696,565 1,586,676
Preferred Stock - Cumulative
Six Per Cent. Preferred Stock - $100 par value; authorized
45,000 shares; outstanding - 44,508 shares 4,451 4,451
Serial preferred stock - $100 par value; authorized 2,286,500 and
2,360,000 shares; outstanding - 3.60% Series - 260,000 shares 26,000 26,000
---------- ----------
Total Preferred Stock (Note G) 30,451 30,451
Long-Term Debt
First mortgage bonds
Series Due
------ ---
5-5/8% 1995 - 10,000
4-1/2% 1996 30,000 30,000
5-7/8% 1997 130,000 130,000
6-5/8% 1997 10,000 10,000
5-1/8% 1998 60,000 60,000
6.10 % 1999-2008 - 25,000
6.25 % 1999-2008 - 1,000
6-1/2% 1999 40,000 40,000
6-5/8% 1999 51,000 51,000
6.45 % 2004 - 12,000
7-1/4% 2004 140,000 140,000
6.45 % 2006 - 4,000
6.50 % 2007-2009 - 10,000
9-3/4% 2015 - 46,350
7-1/8% 2016 100,000 100,000
6.85 % 2021 9,000 9,000
7-3/4% 2023 100,000 100,000
7.05 % 2024 60,000 60,000
9-1/8% 2024 3,443 3,443
8-3/8% 2026 100,000 100,000
7.70 % 2027 200,000 200,000
---------- ----------
1,033,443 1,141,793
Debentures (unsecured)
6-1/8% 1997 25,000 25,000
10-1/4% 1998 - 2,290
9.47% 2006 7,000 7,000
8-1/4% 2022 25,000 25,000
6-7/8% 2095 100,000 -
Notes (unsecured)
Variable rate due 2006 1,000 -
Variable rate due 2015 17,350 -
Variable rate due 2016 67,000 67,000
Variable rate due 2030 80,000 -
Obligations under capital lease (Note F) 43,924 43,696
Unamortized discount - net (23,129) (21,867)
Long-term debt due currently (51,419) (32,136)
---------- ----------
Total Long-Term Debt (Note H) 1,325,169 1,257,776
---------- ----------
Total Capitalization $3,052,185 $2,874,903
========== ==========
<FN>
The notes are an integral part of the financial statements.
- 61 -
62
WISCONSIN ELECTRIC POWER COMPANY
COMMON STOCK EQUITY STATEMENT
- -------------------------------------------------- ----------------------------------------------------------
Common Stock Common Stock Other Paid Retained
Shares $10 Par Value In Capital Earnings Total
- -------------------------------------------------- ----------------------------------------------------------
(Thousands of Dollars)
Balance - December 31, 1992 33,289,327 $332,893 $213,409 $ 861,092 $1,407,394
Net income 192,080 192,080
Cash dividends
Common stock (74,771) (74,771)
Preferred stock (4,729) (4,729)
Purchase of preferred stock (Note G) (2,854) (2,854)
Stockholder capital contribution 10,000 10,000
Other 134 245 379
- -------------------------------------------------- ----------------------------------------------------------
Balance - December 31, 1993 33,289,327 332,893 220,689 973,917 1,527,499
Net income 181,754 181,754
Cash dividends
Common stock (150,951) (150,951)
Preferred stock (1,381) (1,381)
Stockholder capital contribution 30,000 30,000
Other (245) (245)
- -------------------------------------------------- ----------------------------------------------------------
Balance - December 31, 1994 33,289,327 332,893 250,689 1,003,094 1,586,676
Net income 240,668 240,668
Cash dividends
Common stock (159,576) (159,576)
Preferred stock (1,203) (1,203)
Stockholder capital contribution 30,000 30,000
- -------------------------------------------------- ----------------------------------------------------------
Balance - December 31, 1995 33,289,327 $332,893 $280,689 $1,082,983 $1,696,565
================================================== ==========================================================
<FN>
The notes are an integral part of the financial statements.
- 62 -
63
WISCONSIN ELECTRIC POWER COMPANY
NOTES TO FINANCIAL STATEMENTS
A - Summary of Significant Accounting Policies
General: The accounting records of Wisconsin Electric Power Company ("WE" or
the "Company") are kept as prescribed by the Federal Energy Regulatory
Commission ("FERC"), modified for requirements of the Public Service
Commission of Wisconsin ("PSCW").
The preparation of financial statements in conformity with generally accepted
accounting principles requires management to make estimates and assumptions
that affect the reported amounts of certain assets and liabilities and
disclosure of contingent assets and liabilities at the date of financial
statements and the reported amounts of revenues and expenses during the
reporting period. Actual results could differ from those estimates.
Revenues: Utility revenues are recognized on the accrual basis and include
estimated amounts for service rendered but not billed.
Fuel: The cost of fuel is expensed in the period consumed.
Property: Property is recorded at cost. Additions to and significant
replacements of utility property are charged to utility plant at cost; minor
items are charged to maintenance expense. Cost includes material, labor and
allowance for funds used during construction (see Note E). The cost of
depreciable utility property, together with removal cost less salvage, is
charged to accumulated provision for depreciation when property is retired.
Deferred Regulatory Assets and Liabilities: Pursuant to Statement of
Financial Accounting Standards No. 71, Accounting for the Effects of Certain
Types of Regulation, WE capitalizes, as deferred regulatory assets, incurred
costs which are expected to be recovered in future utility rates. WE also
records, as deferred regulatory liabilities, the current recovery in utility
rates of costs which are expected to be paid in the future. A significant
portion of WE's deferred regulatory assets and liabilities relate to the
amounts recorded due to the adoption of Statement of Financial Accounting
Standards No. 109, Accounting for Income Taxes ("FAS 109"). (See Note D.)
Statement of Cash Flows: Cash and cash equivalents include marketable debt
securities acquired three months or less from maturity.
Conservation Investments: WE directs a variety of demand-side management
programs to help foster energy conservation by its customers. As authorized
by the PSCW, WE capitalized certain conservation program costs prior to 1995.
Utility rates approved by the PSCW provide for a current return on these
conservation investments. Through 1995, conservation investments were charged
to operating expense over a ten-year amortization period. Beginning in 1996,
the capitalized conservation balance will be charged to operating expense on a
straight line basis over a five-year amortization period.
New Pronouncements: In 1995, the Financial Accounting Standards Board issued
Statement of Financial Accounting Standards No. 121, Accounting for the
Impairment of Long-Lived Assets ("FAS 121"). FAS 121 requires that long-lived
assets be reviewed for impairment whenever events or changes in circumstances
- 63 -
64
NOTES TO FINANCIAL STATEMENTS - (cont'd)
A - Summary of Significant Accounting Policies - (cont'd)
indicate that the carrying amount of an asset may not be recoverable. The
Company will adopt FAS 121 prospectively in 1996. It is anticipated that
adoption will not have a material effect on net income or financial position.
B - Mergers
Wisconsin Natural Gas Company: Effective January 1, 1996, Wisconsin Energy
Corporation ("WEC"), WE's parent company, merged its natural gas utility
subsidiary, Wisconsin Natural Gas Company ("WN") into WE. The accounting
treatment for this merger was similar to that which would result from a
pooling of interests. The Company's prior years' financial information has
been restated to include WN at historical values. Where applicable,
references to WE include WN prior to their merger.
Wisconsin Southern Gas Company, Inc.: Effective January 1, 1994, WEC acquired
all of the outstanding common stock of Wisconsin Southern Gas Company, Inc.
("WSG") through a statutory merger of WSG into WN in which all of WSG's common
stock was converted into common stock of WEC. WSG was a gas utility engaged
in the purchase, distribution, transportation and sale of natural gas
primarily in a section of southeastern Wisconsin which was contiguous to WN's
service territory. WSG was merged into WN using the pooling of interests
method of accounting. Accordingly, prior years' financial and statistical
information was restated to include WSG at historical values.
Northern States Power Company: On April 28, 1995, WEC and Northern States
Power Company, a Minnesota corporation ("NSP"), entered into an Agreement and
Plan of Merger, which was amended and restated as of July 26, 1995 ("Merger
Agreement"). The Merger Agreement provides for a strategic business
combination involving WEC and NSP in a "merger-of-equals" transaction
("Transaction"). As a result, WEC will become a registered public utility
holding company under the Public Utility Holding Company Act of 1935, as
amended, and will change its name to Primergy Corporation ("Primergy").
Primergy will be the parent company of WE (which will be renamed Wisconsin
Energy Company), of NSP (which, for regulatory reasons, will reincorporate in
Wisconsin ("New NSP")), and of the other subsidiaries of WEC and NSP. The
Transaction is intended to be tax-free for income tax purposes and to be
accounted for as a pooling of interests. On September 13, 1995, stockholders
of WEC and NSP voted to approve the Transaction. The Merger Agreement is
subject to various conditions, including the approval of various regulatory
agencies. Subject to obtaining all requisite approvals, WEC and NSP
anticipate completing the Transaction by January 1, 1997.
In connection with the Transaction, Northern States Power Company, a Wisconsin
corporation ("NSP-WI"), currently a subsidiary of NSP, will be merged into
Wisconsin Energy Company. Prior to the merger of NSP-WI into Wisconsin Energy
Company, New NSP will acquire from NSP-WI certain gas utility assets in
LaCrosse and Hudson, Wisconsin with a net historical cost at December 31, 1995
of approximately $19.3 million.
The following summarized Wisconsin Energy Company unaudited pro forma
financial information combines historical balance sheet and income statement
information of WE and NSP-WI to give effect to the Transaction, including the
transfer of the gas assets from NSP-WI to New NSP, and should be read in
- 64 -
65
NOTES TO FINANCIAL STATEMENTS - (cont'd)
B - Mergers - (cont'd)
conjunction with the historical financial statements and related notes thereto
of WE and NSP-WI. The unaudited pro forma income statement information does
not reflect adjustments for 1995 revenues of $28.9 million and related
expenses associated with the transfer of the gas assets from NSP-WI to New
NSP. A $136.6 million pro forma adjustment has been made to conform the
presentation of noncurrent deferred income taxes in the summarized unaudited
pro forma combined balance sheet information as a net liability. The
allocation between WEC and NSP and their customers of the estimated cost
savings resulting from the Transaction, net of costs incurred to achieve such
savings, will be subject to regulatory review and approval. None of the
estimated cost savings, the costs to achieve such savings, nor transaction
costs are reflected in the unaudited pro forma financial information. All
other financial statement presentation and accounting policy differences are
immaterial and have not been adjusted in the unaudited pro forma financial
information.
The unaudited pro forma balance sheet information gives effect to the
Transaction as if it had occurred at December 31, 1995. The unaudited pro
forma income statement information gives effect to the Transaction as if it
had occurred at January 1, 1995. The following information is not necessarily
indicative of the financial position or operating results that would have
occurred had the Transaction been consummated on the date or at the beginning
of the period for which the Transaction is being given effect nor is it
necessarily indicative of future operating results or financial position.
==============================================================================
Wisconsin Energy Company: * Unaudited
WE NSP-WI Pro Forma
(As Reported) (As Reported) Combined**
------------- ------------- -------------
(Millions of Dollars)
As of December 31, 1995:
Utility plant-net $ 2,911 $ 652 $ 3,544
Current assets 518 86 620
Other assets 890 53 807
----------- ----------- -----------
Total Assets $ 4,319 $ 791 $ 4,971
=========== =========== ===========
Common stockholder's equity $ 1,697 $ 318 $ 2,015
Preferred stock and premium 30 - 30
Long-term debt 1,325 214 1,539
----------- ----------- -----------
Total Capitalization 3,052 532 3,584
Current liabilities 425 102 527
Other liabilities 842 157 860
----------- ----------- -----------
Total Equity & Liabilities $ 4,319 $ 791 $ 4,971
=========== =========== ===========
==============================================================================
- 65 -
66
NOTES TO FINANCIAL STATEMENTS - (cont'd)
B - Mergers - (cont'd)
==============================================================================
Wisconsin Energy Company: * Unaudited
(cont'd) WE NSP-WI Pro Forma
(As Reported) (As Reported) Combined**
------------- ------------- -------------
(Millions of Dollars)
For the Year Ended
December 31, 1995:
Utility Operating Revenues $ 1,770 $ 459 $ 2,229
Utility Operating Income $ 329 $ 56 $ 385
Net Income, after Preferred
Dividend Requirements $ 239 $ 39 $ 278
==============================================================================
* In connection with the Merger Agreement, WE will be renamed Wisconsin
Energy Company.
** Includes a pro forma adjustment for the transfer of selected gas assets
from NSP-WI to New NSP and a $136.6 million pro forma adjustment to conform
the presentation of noncurrent deferred taxes as a net liability.
Note: Earnings per share of common stock are not applicable because all of
the Wisconsin Energy Company common stock will be owned by Primergy.
C - Depreciation
Depreciation expense is accrued at straight line rates over the estimated
useful lives of the assets. These rates are certified by the PSCW and include
estimates for salvage and removal costs. Depreciation as a percent of average
depreciable utility plant was 3.8% in 1995 and 3.9% in 1994 and 1993. Nuclear
plant decommissioning is accrued as depreciation expense (see Note F).
D - Income Taxes
Comprehensive interperiod income tax allocation is used for federal and state
temporary differences. The federal investment tax credit is accounted for on
the deferred basis and is reflected in income ratably over the life of the
related property.
Following is a summary of income tax expense and a reconciliation of total
income tax expense with the tax expected at the federal statutory rate:
==============================================================================
1995 1994 1993
-------- -------- --------
(Thousands of Dollars)
Current tax expense $149,249 $131,574 $ 92,657
Investment tax credit-net (4,482) (4,625) (4,626)
Deferred tax expense (2,833) (25,095) 13,096
-------- -------- --------
Total Tax Expense $141,934 $101,854 $101,127
======== ======== ========
==============================================================================
- 66 -
67
NOTES TO FINANCIAL STATEMENTS - (cont'd)
D - Income Taxes - (cont'd)
==============================================================================
1995 1994 1993
-------- -------- --------
(Thousands of Dollars)
Income Before Income Taxes
and Preferred Dividend $382,602 $283,608 $293,207
======== ======== ========
Expected tax at federal
statutory rate $133,911 $ 99,263 $102,622
State income tax net of
federal tax reduction 18,943 14,087 12,078
Investment tax credit
restored (4,482) (4,625) (5,241)
Other (no item over
5% of expected tax) (6,438) (6,871) (8,332)
-------- -------- --------
Total Tax Expense $141,934 $101,854 $101,127
======== ======== ========
==============================================================================
FAS 109 requires the recording of deferred assets and liabilities to recognize
the expected future tax consequences of events that have been reflected in the
Company's financial statements or tax returns and the adjustment of deferred
tax balances to reflect tax rate changes. Following is a summary of deferred
income taxes under FAS 109:
==============================================================================
December 31
1995 1994
-------- --------
(Thousands of Dollars)
Deferred Income Tax Assets
Decommissioning trust $ 43,759 $ 42,685
Construction advances 43,052 40,839
Other 49,770 54,407
-------- --------
Total Deferred Income Tax Assets $136,581 $137,931
======== ========
Deferred Income Tax Liabilities
Property related $445,878 $428,044
Conservation investments 25,775 27,564
Other 8,175 17,138
-------- --------
Total Deferred Income Tax Liabilities $479,828 $472,746
======== ========
==============================================================================
- 67 -
68
NOTES TO FINANCIAL STATEMENTS - (cont'd)
D - Income Taxes - (cont'd)
WE also has recorded the following deferred regulatory assets and liabilities
representing the future expected impact of deferred taxes on utility revenues:
==============================================================================
December 31
1995 1994
-------- --------
(Thousands of Dollars)
Deferred Regulatory Assets $155,944 $158,912
Deferred Regulatory Liabilities 163,676 171,599
==============================================================================
E - Allowance for Funds Used During Construction ("AFUDC")
AFUDC is included in utility plant accounts and represents the cost of
borrowed funds used during plant construction and a return on stockholders'
capital used for construction purposes. On the income statement, the cost of
borrowed funds (before income taxes) is a reduction of interest expense and
the return on stockholders' capital is an item of noncash other income.
Utility rates approved by the PSCW provide for a current return on investment
for selected long-term projects included in construction work in progress
("CWIP"). AFUDC was capitalized on the remaining CWIP at a rate of 10.83% in
1995, 1994 and 1993, as approved by the PSCW.
F - Nuclear Operations
Point Beach Nuclear Plant: WE operates two 500 megawatt generating units at
its Point Beach Nuclear Plant ("Point Beach"). During 1995, Point Beach
accounted for 26.9% of WE's net electric generation. The current operating
licenses for the two units at Point Beach expire in 2010 and 2013 for Units 1
and 2, respectively.
WE has filed an application with the PSCW for replacement of the Point Beach
Unit 2 steam generators. As a result of degradation of some of the tubes
within the Unit 2 steam generators, the unit has been operating at
approximately 90% of its capacity since its return to service after its annual
refueling outage in the fall of 1995. Considering the rate of tube
degradation in the steam generators, there is a likelihood that WE would not
be able to restart Unit 2 following the fall 1996 outage without replacement
of the steam generators.
In a related matter, WE completed construction of an Independent Spent Fuel
Storage Installation ("ISFSI") in June 1995. The ISFSI will provide interim
dry cask storage of spent fuel from Point Beach, which is necessary because
the spent fuel pool inside the plant is nearly full. WE loaded the first cask
with spent fuel in December 1995. On December 22, 1995, the Dane County
Circuit Court ("Court") issued a decision vacating and remanding the February
1995 PSCW approval of the ISFSI on procedural grounds, stating that the
- 68 -
69
NOTES TO FINANCIAL STATEMENTS - (cont'd)
F - Nuclear Operations - (cont'd)
Environmental Impact Statement prepared by the PSCW for this project was
inadequate in two respects. Transfer of additional spent fuel to the ISFSI
has been temporarily suspended by WE pending the PSCW's further action.
The PSCW has issued two Supplemental Environmental Impact Statements which
address steam generator issues and the inadequacies found by the Court with
the original Environmental Impact Statement for the ISFSI project. The PSCW
held related hearings on these matters in February and March 1996. WE
anticipates that the PSCW will issue a combined final order on the replacement
of the Unit 2 steam generators and the remanded dry cask storage matters in
May 1996. Failure by the PSCW to approve steam generator replacement and
resolve the remanded issues could jeopardize the continued operation of Point
Beach and materially affect WE's financial position and results of operations.
WE would likely seek regulatory relief to minimize the replacement power costs
resulting from lost generating capacity.
Nuclear Fuel: WE has a nuclear fuel leasing arrangement with Wisconsin
Electric Fuel Trust ("Trust"), which is treated as a capital lease. The
nuclear fuel is leased for a period of 60 months or until the removal of the
fuel from the reactor, if earlier. Lease payments include charges for the
cost of fuel burned, financing costs and a management fee. In the event WE or
the Trust terminates the lease, the Trust would recover its unamortized cost
of nuclear fuel from WE. Under the lease terms, WE is in effect the ultimate
guarantor of the Trust's commercial paper and line of credit borrowings
financing the investment in nuclear fuel.
Provided below is a summary of nuclear fuel investment at December 31 and
interest expense for the respective years on the nuclear fuel lease:
==============================================================================
1995 1994 1993
-------- -------- --------
(Thousands of Dollars)
Nuclear Fuel
Under capital lease $ 89,840 $ 89,705
Accumulated provision for amortization (50,532) (50,983)
In process/stock 19,952 17,884
-------- --------
Total Nuclear Fuel $ 59,260 $ 56,606
======== ========
Interest Expense on Nuclear Fuel Lease $ 2,401 $ 1,896 $ 1,697
==============================================================================
- 69 -
70
NOTES TO FINANCIAL STATEMENTS - (cont'd)
F - Nuclear Operations - (cont'd)
The future minimum lease payments under the capital lease and the present
value of the net minimum lease payments as of December 31, 1995 are as
follows:
============================================================================
(Thousands of Dollars)
1996 $ 22,446
1997 14,747
1998 6,960
1999 2,443
2000 490
--------
Total Minimum Lease Payments 47,086
Less: Interest (3,162)
--------
Present Value of Net Minimum Lease Payments $ 43,924
========
==============================================================================
The estimated cost of disposal of spent fuel based on a contract with the U.S.
Department of Energy ("DOE") is included in nuclear fuel expense. The Energy
Policy Act of 1992 establishes a Uranium Enrichment Decontamination and
Decommissioning Fund ("D&D Fund") for the DOE's nuclear fuel enrichment
facilities. Deposits to the D&D Fund are derived in part from special
assessments to utilities. As of December 31, 1995, WE has on its books a
remaining estimated liability equal to the projected special assessments of
$29.5 million. A corresponding deferred regulatory asset will be amortized to
nuclear fuel expense and included in utility rates over the next 12 years.
Nuclear Insurance: The Price-Anderson Act ("Act") provides an aggregate
limitation of $8.9 billion on public liability claims arising out of a nuclear
incident. WE has $200 million of liability insurance from commercial sources.
The Act also establishes an industry-wide retrospective rating plan under
which nuclear reactor owners could be assessed up to $79 million per reactor
(WE owns two), but not more than $10 million in any one year for each reactor,
in the event of a nuclear incident.
An industry-wide insurance program, with an aggregate limit of $200 million,
has been established to cover radiation injury claims of nuclear workers first
employed after 1987. If claims in excess of the available funds develop, WE
could be assessed a maximum of approximately $3.0 million per reactor.
WE has property damage, decontamination and decommissioning insurance totaling
$1.5 billion for loss from damage at Point Beach with Nuclear Mutual Limited
("NML") and Nuclear Electric Insurance Limited ("NEIL"). Under the NML and
NEIL policies, WE has a potential maximum retrospective premium liability per
loss of $5.6 million and $9.8 million, respectively.
WE also maintains additional insurance with NEIL covering extra expenses of
obtaining replacement power during a prolonged accidental outage (in excess of
21 weeks) at Point Beach. This insurance coverage provides weekly indemnities
of $3.5 million per unit for outages during the first year, declining to 80%
of the amounts during the second and third years. Under the policy, WE's
maximum retrospective premium liability is approximately $7.7 million.
- 70 -
71
NOTES TO FINANCIAL STATEMENTS - (cont'd)
F - Nuclear Operations - (cont'd)
It should not be assumed that, in the event of a major nuclear incident, any
insurance or statutory limitation of liability would protect WE from material
adverse impact.
Nuclear Decommissioning: Subject to approval by the PSCW of the Point Beach
Unit 2 steam generator replacements and resolution of the remanded ISFSI
matters described above, WE expects to operate the two units at Point Beach to
the expiration of their current operating licenses. The estimated cost to
decommission the plant in 1995 dollars is $356 million based upon a site
specific decommissioning cost study completed in 1994. Assuming plant
shutdown at the expiration of the current operating licenses, prompt
dismantlement and annual escalation of costs at specific inflation factors
established by the PSCW, it is projected that approximately $1.6 billion will
be spent over a twenty-year period, beginning in 2010, to decommission the
plant.
Nuclear decommissioning costs are accrued as depreciation expense over the
expected service lives of the two units based upon an external sinking fund
method. In 1996, WE has increased its funding levels based on a site specific
estimate as required by the PSCW. It is expected that the annual payments to
the Nuclear Decommissioning Trust Fund ("Fund") along with the earnings on the
Fund will provide sufficient funds at the time of decommissioning. WE
believes it is probable that any shortfall in funding would be recoverable in
utility rates.
As required by Statement of Financial Accounting Standards No. 115, Accounting
for Certain Investments in Debt and Equity Securities ("FAS 115"), WE's debt
and equity security investments in the Fund are classified as available for
sale. Gains and losses on the Fund were determined on the basis of specific
identification; net unrealized holding gains on the Fund were recorded as part
of accumulated provision for depreciation.
Following is a summary of decommissioning costs and earnings charged to
depreciation expense and the Fund balance included in accumulated provision
for depreciation at December 31. The Fund balance is stated at fair value:
==============================================================================
1995 1994 1993
-------- -------- --------
(Thousands of Dollars)
Decommissioning costs $ 3,456 $ 3,456 $ 3,456
Earnings 7,405 6,682 7,915
-------- -------- --------
Depreciation Expense $ 10,861 $ 10,138 $ 11,371
======== ======== ========
Total costs accrued to date $235,420 $224,559
Unrealized gain 39,705 2,246
-------- --------
Accumulated Provision for Depreciation $275,125 $226,805
======== ========
==============================================================================
- 71 -
72
NOTES TO FINANCIAL STATEMENTS - (cont'd)
G - Preferred Stock
Serial Preferred Stock authorized but unissued is cumulative, $25 par value,
5,000,000 shares.
In the event of default in the payment of preferred dividends, no dividends or
other distributions may be paid on the Company's common stock.
The 3.60% Series Preferred Stock is redeemable in whole or in part at the
option of WE at $101 per share plus any accrued dividends.
In 1994, WE called for redemption all of its 52,500 outstanding shares of
6.75% Series Preferred Stock at a redemption price of par. In 1993, WE called
for redemption 626,500 shares at a purchase price of $104.05 per share plus
accrued dividends to the redemption date.
H - Long-Term Debt
The maturities and sinking fund requirements through 2000 for the aggregate
amount of long-term debt outstanding (excluding obligations under capital
lease, see Note F) at December 31, 1995 are shown below:
==============================================================================
(Thousands of Dollars)
1996 $ 30,000
1997 165,700
1998 60,700
1999 91,700
2000 700
==============================================================================
Sinking fund requirements for the years 1996 through 2000, included in the
table above, are $2.8 million. Substantially all utility plant is subject to
the applicable mortgage.
Long-term debt premium or discount and expense of issuance are amortized by
the straight line method over the lives of the debt issues and included as
interest expense. Unamortized amounts pertaining to reacquired debt are
written off currently, when acquired for sinking fund purposes, or amortized
in accordance with PSCW orders, when acquired for early retirement.
The fair value of the Company's long-term debt was $1.5 billion and $1.2
billion at December 31, 1995 and 1994, respectively. The fair value of the
first mortgage bonds and debentures is estimated based upon the market value
of the same or similar issues. Book value approximates fair value for the
Company's unsecured notes. The fair value of WE's obligations under capital
lease is the market value of the Wisconsin Electric Fuel Trust's commercial
paper.
In September and October 1995, WE issued $98.35 million of unsecured variable
rate promissory notes maturing between March 1, 2006 and September 1, 2030.
These notes were issued as a revenue and collateral source for an equal
principal amount of tax exempt Refunding Revenue Bonds issued on WE's behalf
to refund $98.35 million of previously issued tax exempt bonds called for
optional redemption that were secured by WE's First Mortgage Bonds.
- 72 -
73
NOTES TO FINANCIAL STATEMENTS - (cont'd)
H - Long-Term Debt - (cont'd)
In December 1995, WE issued $100 million of unsecured One Hundred Year 6 7/8%
Debentures due 2095. Proceeds of the issue were added to WE's general funds
and were applied to the repayment of short-term borrowings.
At December 31, 1995, the interest rate for the $67 million variable rate note
due 2016 was 5.00% and the interest rate for the $98.35 million variable rate
notes due 2006-2030 was 5.10%.
I - Notes Payable
Short-term notes payable balances and their corresponding weighted average
interest rates consist of:
==============================================================================
December 31
1995 1994
-------------------- ----------------------
Interest Interest
Balance Rate Balance Rate
-------- -------- -------- --------
(Thousands of Dollars)
Banks $100,885 5.78% $ 87,399 6.03%
Commercial paper 49,809 5.88% 155,106 6.04%
-------- --------
$150,694 $242,505
======== ========
==============================================================================
Unused lines of credit for short-term borrowing amounted to $108.6 million at
December 31, 1995. In support of various informal lines of credit from banks,
the Company has agreed to maintain unrestricted compensating balances or to
pay commitment fees; neither the compensating balances nor the commitment fees
are significant.
J - Pension Plans
Effective in 1993, the PSCW adopted Statement of Financial Accounting
Standards No. 87, Employers' Accounting for Pensions ("FAS 87"), for
ratemaking.
WE has several defined benefit noncontributory pension plans covering all
eligible employees. Pension benefits are based on years of service and the
employee's compensation. The majority of the plans' assets are equity
securities; other assets include corporate and government bonds and real
estate. The plans are funded to meet the requirements of the Employee
Retirement Income Security Act of 1974.
In the opinion of the Company, current pension trust assets and amounts which
are expected to be paid to the trusts in the future will be adequate to meet
future pension payment obligations to current and future retirees.
- 73 -
74
NOTES TO FINANCIAL STATEMENTS - (cont'd)
J - Pension Plans - (cont'd)
==============================================================================
Pension Cost calculated per FAS 87 1995 1994 1993
- ---------------------------------- -------- -------- --------
(Thousands of Dollars)
Components of Net Periodic Pension Cost,
Year Ended December 31 -
Cost of pension benefits earned by
employees $ 8,985 $ 10,933 $ 10,842
Interest cost on projected benefit
obligation 41,586 38,736 36,335
Actual (return) loss on plan assets (136,243) 7,634 (43,226)
Net amortization and deferral 88,493 (52,180) 1,067
-------- -------- --------
Total pension cost calculated
under FAS 87 $ 2,821 $ 5,123 $ 5,018
======== ======== ========
Actuarial Present Value of Accumulated
Benefit Obligation, at December 31 -
Vested benefits-employees' right to
receive benefit no longer contingent
upon continued employment $543,371 $427,847
Nonvested benefits-employees' right to
receive benefit contingent upon
continued employment 12,651 9,963
-------- --------
Total obligation $556,022 $437,810
======== ========
Funded Status of Plans: Pension Assets and
Obligations at December 31 -
Pension assets at fair market value $637,529 $527,182
Projected benefit obligation
at present value (584,785) (513,166)
Unrecognized transition asset (22,034) (24,628)
Unrecognized prior service cost 23,194 19,567
Unrecognized net gain (54,780) (17,569)
-------- --------
Projected status of plans $ (876) $ (8,614)
======== ========
Rates used for calculations (%) -
Discount rate-interest rate used to
adjust for the time value of money 7.25 8.25 7.5
Assumed rate of increase in
compensation levels 4.75 5.0 5.0
Expected long-term rate of return
on pension assets 9.0 9.0 9.0
==============================================================================
K - Benefits Other Than Pensions
Postretirement Benefits: Effective in 1993, the Company adopted prospectively
Statement of Financial Accounting Standards No. 106, Employers' Accounting for
Postretirement Benefits Other Than Pensions ("FAS 106") and elected the 20
year option for amortization of the previously unrecognized accumulated
- 74 -
75
NOTES TO FINANCIAL STATEMENTS - (cont'd)
K - Benefits Other Than Pensions - (cont'd)
postretirement benefit obligation. The PSCW has issued an order recognizing
FAS 106 for ratemaking; therefore adoption has no material impact on net
income.
WE sponsors defined benefit postretirement plans that cover both salaried and
nonsalaried employees who retire at age 55 or older with at least 10 years of
credited service. The postretirement medical plan provides coverage to
retirees and their dependents. Retirees contribute to the medical plan. The
group life insurance benefit is based on employee compensation and is reduced
upon retirement.
Employees' Benefit Trusts ("Trusts") are used to fund a major portion of
postretirement benefits. The funding policy for the Trusts is to maximize tax
deductibility. The majority of the Trusts' assets are mutual funds.
==============================================================================
Postretirement Benefit Cost
calculated per FAS 106 1995 1994 1993
- ------------------------------------------- -------- -------- --------
(Thousands of Dollars)
Components of Net Periodic Postretirement
Benefit Cost, Year Ended December 31 -
Cost of postretirement benefits
earned by employees $ 2,276 $ 2,653 $ 3,105
Interest cost on projected
benefit obligation 10,458 10,148 10,395
Actual return on plan assets (12,598) (3,893) (2,388)
Net amortization and deferral 13,951 5,648 5,082
-------- -------- --------
Total postretirement benefit cost
calculated under FAS 106 $ 14,087 $ 14,556 $ 16,194
======== ======== ========
Funded Status of Plans: Postretirement
Obligations and Assets at December 31 -
Accumulated Postretirement Benefit
Obligation at December 31 -
Retirees $(92,746) $(83,670)
Fully eligible active plan participants (10,304) (7,223)
Other active plan participants (41,732) (37,255)
-------- --------
Total obligation (144,782) (128,148)
Postretirement assets at
fair market value 45,086 37,919
-------- --------
Accumulated postretirement benefit
obligation in excess of plan assets (99,696) (90,229)
Unrecognized transition obligation 83,268 90,302
Unrecognized prior service cost (1,279) (1,169)
Unrecognized net gain (6,102) (16,484)
-------- --------
Accrued Postretirement Benefit Obligation $(23,809) $(17,580)
======== ========
==============================================================================
- 75 -
76
NOTES TO FINANCIAL STATEMENTS - (cont'd)
K - Benefits Other Than Pensions - (cont'd)
==============================================================================
Postretirement Benefit Cost
calculated per FAS 106 (cont'd) 1995 1994 1993
- ------------------------------------------- -------- -------- --------
(Thousands of Dollars)
Rates used for calculations (%) -
Discount rate-interest rate used to
adjust for the time value of money 7.25 8.25 7.5
Assumed rate of increase in
compensation levels 4.75 5.0 5.0
Expected long-term rate of return
on postretirement assets 9.0 9.0 9.0
Health care cost trend rate 11.0 declining to
5.0 in year 2002
==============================================================================
Changes in health care cost trend rates will affect the amounts reported. For
example, a 1% increase in rates would increase the accumulated postretirement
benefit obligation as of December 31, 1995 by $9.5 million and the aggregate
of the service and interest cost components of net periodic postretirement
benefit cost for the year then ended by $1 million.
Revitalization: In the first quarter of 1994, WE recorded a $73.9 million
charge related to its revitalization program. This charge included $37.5
million for Early Retirement Incentive Packages ("ERIP") and $25 million for
Severance Packages ("SP"). These plans were used to reduce employee staffing
levels. ERIP provided for a monthly income supplement ("ERIP supplement"),
medical benefits and waiver of an early retirement pension reduction. The SP
included a severance payment, medical/dental insurance, outplacement services,
personal financial planning and tuition support. Availability of these plans
to various bargaining units was based upon agreements made between WE and the
bargaining units. These plans were available to most management employees but
not to elected officers.
Under ERIP, 403 employees elected to retire in 1994. Under SP, 651 and 75
employees enrolled in 1994 and 1995, respectively. ERIP supplement costs are
paid from pension plan trusts and medical/dental benefits from employee
benefit trusts. Remaining ERIP and SP costs are paid from general corporate
funds. The ultimate timing of cash flows for ERIP supplement costs depends
upon the funding limitations of WE's pension plans. With the exception of
ERIP supplement costs, approximately $35.4 million have been paid against the
revitalization liability through December 31, 1995, and a liability of $0.9
million remains outstanding at December 31, 1995.
L - Information By Segments of Business
WE is a public utility incorporated in the State of Wisconsin. The Company's
principal business segments include electric, gas and steam utility
operations. The electric utility generates, transmits, distributes and sells
electric energy in southeastern (including metropolitan Milwaukee), east
central and northern Wisconsin and in the Upper Peninsula of Michigan. The
gas utility purchases, distributes and sells natural gas to retail customers
and transports customer-owned gas in three service areas in southeastern, east
central and western Wisconsin that are largely within the electric service
- 76 -
77
NOTES TO FINANCIAL STATEMENTS - (cont'd)
L - Information By Segments of Business - (cont'd)
area. The steam utility produces, distributes and sells steam to space
heating and processing customers in downtown and the near south side of
Milwaukee. The following summarizes the business segments of the Company:
==============================================================================
Year ended December 31 1995 1994 1993
- ---------------------- ---------- ---------- ----------
(Thousands of Dollars)
Electric Operations
Operating revenues $1,437,480 $1,403,562 $1,347,844
Operating income before income taxes 419,271 329,216 329,727
Depreciation 164,789 159,414 149,646
Construction expenditures 223,723 244,718 305,467
Gas Operations
Operating revenues 318,262 324,349 331,301
Operating income before income taxes 47,022 30,993 31,025
Depreciation 17,722 16,856 16,235
Construction expenditures 24,851 25,481 24,419
Steam Operations
Operating revenues 14,742 14,281 14,090
Operating income before income taxes 3,757 2,825 3,147
Depreciation 1,365 1,344 1,185
Construction expenditures 206 1,213 4,940
Total
Operating revenues 1,770,484 1,742,192 1,693,235
Operating income before income taxes 470,050 363,034 363,899
Depreciation 183,876 177,614 167,066
Construction expenditures
(including non-utility) 248,867 271,448 334,932
At December 31
- --------------
Net Identifiable Assets
Electric $3,901,611 $3,797,755 $3,665,493
Gas 386,864 376,344 385,390
Steam 25,214 25,315 25,119
Non-utility 5,235 2,779 2,971
---------- ---------- ----------
Total Assets $4,318,924 $4,202,193 $4,078,973
========== ========== ==========
==============================================================================
M - Transactions with Associated Companies
Managerial, financial, accounting, legal, data processing and other services
may be rendered between associated companies and are billed in accordance with
service agreements approved by the PSCW. The Company received from WEC
stockholder capital contributions of $30 million in 1995 and 1994, and $10
million in 1993.
- 77 -
78
NOTES TO FINANCIAL STATEMENTS - (cont'd)
N - Commitments and Contingencies
Kimberly Cogeneration Facility: In 1993, a competitive bidding process
conducted by the PSCW resulted in selection of a proposal submitted by an
unaffiliated independent power producer, LSP-Whitewater L.P. ("LS Power"), to
construct a generation facility to meet a portion of WE's anticipated increase
in system supply needs. WE subsequently signed a long-term agreement to
purchase electricity from the proposed facility. The agreement is contingent
upon the facility being completed and going into operation, which at this time
is planned for mid-1997.
Prior to the 1993 selection of the LS Power generation facility by the PSCW,
WE had proposed to construct its own 220 megawatt cogeneration facility in
Kimberly, Wisconsin, which was intended to provide process steam to Repap
Wisconsin, Inc. ("Repap") starting in mid-1994. In the PSCW Order, the WE
project was selected as the second place conditional project if the LS Power
project did not proceed. WE had made expenditures for the Kimberly facility
of approximately $65.8 million associated with the procurement of three
combustion turbines, one steam turbine and three heat recovery boilers in
order to achieve the in-service dates as agreed to in a steam service contract
with Repap.
The Company is currently reviewing other options for use or sale of its
Kimberly Cogeneration Facility equipment (the "Equipment"). The Equipment is
of a technology of natural gas-fired combined cycle generation equipment that
is marketed worldwide. The Company is investigating opportunities to sell the
Equipment or to use it in another power project and is currently evaluating
potential sales opportunities and/or power projects involving the Equipment.
At this time, the Company does not believe that disposition of the Equipment
will have a material adverse effect on its financial condition. However,
there is a possibility that WE may need to recognize an impairment of the
Equipment in the future should the projects noted above not occur and should
no other viable sales opportunities and/or power projects involving the
Equipment be identified.
Manufactured Gas Plant Sites: WE's natural gas business unit is investigating
the remediation of a number of former manufactured gas plant ("MGP") sites.
Operations at these MGP sites ceased over 40 years ago. Limited remediation
activities occurred at a number of these sites during the 1980's, with removal
of waste materials known to be present at that time. In 1995, WE presented a
plan to investigate and remediate sites to the Wisconsin Department of Natural
Resources ("DNR"). During 1995, WE conducted site investigations at four
sites and partial remediation activities were conducted at one site.
Approximately $1.6 million has been spent through December 31, 1995 for such
activities. Remediation costs to be incurred through the year 2000 have been
estimated to be $12 million, but the total costs are uncertain pending the
results of further site specific investigations and the selection of site
specific remedial actions. In a September 11, 1995 letter order, the PSCW
allowed WE to defer MGP site remediation costs with final rate treatment of
such costs to be determined in future rate cases. As of December 31, 1995, WE
has recorded an accrued liability of $1.6 million for MGP site remediation and
a related deferred regulatory asset of $3.2 million. WE expects to accrue
additional MGP site remediation liabilities during 1996 as site specific
investigations are completed and site specific remedial actions are
identified. WE will seek rate recovery for these costs and does not
anticipate that there will be a material adverse effect on its net income or
financial position.
- 78 -
79
NOTES TO FINANCIAL STATEMENTS - (cont'd)
N - Commitments and Contingencies - (cont'd)
Plans for the construction and financing of future additions to utility plant
can be found elsewhere in this report in MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - "LIQUIDITY AND CAPITAL
RESOURCES - Capital Requirements 1996-2000."
- 79 -
80
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors and the
Stockholders of Wisconsin Electric Power Company
In our opinion, the financial statements listed under Item 14(a)(1) appearing
on page 82 of this report present fairly, in all material respects, the
financial position of Wisconsin Electric Power Company at December 31, 1995
and 1994, and the results of its operations and its cash flows for each of the
three years in the period ended December 31, 1995, in conformity with
generally accepted accounting principles. These financial statements are the
responsibility of the Company's management; our responsibility is to express
an opinion on these financial statements based on our audits. We conducted
our audits of these statements in accordance with generally accepted auditing
standards which require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of
material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements, assessing
the accounting principles used and significant estimates made by management,
and evaluating the overall financial statement presentation. We believe that
our audits provide a reasonable basis for the opinion expressed above.
/s/Price Waterhouse LLP
- -----------------------
PRICE WATERHOUSE LLP
Milwaukee, Wisconsin
January 31, 1996
- 80 -
81
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
ACCOUNTING AND FINANCIAL DISCLOSURE
None.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
In accordance with General Instruction G(3) of Form 10-K, the information
under "Election of Directors" in WE's definitive Information Statement for its
Annual Meeting of Stockholders to be held May 21, 1996 (the "1996 Annual
Meeting Information Statement") is incorporated herein by reference. Also see
"Executive Officers of the Registrant" in Part I of this report.
ITEM 11. EXECUTIVE COMPENSATION
In accordance with General Instruction G(3) of Form 10-K, the information
under "Compensation" and "Retirement Plans" in the 1996 Annual Meeting
Information Statement is incorporated herein by reference.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND
MANAGEMENT
All of WE's Common Stock (100% of such class) is owned by the parent company,
Wisconsin Energy Corporation, 231 West Michigan Street, P.O. Box 2949,
Milwaukee, Wisconsin 53201. The directors, director nominees and executive
officers of WE do not own any of the voting securities of WE. In accordance
with General Instruction G(3) of Form 10-K, the information concerning their
beneficial ownership of WEC stock set forth under "Stock Ownership of
Directors, Nominees and Executive Officers" in the 1996 Annual Meeting
Information Statement is incorporated herein by reference.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
None.
- 81 -
82
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS
ON FORM 8-K
(a) 1. Financial Statements and Report of Independent Accountants
Included in Part II of this report:
Income Statement for the three years ended
December 31, 1995
Statement of Cash Flows for the three years ended
December 31, 1995
Balance Sheet at December 31, 1995 and 1994
Capitalization Statement at December 31, 1995 and 1994
Common Stock Equity Statement for the three years ended
December 31, 1995
Notes to Financial Statements
Report of Independent Accountants
2. Financial Statement Schedules are omitted because of the
absence of conditions under which they are required or
because the required information is given in the
financial statements or notes thereto.
* * * * *
The following Wisconsin Energy Company Unaudited Pro Forma Combined
Condensed Financial Information is contained herein after this
Item 14:
Unaudited Pro Forma Combined Condensed Balance Sheet at
December 31, 1995
Unaudited Pro Forma Combined Condensed Statements of Income
for the 12 months ended December 31, 1995
Notes to Unaudited Pro Forma Combined Condensed Financial
Statements
3. Exhibits
The following Exhibits are filed with this report:
Exhibit No.
(3)-1 Bylaws of Wisconsin Electric Power Company ("WE"),
as amended and restated January 31, 1996.
(4)-1 Indenture for Debt Securities (the
"Indenture") dated as of December 1, 1995.
- 82 -
83
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS
ON FORM 8-K - (cont'd)
(4)-2 Securities Resolution No. 1 under the
Indenture dated December 5, 1995.
(23)-1 Price Waterhouse LLP - Milwaukee, WI Consent of
Independent Accountants appearing on page 87 of this
Annual Report on Form 10-K for the year ended
December 31, 1995.
(23)-2 Consent of Price Waterhouse LLP - Minneapolis, MN,
Northern States Power Company - Wisconsin's ("NSP-WI")
Independent Accountants.
(23)-3 Consent of Deloitte & Touche LLP - Minneapolis, MN,
NSP-WI's Independent Auditors prior to 1995.
(27)-1 WE Financial Data Schedule for the fiscal year ended
December 31, 1995.
In addition to those Exhibits shown above, which are filed herewith, WE hereby
incorporates the following Exhibits pursuant to Exchange Act Rule 12b-32 and
Regulation Section 201.24 by reference to the filings set forth below:
(2)-1 Amended and Restated Agreement and Plan of Merger, dated as of
April 28, 1995, as amended and restated as of July 26, 1995, by and
among Northern States Power Company ("NSP"), Wisconsin Energy
Corporation ("WEC"), Northern Power Wisconsin Corp. ("New NSP") and
WEC Sub Corp. (Exhibit (2)-1 to WEC's Registration Statement on
Form S-4 filed on August 7, 1995, Registration No. 33-61619
("Form S-4, No. 33-61619"); other related documents are also filed as
exhibits to such Registration Statement.)
(2)-2 WEC Stock Option Agreement, dated as of April 28, 1995, by and among
NSP and WEC. (Exhibit (2)-2 to Form S-4, No. 33-61619.)
(2)-3 NSP Stock Option Agreement, dated as of April 28, 1995, by and among
WEC and NSP. (Exhibit (2)-3 to Form S-4, No. 33-61619.)
(2)-4 Committees of the Board of Directors of Primergy Corporation
("Primergy"). (Exhibit (2)-4 to Form S-4, No. 33-61619.)
(2)-5 Form of Employment Agreement between Primergy and James J. Howard.
(Exhibit (2)-5 to Form S-4, No. 33-61619.)
(2)-6 Form of Employment Agreement between Primergy and Richard A. Abdoo.
(Exhibit (2)-6 to Form S-4, No. 33-61619.)
(2)-7 Form of Amended and Restated Articles of Incorporation of New NSP.
(Exhibit 3-3 (b) to Form S-4, No. 33-61619.)
(2)-8 Letter Agreement, dated January 17, 1995, between NSP and WEC.
(Exhibit (2)-8 to WEC's Schedule 13D dated May 4, 1995 with respect
to the NSP Stock Option Agreement.)
- 83 -
84
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS
ON FORM 8-K - (cont'd)
(2)-9 Letter Agreement, dated April 26, 1995, between NSP and WEC amending
Letter Agreement dated January 17, 1995. (Exhibit (2)-9 to WEC's
Schedule 13D dated May 4, 1995 with respect to the NSP Stock Option
Agreement.)
(2)-10 Plan and Agreement of Merger, dated June 30, 1994, by and between WE
and Wisconsin Natural Gas Company ("WN"). (Appendix A to WE's Proxy
Statement dated October 31, 1994, in File No. 1-1245.)
(3)-2 Restated Articles of Incorporation of WE, as amended and restated
effective January 10, 1995. (Exhibit (3)-1 to WE's Annual Report on
Form 10-K for the year ended December 31, 1994, File No. 1-1245.)
(4)-3 Reference is made to Article III of the Restated Articles of
Incorporation of WE. (Exhibit (3)-2 herein.)
Mortgage, Indenture,
Supplemental Indenture
or Securities
Resolution Company Date Exhibit # Under File No.
- ------------------------------------------------------------------------------
(4)- 4 Mortgage and Wisconsin 10/28/38 B-1 2-4340
Deed of Trust Electric
("WE")
5 Second WE 6/1/46 7-C 2-6422
6 Third WE 3/1/49 7-C 2-8456
7 Fourth WE 6/1/50 7-D 2-8456
8 Fifth WE 5/1/52 4-G 2-9588
9 Sixth WE 5/1/54 4-H 2-10846
10 Seventh WE 4/15/56 4-I 2-12400
11 Eighth WE 4/1/58 2-I 2-13937
12 Ninth WE 11/15/60 2-J 2-17087
13 Tenth WE 11/1/66 2-K 2-25593
14 Eleventh WE 11/15/67 2-L 2-27504
15 Twelfth WE 5/15/68 2-M 2-28799
16 Thirteenth WE 5/15/69 2-N 2-32629
17 Fourteenth WE 11/1/69 2-O 2-34942
18 Fifteenth WE 7/15/76 2-P 2-54211
19 Sixteenth WE 1/1/78 2-Q 2-61220
20 Seventeenth WE 5/1/78 2-R 2-61220
21 Eighteenth WE 5/15/78 2-S 2-61220
22 Nineteenth WE 8/1/79 (a)2(a) 1-1245 (9/30/79
WE Form 10-Q)
23 Twentieth WE 11/15/79 (a)2(a) 1-1245 (12/31/79
WE Form 10-K)
24 Twenty-First WE 4/15/80 (4)-21 2-69488
25 Twenty-Second WE 12/1/80 (4)-1 1-1245 (12/31/80
WE Form 10-K)
26 Twenty-Third WE 9/15/85 (4)-1 1-1245 (9/30/85
WE Form 10-Q)
27 Twenty-Four WE 9/15/85 (4)-1 1-1245 (9/30/85
WE Form 10-Q)
28 Twenty-Fifth WE 12/15/86 (4)-25 1-1245 (12/31/86
WE Form 10-K)
- 84 -
85
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS
ON FORM 8-K - (cont'd)
Mortgage, Indenture,
Supplemental Indenture
or Securities
Resolution Company Date Exhibit # Under File No.
- ------------------------------------------------------------------------------
29 Twenty-Sixth WE 1/15/88 4 1-1245 (1/26/88
Form 8-K)
30 Twenty-Seventh WE 4/15/88 4 1-1245 (3/31/88
Form 10-Q)
31 Twenty-Eighth WE 9/1/89 4 1-1245 (9/30/89
WE Form 10-Q)
32 Twenty-Ninth WE 10/1/91 4-1 1-1245 (12/31/91
WE Form 10-K)
33 Thirtieth WE 12/1/91 4-2 1-1245 (12/31/91
WE Form 10-K)
34 Thirty-First WE 8/1/92 4-1 1-1245 (6/30/92
WE Form 10-Q)
35 Thirty-Second WE 8/1/92 4-2 1-1245 (6/30/92
WE Form 10-Q)
36 Thirty-Third WE 10/1/92 4-1 1-1245 (9/30/92
WE Form 10-Q)
37 Thirty-Fourth WE 11/1/92 4-2 1-1245 (9/30/92
WE Form 10-Q)
38 Thirty-Fifth WE 12/15/92 4-1 1-1245 (12/31/92
WE Form 10-K)
39 Thirty-Sixth WE 1/15/93 4-2 1-1245 (12/31/92
WE Form 10-K)
40 Thirty-Seventh WE 3/15/93 4-3 1-1245 (12/31/92
WE Form 10-K)
41 Thirty-Eighth WE 8/01/93 (4)-1 1-1245 (6/30/93
WE Form 10-Q)
42 Thirty-Ninth WE 9/15/93 (4)-1 1-1245 (9/30/93
WE Form 10-Q)
43 Fortieth WE 1/01/96 (4)-1 1-1245 (1/1/96
WE Form 8-K)
All agreements and instruments with respect to long-term debt not
exceeding 10 percent of the total assets of the Registrant and its
subsidiaries on a consolidated basis have been omitted as permitted
by related instructions. The Registrant agrees pursuant to Item
601(b)(4) of Regulation S-K to furnish to the Securities and Exchange
Commission, upon request, a copy of all such agreements and
instruments.
(10)-1 Amended Non-Qualified Trust Agreement by and between WEC and Firstar
Trust Company dated January 26, 1996, regarding trust established to
provide a source of funds to assist in meeting of the liabilities under
various nonqualified deferred compensation plans made between WEC or
its subsidiaries and various plan participants. (Exhibit (10)-2 to
WEC's Annual Report on Form 10-K for the year ended December 31, 1995,
File No. 1-9057.) *
(10)-2 Supplemental Benefits Agreement between WEC and Richard A. Abdoo dated
November 21, 1994, and April 26, 1995 letter agreement.
(Exhibit (10)-1 to WEC's Quarterly Report on Form 10-Q for the quarter
ended June 30, 1995, File No. 1-9057. ("WEC's 6/30/95 10-Q")) *
- 85 -
86
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS
ON FORM 8-K - (cont'd)
(10)-3 WEC Senior Executive Severance Policy, as adopted effective
April 28, 1995 and amended on July 26, 1995. (Exhibit (10)-3 to
WEC's 6/30/95 10-Q.) *
(10)-4 Service Agreement dated January 1, 1987, between WE, WEC and other
non-utility affiliated companies. (Exhibit (10)-(a) to WE's Current
Report on Form 8-K dated January 2, 1987 in File No. 1-1245.)
(99)-1 Wisconsin Energy Company unaudited pro forma combined condensed
statements of income for each of the three years in the period ended
December 31, 1994. (Included in WE's Current Report on Form 8-K dated
as of August 25, 1995, File No. 1-1245.)
(99)-2 Audited Financial Statements of NSP-WI. (Item 8 of NSP-WI's Annual
Report on Form 10-K for the fiscal year ended December 31, 1995, File
No. 10-3140):
Report of Independent Accountants.
Independent Auditor's Report for years prior to 1995.
Statements of Income and Retained Earnings for the three years ended
December 31, 1995.
Statements of Cash Flows for the three years ended December 31, 1995.
Balance Sheets at December 31, 1995 and 1994.
Notes to Financial Statements.
- -----------------------
* Management contracts and executive compensation plans or arrangements
required to be filed as exhibits pursuant to Item 14(c) of Form 10-K.
Certain compensatory plans in which directors or executive officers of
the Registrant are eligible to participate are not filed in reliance
on the exclusion in Item 601(b)(10)(iii)(B)(6) of Regulation S-K.
(b) Reports on Form 8-K
No reports on Form 8-K were filed during the fourth quarter of the year
ended December 31, 1995.
A Current Report on Form 8-K dated as of January 1, 1996 was filed on
January 16, 1996 to report the consummation of the merger of WN into WE,
incorporate by reference or file related historical and pro forma
financial statements and exhibits, and report developments concerning
WE's Point Beach Nuclear Plant independent spent fuel storage
installation.
- 86 -
87
CONSENT OF INDEPENDENT ACCOUNTANTS
We hereby consent to the incorporation by reference in the Registration
Statements and Prospectuses constituting part of the Registration Statements
on Form S-3 (Nos. 33-51749 and 33-64343) of Wisconsin Electric Power Company
of our report dated January 31, 1996 appearing in this Form 10-K.
/s/Price Waterhouse LLP
- -----------------------
PRICE WATERHOUSE LLP
Milwaukee, Wisconsin
March 28, 1996
- 87 -
88
WISCONSIN ENERGY COMPANY
UNAUDITED PRO FORMA COMBINED CONDENSED FINANCIAL INFORMATION
On April 28, 1995, Wisconsin Energy Corporation ("WEC"), Wisconsin Electric
Power Company's ("WE") parent company, entered into an Agreement and Plan of
Merger with Northern States Power Company, a Minnesota corporation ("NSP"),
which was amended and restated as of July 26, 1995 (the "Merger Agreement").
The Merger Agreement provides for a strategic business combination involving
the two companies in a "merger-of-equals" transaction (the "Transaction"), as
previously reported in WE's Current Report on Form 8-K dated as of August 25,
1995 and in its Quarterly Reports on Form 10-Q for the quarters ended
March 31, 1995, June 30, 1995 and September 30, 1995 ("WE's 3/31/95, 6/30/95
and 9/30/95 10-Q's"). Detailed information with respect to the Merger
Agreement and the proposed Transaction is contained in the Joint Proxy
Statement / Prospectus dated August 7, 1995 (contained in WEC's Registration
Statement on Form S-4, Registration No. 33-61619) relating to the meetings of
the stockholders of WEC and NSP to vote on the Merger Agreement and related
matters.
Further information concerning the Merger Agreement and the proposed
Transaction is included in Item 1. BUSINESS - "MERGER AGREEMENT WITH NORTHERN
STATES POWER COMPANY", in Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - "RESULTS OF OPERATIONS -
Mergers" and in Note B - "Mergers" in the NOTES TO FINANCIAL STATEMENTS in
Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA in this report.
As a result of the Transaction, WEC will become a registered public utility
holding company under the Public Utility Holding Company Act of 1935, as
amended, and will change its name to Primergy Corporation ("Primergy").
Primergy will be the parent company of WE (which will be renamed Wisconsin
Energy Company), of NSP (which, for regulatory reasons, will reincorporate in
Wisconsin ("New NSP")), and of the other subsidiaries of WEC and NSP. In
connection with the Transaction, Northern States Power Company, a Wisconsin
corporation ("NSP-WI"), currently a utility subsidiary of NSP, will be merged
into Wisconsin Energy Company. Prior to the merger of NSP-WI into Wisconsin
Energy Company, New NSP will acquire certain gas utility assets and
liabilities of NSP-WI divisions in LaCrosse and Hudson, Wisconsin from NSP-WI.
The following unaudited pro forma financial information combines the
historical consolidated balance sheets and statements of income of WE (as
restated to reflect the merger of WN into WE effective January 1, 1996) and
NSP-WI after giving effect to the proposed Transaction. The unaudited pro
forma combined condensed balance sheet information at December 31, 1995 give
effect to the Transaction as if it had occurred at December 31, 1995. The
unaudited pro forma combined condensed statements of income for the twelve
months ended December 31, 1995 gives effect to the Transaction as if it had
occurred at January 1, 1995. This financial information is prepared on the
basis of accounting for the Transaction as a pooling of interests. WE's
Current Report on Form 8-K dated as of August 25, 1995 contains unaudited pro
forma combined condensed statements of income of Wisconsin Energy Company for
each of the three years in the period ended December 31, 1994, which are not
repeated herein, but are incorporated by reference as an exhibit to this
report.
The following unaudited pro forma financial information has been prepared
from, and should be read in conjunction with, the historical consolidated
financial statements and related notes thereto of WE and NSP-WI. The
- 88 -
89
WISCONSIN ENERGY COMPANY
UNAUDITED PRO FORMA COMBINED CONDENSED FINANCIAL INFORMATION -
(cont'd)
following information is not necessarily indicative of the financial position
or operating results that would have occurred had the Transaction been
consummated on the date, or at the beginning of the period for which the
Transaction is being given effect nor is it necessarily indicative of future
operating results or financial position.
- 89 -
90
NORTHERN STATES POWER COMPANY - WISCONSIN
UNAUDITED PRO FORMA CONDENSED BALANCE SHEET
DECEMBER 31, 1995
(In thousands)
NSP-WI Pro Forma NSP-WI
Pro Forma Balance Sheet As Reported Adjustments As Adjusted
------------------------------------------ ------------ ------------ ------------
(Note 2)
Assets
Utility Plant
Electric $ 864,514 $ - $ 864,514
Gas 94,425 (33,644) 60,781
Other 63,758 - 63,758
------------ ------------ ------------
Total 1,022,697 (33,644) 989,053
Accumulated provision for depreciation (370,634) 15,215 (355,419)
Nuclear fuel - net - - -
------------ ------------ ------------
Net Utility Plant 652,063 (18,429) 633,634
Current Assets 85,591 16,836 102,427
Other Assets 53,244 (944) 52,300
------------ ------------ ------------
Total Assets $ 790,898 $ (2,537) $ 788,361
============ ============ ============
Liabilities and Equity
Capitalization
Common stock equity $ 318,299 $ - $ 318,299
Cumulative preferred stock and premium - - -
Long-term debt 213,235 - 213,235
------------ ------------ ------------
Total Capitalization 531,534 - 531,534
Current Liabilities
Current portion of long-term debt - - -
Short-term debt 50,900 - 50,900
Other 51,362 (38) 51,324
------------ ------------ ------------
Total Current Liabilities 102,262 (38) 102,224
Other Liabilities 157,102 (2,499) 154,603
------------ ------------ ------------
Total Capitalization and Liabilities $ 790,898 $ (2,537) $ 788,361
============ ============ ============
<FN>
See accompanying notes to unaudited pro forma combined condensed financial statements.
- 90 -
91
WISCONSIN ENERGY COMPANY *
UNAUDITED PRO FORMA COMBINED CONDENSED BALANCE SHEET
DECEMBER 31, 1995
(In thousands)
Adjusted
WE NSP-WI Pro Forma Pro Forma
Pro Forma Balance Sheet As Reported As Adjusted Adjustments Combined
------------------------------------------ ------------ ------------ ------------ ------------
(See Page 93) (Note 3)
Assets
Utility Plant
Electric $ 4,608,120 $ 864,514 $ - $ 5,472,634
Gas 491,176 60,781 - 551,957
Other 40,078 63,758 - 103,836
------------ ------------ ------------ ------------
Total 5,139,374 989,053 - 6,128,427
Accumulated provision for depreciation (2,288,080) (355,419) - (2,643,499)
Nuclear fuel - net 59,260 - - 59,260
------------ ------------ ------------ ------------
Net Utility Plant 2,910,554 633,634 - 3,544,188
Current Assets 517,724 102,427 - 620,151
Other Assets 890,646 52,300 (136,581) 806,365
------------ ------------ ------------ ------------
Total Assets $ 4,318,924 $ 788,361 $ (136,581) $ 4,970,704
============ ============ ============ ============
Liabilities and Equity
Capitalization
Common stock equity $ 1,696,565 $ 318,299 $ - $ 2,014,864
Cumulative preferred stock and premium 30,451 - - 30,451
Long-term debt 1,325,169 213,235 - 1,538,404
------------ ------------ ------------ ------------
Total Capitalization 3,052,185 531,534 - 3,583,719
Current Liabilities
Current portion of long-term debt 51,419 - - 51,419
Short-term debt 150,694 50,900 - 201,594
Other 222,571 51,324 - 273,895
------------ ------------ ------------ ------------
Total Current Liabilities 424,684 102,224 - 526,908
Other Liabilities 842,055 154,603 (136,581) 860,077
------------ ------------ ------------ ------------
Total Capitalization and Liabilities $ 4,318,924 $ 788,361 $ (136,581) $ 4,970,704
============ ============ ============ ============
<FN>
See accompanying notes to unaudited pro forma combined condensed financial statements.
* In connection with the Merger Agreement, WE will be renamed Wisconsin Energy Company.
- 91 -
92
WISCONSIN ENERGY COMPANY *
UNAUDITED PRO FORMA COMBINED CONDENSED STATEMENTS OF INCOME
12 MONTHS ENDED DECEMBER 31, 1995
(In thousands)
WE NSP-WI Pro Forma Pro Forma
As Reported As Reported Adjustments Combined
----------- ----------- ----------- -----------
Utility Operating Revenues
Electric $ 1,437,480 $ 380,724 $ - $ 1,818,204
Gas 318,262 78,058 - 396,320
Steam 14,742 - - 14,742
----------- ----------- ----------- -----------
Total Operating Revenues 1,770,484 458,782 - 2,229,266
Utility Operating Expenses
Electric production - fuel
and purchased power 345,387 178,446 - 523,833
Cost of gas sold
and transported 188,764 52,356 - 241,120
Other operation 395,242 79,472 - 474,714
Maintenance 112,400 20,780 - 133,180
Depreciation and amortization 183,876 33,059 - 216,935
Taxes other than income taxes 74,765 14,109 - 88,874
Income taxes 141,029 24,662 - 165,691
----------- ----------- ----------- -----------
Total Operating Expenses 1,441,463 402,884 - 1,844,347
----------- ----------- ----------- -----------
Utility Operating Income 329,021 55,898 - 384,919
Other Income (Expense) 21,272 2,421 - 23,693
----------- ----------- ----------- -----------
Income Before Interest Charges
and Preferred Dividends 350,293 58,319 - 408,612
Interest Charges 109,625 19,102 - 128,727
----------- ----------- ----------- -----------
Net Income 240,668 39,217 - 279,885
Preferred Dividend
Stock Requirement 1,203 - - 1,203
----------- ----------- ----------- -----------
Earnings Available
for Common Stockholder $ 239,465 $ 39,217 $ - $ 278,682
=========== =========== =========== ===========
<FN>
See accompanying notes to unaudited pro forma combined condensed financial statements.
* In connection with the Merger Agreement, WE will be renamed Wisconsin Energy Company.
Note: Earnings per share of common stock are not applicable because all of the Wisconsin Energy Company
common stock will be owned by Primergy.
- 92 -
93
WISCONSIN ENERGY COMPANY *
NOTES TO UNAUDITED PRO FORMA COMBINED CONDENSED FINANCIAL STATEMENTS
1. The unaudited pro forma combined condensed financial statements reflect
the previously planned merger by WEC of WN into WE to form a single
combined utility subsidiary. Completion of the planned merger occurred on
January 1, 1996. WE's financial information has been restated to include
WN.
As previously reported, on April 28, 1995, WEC, WE's parent company, and
NSP entered into a Merger Agreement, which was amended and restated as of
July 26, 1995. The Merger Agreement provides for a strategic business
combination involving WEC and NSP in a "merger-of-equals" transaction. As
a result, WEC will become a registered public utility holding company
under the Public Utility Holding Company Act of 1935, as amended, and will
change its name to Primergy Corporation ("Primergy"). Primergy will be
the parent company of NSP, WE (which will be renamed Wisconsin Energy
Company) and the other subsidiaries of WEC and NSP. The business
combination is intended to be tax-free for income tax purposes and to be
accounted for as a "pooling of interests". Subject to obtaining all
requisite approvals, WEC and NSP anticipate completing this business
combination by January 1, 1997.
As part of this proposed merger, the unaudited pro forma combined
condensed financial statements reflect the merger of NSP-WI, currently a
wholly owned subsidiary of NSP, into Wisconsin Energy Company. Prior to
the merger of NSP-WI into Wisconsin Energy Company, New NSP will acquire
certain gas utility assets in LaCrosse and Hudson, Wisconsin from NSP-WI.
2. A pro forma adjustment has been made in the NSP-WI Unaudited Pro Forma
Condensed Balance Sheet at December 31, 1995 to reflect the sale at net
book value of the gas utility assets and liabilities of NSP-WI divisions
in LaCrosse and Hudson, Wisconsin to New NSP.
3. A pro forma adjustment has been made in the Wisconsin Energy Company
Unaudited Pro Forma Combined Condensed Balance Sheet at December 31, 1995
to conform the presentation of noncurrent deferred income taxes into one
net amount. All other financial statement presentation and accounting
policy differences are immaterial and have not been adjusted in the
unaudited pro forma combined condensed financial statements.
4. Unaudited pro forma income statement amounts for Wisconsin Energy Company
do not reflect the transfer of the LaCrosse and Hudson divisions by NSP-WI
to New NSP. The revenues related to those divisions for the twelve months
ended December 31, 1995 were $28,897,000. The amount of related expenses
has not been quantified.
5. Intercompany transactions (including purchased power and exchanged power
transactions) between WE and NSP-WI during the period presented were not
material and, accordingly, no pro forma adjustments were made to eliminate
such transactions.
* In connection with the Merger Agreement, WE will be renamed Wisconsin Energy
Company.
- 93 -
94
WISCONSIN ENERGY COMPANY *
NOTES TO UNAUDITED PRO FORMA COMBINED CONDENSED FINANCIAL STATEMENTS (Cont'd)
6. The allocation between NSP and WEC and their customers of the estimated
cost savings resulting from the transactions contemplated by the Merger
Agreement, net of the costs incurred to achieve such savings, will be
subject to regulatory review and approval. Cost savings resulting from
the proposed merger are estimated to be approximately $2 billion over a
10-year period, net of transaction costs (including fees for financial
advisors, attorneys, accountants, consultants, filings and printing) and
costs to achieve the savings of approximately $30 million and $122
million, respectively. None of these estimated cost savings, the costs to
achieve such savings, or transaction costs have been reflected in the
unaudited pro forma combined condensed financial statements.
* In connection with the Merger Agreement, WE will be renamed Wisconsin Energy
Company.
- 94 -
95
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the Registrant has duly caused this report to be signed
on its behalf by the undersigned, thereunto duly authorized.
WISCONSIN ELECTRIC POWER COMPANY
/s/R. A. Abdoo
By -------------------------------------
Date March 28, 1996 (R. A. Abdoo, Chairman of the Board
and Chief Executive Officer)
Pursuant to the requirements of the Securities Exchange Act of 1934,
this report has been signed below by the following persons on behalf of the
Registrant and in the capacities and on the dates indicated.
Signature and Title Date
/s/R. A. Abdoo
- --------------------------------------------------- March 28, 1996
(R. A. Abdoo, Chairman of the Board and
Chief Executive Officer and Director
- Principal Executive Officer)
/s/R. R. Grigg, Jr.
- --------------------------------------------------- March 28, 1996
(R. R. Grigg, Jr., President and Chief Operating
Officer and Director)
/s/D. K. Porter
- --------------------------------------------------- March 28, 1996
(D. K. Porter, Senior Vice President
and Director)
/s/C. H. Baker
- --------------------------------------------------- March 28, 1996
(C. H. Baker, Vice President and Chief Financial
Officer)
/s/A. K. Klisurich
- --------------------------------------------------- March 28, 1996
(A. K. Klisurich, Controller
- Principal Accounting Officer)
- 95 -
96
Signature and Title Date
/s/J. F. Ahearne
- ---------------------------------------------------- March 28, 1996
(J. F. Ahearne, Director)
/s/J. F. Bergstrom
- ---------------------------------------------------- March 28, 1996
(J. F. Bergstrom, Director)
/s/R. A. Cornog
- ---------------------------------------------------- March 28, 1996
(R. A. Cornog, Director)
/s/G. B. Johnson
- ---------------------------------------------------- March 28, 1996
(G. B. Johnson, Director)
/s/F. P. Stratton
- ---------------------------------------------------- March 28, 1996
(F. P. Stratton, Jr., Director)
/s/J. G. Udell
- ---------------------------------------------------- March 28, 1996
(J. G. Udell, Director)
- 96 -
97
Wisconsin Electric Power Company
EXHIBIT INDEX
-------------
1995 Annual Report on Form 10-K
For the Year Ended December 31, 1995
Exhibit
Number
- -------
The following Exhibits are filed with this report:
(3)-1 Bylaws of Wisconsin Electric Power Company ("WE"), as amended and
restated January 31, 1996.
(4)-1 Indenture for Debt Securities (the "Indenture") dated as of December 1,
1995.
(4)-2 Securities Resolution No. 1 under the Indenture dated December 5, 1995.
(23)-1 Price Waterhouse LLP - Milwaukee, WI Consent of Independent Accountants
appearing on page 87 of this Annual Report on Form 10-K for the year
ended December 31, 1995.
(23)-2 Consent of Price Waterhouse LLP - Minneapolis, MN, Northern States
Power Company - Wisconsin's ("NSP-WI") Independent Accountants.
(23)-3 Consent of Deloitte & Touche LLP - Minneapolis, MN, NSP-WI's
Independent Auditors prior to 1995.
(27)-1 WE Financial Data Schedule for the fiscal year ended December 31, 1995.
In addition to those Exhibits shown above, which are filed herewith, WE hereby
incorporates the following Exhibits pursuant to Exchange Act Rule 12b-32 and
Regulation Section 201.24 by reference to the filings set forth below:
(2)-1 Amended and Restated Agreement and Plan of Merger, dated as of
April 28, 1995, as amended and restated as of July 26, 1995, by and
among Northern States Power Company ("NSP"), Wisconsin Energy
Corporation ("WEC"), Northern Power Wisconsin Corp. ("New NSP") and
WEC Sub Corp. (Exhibit (2)-1 to WEC's Registration Statement on
Form S-4 filed on August 7, 1995, Registration No. 33-61619
("Form S-4, No. 33-61619"); other related documents are also filed as
exhibits to such Registration Statement.)
(2)-2 WEC Stock Option Agreement, dated as of April 28, 1995, by and among
NSP and WEC. (Exhibit (2)-2 to Form S-4, No. 33-61619.)
(2)-3 NSP Stock Option Agreement, dated as of April 28, 1995, by and among
WEC and NSP. (Exhibit (2)-3 to Form S-4, No. 33-61619.)
(2)-4 Committees of the Board of Directors of Primergy Corporation
("Primergy"). (Exhibit (2)-4 to Form S-4, No. 33-61619.)
(2)-5 Form of Employment Agreement between Primergy and James J. Howard.
(Exhibit (2)-5 to Form S-4, No. 33-61619.)
- 97 -
98
Exhibit
Number
- -------
(2)-6 Form of Employment Agreement between Primergy and Richard A. Abdoo.
(Exhibit (2)-6 to Form S-4, No. 33-61619.)
(2)-7 Form of Amended and Restated Articles of Incorporation of New NSP.
(Exhibit 3-3 (b) to Form S-4, No. 33-61619.)
(2)-8 Letter Agreement, dated January 17, 1995, between NSP and WEC.
(Exhibit (2)-8 to WEC's Schedule 13D dated May 4, 1995 with respect
to the NSP Stock Option Agreement.)
(2)-9 Letter Agreement, dated April 26, 1995, between NSP and WEC amending
Letter Agreement dated January 17, 1995. (Exhibit (2)-9 to WEC's
Schedule 13D dated May 4, 1995 with respect to the NSP Stock Option
Agreement.)
(2)-10 Plan and Agreement of Merger, dated June 30, 1994, by and between WE
and Wisconsin Natural Gas Company ("WN"). (Appendix A to WE's Proxy
Statement dated October 31, 1994, in File No. 1-1245.)
(3)-2 Restated Articles of Incorporation of WE, as amended and restated
effective January 10, 1995. (Exhibit (3)-1 to WE's Annual Report on
Form 10-K for the year ended December 31, 1994, File No. 1-1245.)
(4)-3 Reference is made to Article III of the Restated Articles of
Incorporation of WE. (Exhibit (3)-2 herein.)
Mortgage, Indenture,
Supplemental Indenture
or Securities
Resolution Company Date Exhibit # Under File No.
- ------------------------------------------------------------------------------
(4)- 4 Mortgage and Wisconsin 10/28/38 B-1 2-4340
Deed of Trust Electric
("WE")
5 Second WE 6/1/46 7-C 2-6422
6 Third WE 3/1/49 7-C 2-8456
7 Fourth WE 6/1/50 7-D 2-8456
8 Fifth WE 5/1/52 4-G 2-9588
9 Sixth WE 5/1/54 4-H 2-10846
10 Seventh WE 4/15/56 4-I 2-12400
11 Eighth WE 4/1/58 2-I 2-13937
12 Ninth WE 11/15/60 2-J 2-17087
13 Tenth WE 11/1/66 2-K 2-25593
14 Eleventh WE 11/15/67 2-L 2-27504
15 Twelfth WE 5/15/68 2-M 2-28799
16 Thirteenth WE 5/15/69 2-N 2-32629
17 Fourteenth WE 11/1/69 2-O 2-34942
18 Fifteenth WE 7/15/76 2-P 2-54211
19 Sixteenth WE 1/1/78 2-Q 2-61220
20 Seventeenth WE 5/1/78 2-R 2-61220
21 Eighteenth WE 5/15/78 2-S 2-61220
- 98 -
99
Mortgage, Indenture,
Supplemental Indenture
or Securities
Resolution Company Date Exhibit # Under File No.
- ------------------------------------------------------------------------------
22 Nineteenth WE 8/1/79 (a)2(a) 1-1245 (9/30/79
WE Form 10-Q)
23 Twentieth WE 11/15/79 (a)2(a) 1-1245 (12/31/79
WE Form 10-K)
24 Twenty-First WE 4/15/80 (4)-21 2-69488
25 Twenty-Second WE 12/1/80 (4)-1 1-1245 (12/31/80
WE Form 10-K)
26 Twenty-Third WE 9/15/85 (4)-1 1-1245 (9/30/85
WE Form 10-Q)
27 Twenty-Four WE 9/15/85 (4)-1 1-1245 (9/30/85
WE Form 10-Q)
28 Twenty-Fifth WE 12/15/86 (4)-25 1-1245 (12/31/86
WE Form 10-K)
29 Twenty-Sixth WE 1/15/88 4 1-1245 (1/26/88
Form 8-K)
30 Twenty-Seventh WE 4/15/88 4 1-1245 (3/31/88
Form 10-Q)
31 Twenty-Eighth WE 9/1/89 4 1-1245 (9/30/89
WE Form 10-Q)
32 Twenty-Ninth WE 10/1/91 4-1 1-1245 (12/31/91
WE Form 10-K)
33 Thirtieth WE 12/1/91 4-2 1-1245 (12/31/91
WE Form 10-K)
34 Thirty-First WE 8/1/92 4-1 1-1245 (6/30/92
WE Form 10-Q)
35 Thirty-Second WE 8/1/92 4-2 1-1245 (6/30/92
WE Form 10-Q)
36 Thirty-Third WE 10/1/92 4-1 1-1245 (9/30/92
WE Form 10-Q)
37 Thirty-Fourth WE 11/1/92 4-2 1-1245 (9/30/92
WE Form 10-Q)
38 Thirty-Fifth WE 12/15/92 4-1 1-1245 (12/31/92
WE Form 10-K)
39 Thirty-Sixth WE 1/15/93 4-2 1-1245 (12/31/92
WE Form 10-K)
40 Thirty-Seventh WE 3/15/93 4-3 1-1245 (12/31/92
WE Form 10-K)
41 Thirty-Eighth WE 8/01/93 (4)-1 1-1245 (6/30/93
WE Form 10-Q)
42 Thirty-Ninth WE 9/15/93 (4)-1 1-1245 (9/30/93
WE Form 10-Q)
43 Fortieth WE 1/01/96 (4)-1 1-1245 (1/1/96
WE Form 8-K)
All agreements and instruments with respect to long-term debt not
exceeding 10 percent of the total assets of the Registrant and its
subsidiaries on a consolidated basis have been omitted as permitted
by related instructions. The Registrant agrees pursuant to Item
601(b)(4) of Regulation S-K to furnish to the Securities and Exchange
Commission, upon request, a copy of all such agreements and
instruments.
- 99 -
100
Exhibit
Number
- -------
(10)-1 Amended Non-Qualified Trust Agreement by and between WEC and Firstar
Trust Company dated January 26, 1996, regarding trust established to
provide a source of funds to assist in meeting of the liabilities under
various nonqualified deferred compensation plans made between WEC or
its subsidiaries and various plan participants. (Exhibit (10)-2 to
WEC's Annual Report on Form 10-K for the year ended December 31, 1995,
File No. 1-9057.) *
(10)-2 Supplemental Benefits Agreement between WEC and Richard A. Abdoo dated
November 21, 1994, and April 26, 1995 letter agreement.
(Exhibit (10)-1 to WEC's Quarterly Report on Form 10-Q for the quarter
ended June 30, 1995, File No. 1-9057. ("WEC's 6/30/95 10-Q")) *
(10)-3 WEC Senior Executive Severance Policy, as adopted effective
April 28, 1995 and amended on July 26, 1995. (Exhibit (10)-3 to
WEC's 6/30/95 10-Q.) *
(10)-4 Service Agreement dated January 1, 1987, between WE, WEC and other
non-utility affiliated companies. (Exhibit (10)-(a) to WE's Current
Report on Form 8-K dated January 2, 1987 in File No. 1-1245.)
(99)-1 Wisconsin Energy Company unaudited pro forma combined condensed
statements of income for each of the three years in the period ended
December 31, 1994. (Included in WE's Current Report on Form 8-K dated
as of August 25, 1995, File No. 1-1245.)
(99)-2 Audited Financial Statements of NSP-WI. (Item 8 of NSP-WI's Annual
Report on Form 10-K for the fiscal year ended December 31, 1995, File
No. 10-3140):
Report of Independent Accountants.
Independent Auditor's Report for years prior to 1995.
Statements of Income and Retained Earnings for the three years ended
December 31, 1995.
Statements of Cash Flows for the three years ended December 31, 1995.
Balance Sheets at December 31, 1995 and 1994.
Notes to Financial Statements.
- ---------------------------
* Management contracts and executive compensation plans or arrangements
required to be filed as exhibits pursuant to Item 14(c) of Form 10-K.
Certain compensatory plans in which directors or executive officers of
the Registrant are eligible to participate are not filed in reliance
on the exclusion in Item 601(b)(10)(iii)(B)(6) of Regulation S-K.
- 100 -