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UNITED STATES
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, 1999
or
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the transition period from ______ to _______
Commission Name of Registrant, State of Incorporation, IRS Employer
File Address of Principal Executive Offices and Identification
Number Telephone Number Number
- ---------- -------------------------------------------- ------------------
1-9894 ALLIANT ENERGY CORPORATION 39-1380265
(a Wisconsin corporation)
222 West Washington Avenue
Madison, Wisconsin 53703
Telephone (608)252-3311
0-4117-1 IES UTILITIES INC. 42-0331370
(an Iowa corporation)
Alliant Energy Tower
Cedar Rapids, Iowa 52401
Telephone (319)398-4411
0-337 WISCONSIN POWER AND LIGHT COMPANY 39-0714890
(a Wisconsin corporation)
222 West Washington Avenue
Madison, Wisconsin 53703
Telephone (608)252-3311
Securities registered pursuant to Section 12 (b) of the Act:
Name of Each
Exchange on Which
Title of Class Registered
---------------------------- -----------------------
Alliant Energy Common Stock, $.01 Par Value New York Stock Exchange
Corporation
Alliant Energy Common Stock Purchase Rights New York Stock Exchange
Corporation
IES Utilities Inc. 7-7/8% Quarterly Debt New York Stock Exchange
Capital Securities
(Subordinated Deferrable
Interest Debentures)
Wisconsin Power and 4.50% Preferred Stock, No American Stock Exchange
Light Company Par Value
Securities registered pursuant to Section 12 (g) of the Act:
Title of Class
--------------
IES Utilities Inc. 4.80% Cumulative Preferred Stock, Par Value $50 per share
Wisconsin Power and Preferred Stock (Accumulation without Par Value)
Light Company
Indicate by check mark whether the registrants (1) have 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) have 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 the registrants' knowledge, in definitive proxy
or information statements incorporated by reference in Part III of the
Form 10-K or any amendment to this Form 10-K. [ ]
This combined Form 10-K is separately filed by Alliant Energy
Corporation, IES Utilities Inc. and Wisconsin Power and Light Company.
Information contained in the annual report relating to Wisconsin Power
and Light Company and IES Utilities Inc. is filed by such registrant on
its own behalf. Each of Wisconsin Power and Light Company and IES
Utilities Inc. makes no representation as to information relating to
registrants other than itself.
The aggregate market value of the voting and non-voting common equity
held by nonaffiliates as of January 31, 2000:
Alliant Energy Corporation $2.34 billion
IES Utilities Inc. $--
Wisconsin Power and Light Company $--
Number of shares outstanding of each class of common stock as of January
31, 2000:
Alliant Energy Common Stock, $.01 par value, 79,000,744
Corporation shares outstanding
IES Utilities Inc. Common Stock, $2.50 par value, 13,370,788
shares outstanding (all of which are owned
beneficially and of record by Alliant Energy
Corporation)
Wisconsin Power and Common Stock, $5 par value, 13,236,601 shares
Light Company outstanding (all of which are owned
beneficially and of record by Alliant Energy
Corporation)
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the Proxy Statements relating to Alliant Energy Corporation's
2000 Annual Meeting of Shareowners and Wisconsin Power and Light
Company's 2000 Annual Meeting of Shareowners are, or will upon filing with
the Securities and Exchange Commission, be incorporated by reference into
Part III hereof.
2
TABLE OF CONTENTS
Page
Number
------
Part I
Item 1. Business 6
Item 2. Properties 20
Item 3. Legal Proceedings 23
Item 4. Submission of Matters to a Vote of Security Holders 23
Part II
Item 5. Market for Registrants' Common Equity and
Related Stockholder Matters 24
Item 6. Selected Financial Data 25
Item 7. Management's Discussion and Analysis of
Financial Condition and Results of Operations 27
Item 7A. Quantitative and Qualitative Disclosures
About Market Risk 56
Item 8. Financial Statements and Supplementary Data 56
Item 9. Changes in and Disagreements With Accountants
on Accounting and Financial Disclosure 116
Part III
Item 10. Directors and Executive Officers of the Registrants 116
Item 11. Executive Compensation 120
Item 12. Security Ownership of Certain Beneficial
Owners and Management 120
Item 13. Certain Relationships and Related Transactions 120
Part IV
Item 14. Exhibits, Financial Statement Schedules
and Reports on Form 8-K 121
Signatures 130
3
DEFINITIONS
Certain abbreviations or acronyms used in the text and notes of this
report are defined below:
Abbreviation or Acronym Definition
- ----------------------- --------------------------------------------
ADEQ Arkansas Department of Environmental Quality
AFUDC Allowance for Funds Used During Construction
Alliant Energy Alliant Energy Corporation
ANR ANR Pipeline
APB Accounting Principles Board Opinion
ATC American Transmission Company, LLC
Btu British Thermal Unit
Capital Square Capital Square Financial Corporation
Cargill Cargill Incorporated
CEMS Continuous Emission Monitoring System
CIPCO Central Iowa Power Cooperative
Corporate Services Alliant Energy Corporate Services, Inc.
CWIP Construction Work-In-Progress
DAEC Duane Arnold Energy Center
DOE United States Department of Energy
Dth Dekatherm
EAC Energy Adjustment Clause
EDS Electronic Data Systems Corporation
EITF Emerging Issues Task Force
EPA United States Environmental Protection Agency
ERISA Employee Retirement Income Security Act of 1974,
as amended
FASB Financial Accounting Standards Board
FERC Federal Energy Regulatory Commission
ICC Illinois Commerce Commission
IES IES Industries Inc.
IESU IES Utilities Inc.
International Alliant Energy International, Inc.
Investments Alliant Energy Investments, Inc.
IPC Interstate Power Company
IRS Internal Revenue Service
ISCO Alliant Energy Industrial Services, Inc.
ISO Independent System Operator
IUB Iowa Utilities Board
Kewaunee Kewaunee Nuclear Power Plant
KW Kilowatt
KWH Kilowatt-Hour
LTEIP Long-Term Equity Incentive Plan
MAIN Mid-America Interconnected Network, Inc.
MAPP Mid-Continent Area Power Pool
McLeod McLeodUSA Incorporated
4
Abbreviation or Acronym Definition
- ----------------------- ------------------------------------------------
MD&A Management's Discussion and Analysis of Financial
Condition and Results of Operations
MG&E Madison Gas & Electric Company
MGP Manufactured Gas Plants
MPUC Minnesota Public Utilities Commission
MW Megawatt
MWH Megawatt-Hour
NEIL Nuclear Electric Insurance Limited
NEPA National Energy Policy Act of 1992
NERC North American Electric Reliability Council
NGPL Natural Gas Pipeline Co. of America
NMC Nuclear Management Company, LLC
NNG Northern Natural Gas Company
NOPR Notice of Proposed Rulemaking
NOx Nitrogen Oxides
NRC Nuclear Regulatory Commission
NSP Northern States Power Company
NYMEX New York Mercantile Exchange
OCA Office of Consumer Advocate
PCB Polychlorinated Biphenyl
PGA Purchased Gas Adjustment
PRP Potentially Responsible Party
PSCW Public Service Commission of Wisconsin
PUHCA Public Utility Holding Company Act of 1935
Resources Alliant Energy Resources, Inc.
RTO Regional Transmission Organization
SEC Securities and Exchange Commission
SFAS Statement of Financial Accounting Standards
SkyGen SkyGen Energy LLC
SO2 Sulfur Dioxide
South Beloit South Beloit Water, Gas and Electric Company
SOS Standard Offer Service
Transportation Alliant Energy Transportation, Inc.
U.S. United States
USEC United States Enrichment Corporation
WDNR Wisconsin Department of Natural Resources
WEPCO Wisconsin Electric Power Company
Whiting Whiting Petroleum Corporation
WP&L Wisconsin Power and Light Company
WPLH WPL Holdings, Inc.
WPSC Wisconsin Public Service Corporation
WUHCA Wisconsin Utility Holding Company Act
5
FORWARD-LOOKING STATEMENTS
Refer to the "Forward-Looking Statements" section in Item 7. MD&A for
information and disclaimers regarding forward-looking statements
contained in this Annual Report on Form 10-K.
PART I
This Annual Report on Form 10-K includes information relating to Alliant
Energy, IESU and WP&L (as well as IPC, Resources and Corporate
Services). Where appropriate, information relating to a specific entity
has been segregated and labeled as such.
ITEM 1. BUSINESS
A. GENERAL
- ----------
Alliant Energy was formed as the result of a three-way merger involving
WPLH, IES and IPC that was completed in April 1998. The primary first
tier subsidiaries of Alliant Energy include: WP&L, IESU, IPC, Resources
and Corporate Services. Among various other regulatory constraints,
Alliant Energy is operating as a registered public utility holding
company subject to the limitations imposed by PUHCA. Alliant Energy was
incorporated in Wisconsin in 1981. A brief description of the primary
first-tier subsidiaries of Alliant Energy is as follows:
1) IESU - incorporated in Iowa in 1925 as Iowa Railway and Light
Corporation. IESU is a public utility engaged principally in the
generation, transmission, distribution and sale of electric energy; the
purchase, distribution, transportation and sale of natural gas; and the
provision of steam services in selective markets, in the State of Iowa.
In Iowa, non-exclusive franchises, which cover the use of streets and
alleys for public utility facilities in incorporated communities, are
granted for a maximum of twenty-five years by a majority vote of local
qualified residents. At December 31, 1999, IESU supplied electric and
gas service to approximately 345,000 and 181,000 customers,
respectively. In 1999, 1998 and 1997, IESU had no single customer for
which electric and/or gas sales accounted for 10% or more of IESU's
consolidated revenues.
2) WP&L - incorporated in Wisconsin in 1917 as the Eastern Wisconsin
Electric Company, is a public utility engaged principally in the
generation, transmission, distribution and sale of electric energy; the
purchase, distribution, transportation and sale of natural gas; and the
provision of water services in selective markets. Nearly all of WP&L's
customers are located in south and central Wisconsin. WP&L operates in
municipalities pursuant to permits of indefinite duration which are
regulated by Wisconsin law. At December 31, 1999, WP&L supplied electric
and gas service to approximately 407,000 and 162,000 customers,
respectively. WP&L also has approximately 19,000 water customers. In
1999, 1998 and 1997, WP&L had no single customer for which electric
and/or gas sales accounted for 10% or more of WP&L's consolidated
revenues. WP&L owns all of the outstanding capital stock of South
Beloit, a public utility supplying electric, gas and water service,
principally in Winnebago County, Illinois, which was incorporated in
1908. WP&L also owns varying interests in several other subsidiaries and
investments which are not material to WP&L's operations.
3) IPC - incorporated in 1925 under the laws of the State of Delaware.
IPC is a public utility engaged principally in the generation,
transmission, distribution and sale of electric energy and the purchase,
distribution, transportation and sale of natural gas in the States of
Iowa, Minnesota and Illinois. At December 31, 1999, IPC provided
electric and gas service to approximately 167,000 and 50,000 customers,
respectively. In 1999, 1998 and 1997, IPC had no single customer for
which electric and/or gas sales accounted for 10% or more of IPC's
consolidated revenues.
6
4) RESOURCES - incorporated in 1988 in Wisconsin and the majority of
Alliant Energy's non-regulated investments are organized under
Resources. Resources' wholly-owned subsidiaries include ISCO,
International, Investments, Transportation and Capital Square. These
businesses include domestic and international energy products and
services businesses; industrial services, which includes environmental,
engineering and transportation services; investments in affordable
housing initiatives; and investments in various other strategic
initiatives. Alliant Energy also has a 50% ownership interest in a joint
venture, which is managed by Resources, with Cargill, named
Cargill-Alliant LLC.
5) CORPORATE SERVICES - subsidiary formed to provide administrative
services to Alliant Energy and its subsidiaries as required under PUHCA.
Refer to Note 14 of the "Notes to Consolidated Financial Statements" for
a further discussion of Alliant Energy's business segments.
B. INFORMATION RELATING TO ALLIANT ENERGY ON A CONSOLIDATED BASIS
- -----------------------------------------------------------------
EMPLOYEES
As of December 31, 1999, Alliant Energy had the following employees
(full-time and part-time):
Number of
Bargaining Number of
Number of Unit Bargaining
Employees Employees Agreements
----------- -------------- -----------
IESU 1,809 1,112 6
WP&L 1,586 1,473 1
IPC 612 506 3
Resources 997 85 5
Corporate Services 1,213 -- --
----------- -------------- -----------
Alliant Energy Total 6,217 3,176 15
=========== ============== ===========
Refer to the "Other Matters - Labor Issues" section in Item 7. MD&A for
additional discussion of Alliant Energy's collective bargaining
agreements.
CAPITAL EXPENDITURE AND INVESTMENT AND FINANCING PLANS
Refer to the "Liquidity and Capital Resources" section in Item 7. MD&A
for a discussion of anticipated construction and acquisition expenditures
for 2000-2004 and details regarding the financing of future capital
requirements.
REGULATION
Alliant Energy operates as a registered public utility holding company
subject to regulation by the SEC under PUHCA. Alliant Energy and its
subsidiaries are subject to the regulatory provisions of PUHCA, including
provisions relating to the issuance and sales of securities, acquisitions
and sales of certain utility properties, acquisitions and retention of
interests in non-utility businesses and the services provided by
Corporate Services to Alliant Energy and its subsidiaries.
Alliant Energy is subject to regulation by the PSCW. The PSCW regulates,
among other things, the type and amount of Alliant Energy's investments
in non-utility businesses. WP&L is also subject to regulation by the
PSCW as to retail utility rates and service, accounts, issuance and use
of proceeds of securities, certain additions and extensions to facilities
and in other respects. WP&L is generally required to file a rate case
with the PSCW every two years with requests for rate relief based on a
forward-looking test year period. However, as one of the conditions for
approval of the merger, the PSCW has required WP&L to freeze on a
post-merger basis retail electric, natural gas and water rates for a
period of four years.
7
IESU and IPC operate under the jurisdiction of the IUB. The IUB has
authority to regulate rates and standards of service, to prescribe
accounting requirements and to approve the location and construction of
electric generating facilities having a capacity in excess of 25,000 KW.
Requests for rate relief are based on historical test periods, adjusted
for certain known and measurable changes. The IUB must decide on
requests for rate relief within 10 months of the date of the application
for which relief is filed or the interim prices granted become
permanent. Interim rates, if allowed, are permitted to become effective,
subject to refund, no later than 90 days after the rate increase
application is filed. Notwithstanding this process, IESU and IPC agreed
to a four-year price cap effective with the merger as part of the merger
approval process.
IPC is also subject to regulation by the MPUC. Requests for rate relief can
be based on either historical or projected data. The MPUC must reach a final
decision within 10 months. Interim rates are permitted. The MPUC also has
jurisdiction to approve IPC's capital structure on an annual basis.
In addition, South Beloit and IPC are subject to regulation by the ICC for
retail utility rates and service, accounts, issuance and use of proceeds of
securities, certain additions and extensions to facilities and in other
respects. Requests for rate relief must be decided within 11 months.
The FERC has jurisdiction under the Federal Power Act over certain of the
electric utility facilities and operations, wholesale rates and
accounting practices of IESU, WP&L and IPC, and in certain other
respects. In addition, certain natural gas facilities and operations of
the companies are subject to the jurisdiction of the FERC under the
Natural Gas Act.
With respect to environmental matters, the EPA administers certain
federal statutes and has delegated the administration of other
environmental initiatives to the applicable state environmental
agencies. In addition, the state agencies have jurisdiction over air and
water quality standards associated with fossil fuel fired electric
generation and the level and flow of water, safety and other matters
pertaining to hydroelectric generation.
WP&L and IESU are subject to the jurisdiction of the NRC, with respect to
Kewaunee in the case of WP&L and the DAEC in the case of IESU, and to the
jurisdiction of the DOE with respect to the disposal of nuclear fuel and
other radioactive wastes from Kewaunee and the DAEC.
Refer to Item 7. MD&A for additional information regarding regulation
and Alliant Energy's rate matters.
C. INFORMATION RELATING TO UTILITY OPERATIONS
- ---------------------------------------------
Alliant Energy realized 55%, 40%, 3% and 2% of its electric utility
revenues in 1999 in Iowa, Wisconsin, Minnesota and Illinois,
respectively. Approximately 90% of the electric revenues were regulated
by the respective state commissions while the other 10% were regulated by
the FERC. Alliant Energy realized 57%, 37%, 3% and 3% of its gas utility
revenues in Iowa, Wisconsin, Minnesota and Illinois, respectively, during
the same period.
IESU realized 100% of its electric and gas utility retail revenues in
1999 in Iowa. Approximately 95% of the electric revenues in 1999 were
regulated by the IUB while the other 5% were regulated by the FERC. WP&L
realized 98% of its electric utility revenues in 1999 in Wisconsin and 2%
in Illinois. Approximately 84% of the electric revenues in 1999 were
regulated by the PSCW or the ICC while the other 16% were regulated by
the FERC. WP&L realized 96% of its gas utility revenues in 1999 in
Wisconsin and 4% in Illinois during the same period. IPC realized 75%,
19% and 6% of its electric utility revenues in 1999 in Iowa, Minnesota
and Illinois, respectively. Approximately 92% of the electric revenues
were regulated by the respective state commissions while the other 8%
were regulated by the FERC. IPC realized 69%, 23% and 8% of its gas
utility revenues in Iowa, Minnesota and Illinois, respectively, during
the same period.
UTILITY INDUSTRY OUTLOOK
Refer to the "Utility Industry Outlook" section in Item 7. MD&A for a
discussion of various competitive issues impacting utility operations.
8
ELECTRIC UTILITY OPERATIONS
General
As of December 31, 1999, Alliant Energy's utility subsidiaries provided
electricity to approximately 919,000 retail customers in approximately
1,358 communities in Iowa, southern and central Wisconsin, northern and
northwestern Illinois and southern Minnesota. The approximate number of
electric retail customers, communities and wholesale customers served for
each of the individual utilities at December 31, 1999 was as follows:
Retail Communities Wholesale
Customers Served Customers
---------- ------------ --------------
IESU 345,000 525 5
WP&L 407,000 599 28
IPC 167,000 234 10
Electric utility operations accounted for 78.4%, 83.3% and 86.0% of
operating revenues and 92.6%, 89.9% and 91.6% of operating income for
IESU, WP&L and IPC, respectively, for the year ended December 31, 1999.
Electric sales are seasonal to some extent with the annual peak normally
occurring in the summer months. In 1999, the maximum peak hour demand
for IESU was 1,990 MW and occurred on July 27, 1999. For WP&L and IPC,
the maximum peak hour demands were 2,397 MW on July 23, 1999 and 1,015 MW
on July 29, 1999, respectively.
IESU maintains and operates transmission and substation facilities
connecting with its high voltage transmission systems pursuant to a
non-cancelable operation agreement (the Operating Agreement) with CIPCO.
The Operating Agreement, which will terminate on December 31, 2035,
provides for the joint use of certain transmission facilities of IESU and
CIPCO. Alliant Energy has transmission interconnections at various
locations with twelve other transmission owning utilities in the
Midwest. These interconnections enhance the overall reliability of the
Alliant Energy transmission system and provide access to multiple sources
of economic and emergency power and energy.
IESU and IPC are currently full members of MAPP. WP&L is a member of the
MAPP Regional Transmission Group. MAPP is one of the ten regional
members of the NERC. Each regional member of NERC is responsible for
maintaining reliability in its area through coordination of planning and
operations. WP&L is also a full member of MAIN, another regional member
of NERC. IESU and IPC are currently exploring the possibility of
transitioning from the MAPP reliability region to MAIN so all of Alliant
Energy will belong to the same reliability region. Alliant Energy is
unable to predict the outcome of this issue at this time.
Refer to the "Utility Industry Outlook" section in Item 7. MD&A for
additional information regarding the future of Alliant Energy's
transmission business. Refer to Item 2. "Properties" for additional
information regarding electric facilities.
9
Fuel
The average cost of fuel per million Btu's used for electric generation
by IESU, WP&L and IPC for the years 1999, 1998 and 1997 was as follows:
Nuclear Coal All Fuels
------------- ------------- ------------
IESU - 1999 $0.581 $0.899 $0.914
- 1998 0.605 0.885 0.887
- 1997 0.650 0.958 0.945
WP&L - 1999 0.431 1.144 1.034
- 1998 0.450 1.171 1.085
- 1997 0.450 1.175 1.129
IPC - 1999 N/A 1.273 1.320
- 1998 N/A 1.287 1.344
- 1997 N/A 1.340 1.414
Refer to the Electric Operating Information tables for details on the
sources of electric energy for Alliant Energy, IESU and WP&L during 1995
to 1999.
Coal
Corporate Services, as an agent of IESU, WP&L and IPC, has negotiated
several agreements with different suppliers to ensure that a specified
supply of coal is available at known prices for the respective utilities
for calendar years 2000, 2001, and 2002. These contracts, in combination
with existing agreements, provide for a portfolio of coal supplies that
cover approximately 100%, 60% and 10% of the three utilities' estimated
coal supply needs for the years 2000 through 2002, respectively.
Management believes this portfolio of coal supplies represents a
reasonable balance between ensuring an adequate supply and ensuring that
the prices paid for coal is at the then current market conditions.
Remaining coal requirements will be met from either future contracts or
purchases in the spot market.
The majority of the coal utilized by Alliant Energy is from the Wyoming
Powder River Basin. A majority of this coal is transported by rail-car
directly from Wyoming to Alliant Energy's generating facilities, with the
remainder transported from Wyoming to the Mississippi River by rail-car
and then via barges to the final destination. As protection against
interruptions in coal deliveries, Alliant Energy maintains average coal
inventories at its generating stations of 40 to 50 days for stations with
year-round deliveries and 30 to 150 days (depending upon time of the
year) for stations with seasonal deliveries.
Alliant Energy anticipates that its average fossil fuel costs will likely
increase in the future due to price/rate adjustment provisions in
existing coal and transportation contracts. Price adjustment provisions
in existing coal contracts are primarily based on changes in various
indices (e.g. U.S. Department of Labor Statistics Producer Price Indices
and Consumer Price Indices). Other factors which impact coal price
adjustment provisions are mine labor agreements and, if enacted, changes
in various laws and regulations. Rate adjustment provisions in
transportation contracts are primarily based on changes in the Rail Cost
Adjustment Factor as published by the U.S. Surface Transportation Board.
In addition, fuel sulfur restrictions and other environmental limitations
have increased significantly and will likely further increase the
difficulty and cost of obtaining adequate coal supplies. See Note 1(j)
of the "Notes to Consolidated Financial Statements" for a discussion of
the utilities' rate recovery of fuel costs.
Refer to Note 12(b) of the "Notes to Consolidated Financial Statements"
for details relating to Alliant Energy's coal purchase commitments.
10
Purchased Power
During the year ended December 31, 1999, approximately 25.0%, 25.0% and
32.3% of IESU's, WP&L's and IPC's total MWH requirements, respectively,
were met through purchased power. Refer to Note 12(b) of the "Notes to
Consolidated Financial Statements" for details relating to purchase power
commitments.
Nuclear
General - Alliant Energy owns interests in two nuclear facilities,
- -------
Kewaunee and DAEC. Kewaunee, a 532 MW (net capacity) pressurized water
reactor plant, is operated by WPSC and is jointly owned by WPSC (41.2%),
WP&L (41.0%) and MG&E (17.8%). The Kewaunee operating license expires in
2013. DAEC, a 535 MW (net capacity) boiling water reactor plant, is
operated by IESU which has a 70% ownership interest in the plant. The
DAEC operating license expires in 2014. See Item 7. MD&A "Liquidity and
Capital Resources - Capital Requirements - Nuclear Facilities" for a
discussion of an agreement between WPSC and MG&E regarding future
ownership of Kewaunee as well as Alliant Energy's participation in the
NMC.
As co-owners of nuclear generating units, IESU and WP&L are subject to
the jurisdiction of the NRC. The NRC has broad supervisory and
regulatory jurisdiction over the construction and operation of nuclear
reactors, particularly with regard to public health, safety and
environmental considerations. The operation and design of nuclear power
plants is under constant review by the NRC. IESU and WP&L have complied
with and are currently complying with all NRC requests for data relating
to these reviews. As a result of such reviews, further changes in
operations or modifications of equipment may be required, the cost of
which cannot currently be estimated. IESU's and WP&L's anticipated
nuclear-related construction expenditures for 2000-2004 are approximately
$59 million and $35 million, respectively. Refer to "Liquidity and
Capital Resources - Capital Requirements" in Item 7. MD&A for a further
discussion.
Under the Price-Anderson Amendments Act of 1988 (1988 Act), IESU and WP&L
currently have the benefit of public liability coverage which would
compensate the public in the event of an accident at a commercial nuclear
power plant. The 1988 Act permits such coverage to rise with increased
availability of nuclear insurance and the changing number of operating
nuclear plants subject to retroactive premium assessments. The 1988 Act
provides for inflation indexing (Consumer Price Index every fifth year)
of the retroactive premium assessments.
As an outgrowth of the Three Mile Island Nuclear Power Plant experience,
nuclear plant owners have initiated a cooperative insurance program
designed to help cover business interruption expenses for participating
utilities arising from a possible nuclear plant event. IESU and WP&L are
participants in this program. This type of insurance is an industry
response intended to lessen the cost burden on customers in the event of
a lengthy plant shutdown.
In the unlikely event of a catastrophic loss at Kewaunee or DAEC, the
amount of insurance available may not be adequate to cover property
damage, decontamination and premature decommissioning. Uninsured losses,
to the extent not recovered through rates, would be borne by WP&L or IESU
and could have a material adverse effect on their financial condition and
results of operations. Refer to Note 12(e) of the "Notes to Consolidated
Financial Statements" for a further discussion of the nuclear insurance
issue.
Kewaunee - WPSC purchases uranium concentrates, conversion services,
- --------
enrichment services, and fabrication services for nuclear fuel assemblies
at Kewaunee. New fuel assemblies replace used assemblies that are
removed from the reactor every 18 months and placed in storage at the
plant site pending removal by the DOE. Uranium concentrates, conversion
services, and enrichment services are purchased at spot market prices,
through a bid process, or using existing contracts. Conversion services
are complete for nuclear fuel reloads in 2000, 2001 and 2003. A fixed
quantity of enrichment services are contracted through the year 2004.
Additional enrichment services will be acquired under a contract which is
in effect for the life of the plant or by purchases on the spot market.
Fuel fabrication services are contracted well into the next decade and
contain contractual clauses covering force majeure and termination
provisions. A uranium inventory policy requires that sufficient
inventory exist for up to two reactor reloads of fuel. As of December
31, 1999, 983,000 pounds of yellowcake or its equivalent were held in
inventory for the plant.
DAEC - A contract for enrichment services and enriched uranium product
- ----
was signed with the USEC in 1995. This contract is effective through
11
September of 2001. Fabrication of the nuclear fuel is being performed by
General Electric Company for fuel through the 2011 refueling of DAEC.
IESU believes that an ample supply of uranium and enrichment services
will be available in the future and intends to purchase such uranium and
enrichment services as necessary on the spot market and/or via medium
length (less than five years) contracts to supplement its current
contracts and meet its generation requirements.
Additional discussions of various other nuclear issues relating to
Kewaunee and DAEC are included in Item 7. MD&A and the "Notes to
Consolidated Financial Statements."
Power Supply
Refer to "Other Matters - Power Supply" in Item 7. MD&A for a discussion
of power supply concerns.
Electric Environmental Matters
Alliant Energy is regulated in environmental matters by a number of
federal, state and local agencies. Such regulations are the result of a
number of environmental laws passed by the U.S. Congress, state
legislatures and local governments and enforced by federal, state and
local agencies. The laws impacting Alliant Energy's operations include,
but are not limited to, the Clean Water Act; Safe Drinking Water Act;
Clean Air Act, as amended by the Clean Air Act Amendments of 1990;
National Environmental Policy Act; Toxic Substances Control Act;
Emergency Planning and Community Right-to-Know Act; Resource Conservation
and Recovery Act; Comprehensive Environmental Response, Compensation and
Liability Act of 1980 (CERCLA), as amended by the Superfund Amendments
and Reauthorization Act of 1986; Nuclear Waste Policy Act of 1982;
Occupational Safety and Health Act; and the National Energy Policy Act of
1992. Alliant Energy regularly obtains federal, state and local permits
to assure compliance with the environmental protection laws and
regulations. Costs associated with such compliance have increased in
recent years and are expected to increase moderately in the future.
Refer to "Other Matters - Environmental" in Item 7. MD&A and Note 12 of
the "Notes to Consolidated Financial Statements" for a further discussion
of electric environmental matters.
12
Alliant Energy Corporation
- -----------------------------------------------------------------------------------------------------------------------------------
1999 1998 1997 1996 1995
- -----------------------------------------------------------------------------------------------------------------------------------
Electric Operating Information (Utility Only)
- -----------------------------------------------------------------------------------------------------------------------------------
Operating Revenues (000s):
Residential $541,714 $532,676 $521,574 $506,784 $509,970
Commercial 329,487 317,704 307,941 296,345 290,990
Industrial 476,140 477,241 455,912 428,726 412,711
-----------------------------------------------------------------------
Total from ultimate customers 1,347,341 1,327,621 1,285,427 1,231,855 1,213,671
Sales for resale 155,801 199,128 192,346 181,365 143,726
Other 45,796 40,693 37,980 27,155 24,271
-----------------------------------------------------------------------
Total $1,548,938 $1,567,442 $1,515,753 $1,440,375 $1,381,668
=======================================================================
- ----------------------------------------------------------------------------------------------------------------------------------
Electric Sales (000s MWH):
Residential 7,024 6,826 6,851 6,826 6,860
Commercial 5,260 4,943 4,844 4,720 4,661
Industrial 13,036 12,718 12,320 11,666 11,360
-----------------------------------------------------------------------
Total from ultimate customers 25,320 24,487 24,015 23,212 22,881
Sales for resale 5,566 7,189 6,768 7,459 5,001
Other 162 158 161 161 163
----------------------------------------------------------------------
Total 31,048 31,834 30,944 30,832 28,045
=======================================================================
- -----------------------------------------------------------------------------------------------------------------------------------
Customers (End of Period):
Residential 790,669 781,127 772,100 762,665 751,998
Commercial 122,509 121,027 119,463 117,846 116,228
Industrial 2,730 2,618 2,555 2,472 2,418
Other 3,282 3,267 3,281 3,207 2,749
-----------------------------------------------------------------------
Total 919,190 908,039 897,399 886,190 873,393
=======================================================================
- -----------------------------------------------------------------------------------------------------------------------------------
Other Selected Electric Data:
Maximum peak hour demand (MW) (1) 5,233 5,228 5,045 4,953 5,032
Sources of electric energy (000s MWH):
Coal and gas 19,078 19,119 17,423 17,014 17,606
Purchased power 8,619 10,033 10,660 10,895 7,416
Nuclear 4,362 4,201 3,874 4,054 4,166
Other 528 504 565 392 349
-----------------------------------------------------------------------
Total 32,587 33,857 32,522 32,355 29,537
=======================================================================
Revenue per KWH from ultimate customers (in cents) 5.32 5.42 5.35 5.31 5.30
- -----------------------------------------------------------------------------------------------------------------------------------
(1) 1999 data represents the coincident peak of the entire Alliant Energy system. 1998 to 1995 data represents a summation
of the individual peak demands of IESU, WP&L and IPC thus they do not represent the coincident peak of the entire
Alliant Energy system.
13
IES Utilities Inc.
- -----------------------------------------------------------------------------------------------------------------------------------
1999 1998 1997 1996 1995
- -----------------------------------------------------------------------------------------------------------------------------------
Electric Operating Information
- -----------------------------------------------------------------------------------------------------------------------------------
Operating Revenues (000s):
Residential $230,422 $232,662 $227,496 $213,838 $217,351
Commercial 176,251 168,672 162,626 153,163 150,722
Industrial 181,740 181,369 177,890 160,477 148,529
-----------------------------------------------------------------------
Total from ultimate customers 588,413 582,703 568,012 527,478 516,602
Sales for resale 28,479 45,453 25,719 37,384 35,356
Other 11,058 11,267 10,539 9,411 8,513
-----------------------------------------------------------------------
Total $627,950 $639,423 $604,270 $574,273 $560,471
=======================================================================
- -----------------------------------------------------------------------------------------------------------------------------------
Electric Sales (000s MWH):
Residential 2,685 2,661 2,682 2,642 2,690
Commercial 2,658 2,465 2,378 2,315 2,296
Industrial 5,072 4,872 4,743 4,436 4,248
-----------------------------------------------------------------------
Total from ultimate customers 10,415 9,998 9,803 9,393 9,234
Sales for resale 1,392 1,763 794 1,746 1,586
Other 40 42 43 46 50
-----------------------------------------------------------------------
Total 11,847 11,803 10,640 11,185 10,870
=======================================================================
- -----------------------------------------------------------------------------------------------------------------------------------
Customers (End of Period):
Residential 293,433 290,348 288,387 286,315 284,154
Commercial 49,952 49,489 48,962 48,593 48,196
Industrial 715 705 711 703 695
Other 449 479 442 437 444
-----------------------------------------------------------------------
Total 344,549 341,021 338,502 336,048 333,489
=======================================================================
- -----------------------------------------------------------------------------------------------------------------------------------
Other Selected Electric Data:
Maximum peak hour demand (MW) 1,990 1,965 1,854 1,833 1,824
Sources of electric energy (000s MWH):
Coal and gas 6,543 6,417 5,499 4,936 5,759
Purchased power 3,104 3,385 2,789 4,177 3,013
Nuclear 2,548 2,682 2,904 2,753 2,611
Other 226 199 164 44 24
-----------------------------------------------------------------------
Total 12,421 12,683 11,356 11,910 11,407
=======================================================================
Revenue per KWH from ultimate customers (in cents) 5.65 5.83 5.79 5.62 5.59
- -----------------------------------------------------------------------------------------------------------------------------------
14
Wisconsin Power and Light Company
- ------------------------------------------------------------------------------------------------------------------------------------
1999 1998 1997 1996 1995
- ------------------------------------------------------------------------------------------------------------------------------------
Electric Operating Information
- ------------------------------------------------------------------------------------------------------------------------------------
Operating Revenues (000s):
Residential $213,496 $198,770 $199,633 $201,690 $199,850
Commercial 116,947 108,724 107,132 105,319 102,129
Industrial 171,118 162,771 152,073 143,734 140,562
------------------------------------------------------------------------
Total from ultimate customers 501,561 470,265 458,838 450,743 442,541
Sales for resale 102,751 128,536 160,917 131,836 97,350
Other 22,295 15,903 14,388 6,903 6,433
------------------------------------------------------------------------
Total $626,607 $614,704 $634,143 $589,482 $546,324
========================================================================
- ------------------------------------------------------------------------------------------------------------------------------------
Electric Sales (000s MWH):
Residential 3,111 2,964 2,974 2,980 2,938
Commercial 1,980 1,898 1,878 1,814 1,773
Industrial 4,570 4,493 4,256 3,986 3,873
------------------------------------------------------------------------
Total from ultimate customers 9,661 9,355 9,108 8,780 8,584
Sales for resale 3,252 4,492 5,824 5,246 3,109
Other 54 59 60 57 54
------------------------------------------------------------------------
Total 12,967 13,906 14,992 14,083 11,747
========================================================================
- ------------------------------------------------------------------------------------------------------------------------------------
Customers (End of Period):
Residential 355,691 350,334 343,637 336,933 329,643
Commercial 48,696 47,857 46,823 45,669 44,730
Industrial 947 909 855 815 795
Other 1,893 1,860 1,875 1,820 1,342
------------------------------------------------------------------------
Total 407,227 400,960 393,190 385,237 376,510
========================================================================
- ------------------------------------------------------------------------------------------------------------------------------------
Other Selected Electric Data:
Maximum peak hour demand (MW) 2,397 2,292 2,253 2,124 2,197
Sources of electric energy (000s MWH):
Coal and gas 8,186 8,916 8,587 8,687 8,323
Purchased power 3,436 3,923 5,744 4,494 2,227
Nuclear 1,814 1,519 970 1,301 1,555
Other 288 288 355 303 308
------------------------------------------------------------------------
Total 13,724 14,646 15,656 14,785 12,413
========================================================================
Revenue per KWH from ultimate customers (in cents) 5.19 5.03 5.04 5.13 5.16
- ------------------------------------------------------------------------------------------------------------------------------------
15
GAS UTILITY OPERATIONS
As of December 31, 1999, Alliant Energy's utility subsidiaries provided
retail natural gas service to approximately 393,000 customers in
approximately 488 communities in Iowa, southern and central Wisconsin,
northern and northwestern Illinois and southern Minnesota. The
approximate number of customers and communities served for each of the
individual utilities at December 31, 1999 was as follows:
Gas Customers Communities Served
---------------- ----------------------
IESU 181,000 212
WP&L 162,000 235
IPC 50,000 41
Gas utility operations accounted for 18.2%, 16.0% and 14.0% of operating
revenues and 5.2%, 8.9% and 8.4% of operating income for IESU, WP&L and
IPC, respectively, for the year ended December 31, 1999. These
operations include providing gas services to transportation and retail
customers.
In providing gas commodity service to retail customers, Alliant Energy
administers a diversified portfolio of transportation and storage
contracts on behalf of each of the three utilities. Transportation
contracts with NNG, NGPL and ANR allow access to gas supplies located in
the U.S. and Canada. Non-traditional arrangements provide IESU and WP&L
with gas delivered directly to their service territories. The maximum
daily delivery capacity of the individual utilities for the year ended
December 31, 1999 was as follows:
NNG NGPL ANR Non-Traditional Total
--------------- -------------- --------------- ----------------- ---------------
IESU 143,996 Dth 62,619 Dth 61,737 Dth 11,500 Dth 279,852 Dth
WP&L 75,056 Dth -- 132,124 Dth 46,400 Dth 253,580 Dth
IPC 52,595 Dth 29,750 Dth -- -- 82,345 Dth
IESU, WP&L and IPC maintain purchase agreements with over 50 suppliers of
natural gas from all gas producing regions of the U.S. and Canada.
Approximately half of the gas supply contracts are for terms of six
months or less, with the remaining supply contracts having
terms up to two years. The utilities' gas supply commitments are
index-based.
In addition to sales of natural gas to retail customers, IESU, WP&L and
IPC provide transportation service to commercial and industrial customers
by moving customer-owned gas through Alliant Energy's distribution system
to the customers' meter. Revenues are collected for this service
pursuant to transportation tariffs.
The gas sales of the utility subsidiaries follow a seasonal pattern.
There is an annual base load of gas used for cooking, heating and other
purposes, with a large heating peak occurring during the winter season.
Producers, marketers and brokers, as well as storage contracts, supply
natural gas to meet the peak heating season requirements. Storage
contracts allow the utilities to purchase gas in the summer, store the
gas in underground storage fields and deliver it in the winter. Gas
storage met approximately 19%, 26% and 25% of IESU's, WP&L's and IPC's
annual gas requirements in 1999, respectively.
Refer to Note 1(j) of the "Notes to Consolidated Financial Statements"
for a discussion of Alliant Energy's rate recovery mechanisms for its
natural gas costs and Note 12(b) of the "Notes to Consolidated Financial
Statements" for a discussion of Alliant Energy's gas commitments.
Gas Environmental Matters
Refer to Note 12(f) of the "Notes to Consolidated Financial Statements"
for a discussion of gas environmental matters.
16
Alliant Energy Corporation
- ------------------------------------------------------------------------------------------------------------------------------------
1999 1998 1997 1996 1995
- ------------------------------------------------------------------------------------------------------------------------------------
Gas Operating Information (Utility Only)
- ------------------------------------------------------------------------------------------------------------------------------------
Operating Revenues (000s):
Residential $185,090 $175,603 $225,542 $216,268 $179,761
Commercial 89,118 85,842 115,858 108,187 87,951
Industrial 21,855 20,204 27,393 27,569 30,462
Transportation/other 18,256 13,941 25,114 23,931 21,952
-------------------------------------------------------------------
Total $314,319 $295,590 $393,907 $375,955 $320,126
===================================================================
- ------------------------------------------------------------------------------------------------------------------------------------
Gas Sales (000s Dekatherms):
Residential 30,309 28,378 33,894 37,165 33,827
Commercial 18,349 17,760 21,142 22,613 20,599
Industrial 5,963 5,507 6,217 6,856 6,381
Transportation/other 46,954 52,389 56,719 55,240 54,267
-------------------------------------------------------------------
Total 101,575 104,034 117,972 121,874 115,074
===================================================================
- ------------------------------------------------------------------------------------------------------------------------------------
Customers at End of Period (Excluding Transportation/Other):
Residential 347,533 342,586 337,956 331,919 326,005
Commercial 44,289 43,825 43,316 42,658 42,095
Industrial 1,037 982 963 1,022 1,059
-------------------------------------------------------------------
Total 392,859 387,393 382,235 375,599 369,159
===================================================================
- ------------------------------------------------------------------------------------------------------------------------------------
Other Selected Gas Data:
Revenue per dekatherm sold
(excluding transportation/other) $5.42 $5.45 $6.02 $5.28 $4.90
Purchased gas costs per dekatherm sold
(excluding transportation/other) $3.30 $3.22 $4.23 $3.61 $3.31
- ------------------------------------------------------------------------------------------------------------------------------------
17
IES Utilities Inc.
- ------------------------------------------------------------------------------------------------------------------------------------
1999 1998 1997 1996 1995
- ------------------------------------------------------------------------------------------------------------------------------------
Gas Operating Information
- ------------------------------------------------------------------------------------------------------------------------------------
Operating Revenues (000s):
Residential $88,302 $86,821 $110,663 $97,708 $84,562
Commercial 40,459 39,928 54,383 46,966 40,390
Industrial 11,543 10,422 13,961 12,256 8,790
Transportation/other 5,521 4,108 4,510 3,934 3,550
-------------------------------------------------------------------
Total $145,825 $141,279 $183,517 $160,864 $137,292
===================================================================
- ------------------------------------------------------------------------------------------------------------------------------------
Gas Sales (000s Dekatherms):
Residential 13,778 13,803 16,317 17,680 16,302
Commercial 8,077 8,272 9,602 10,323 9,534
Industrial 3,291 3,089 3,318 3,796 3,098
Transportation/other 10,236 11,316 10,321 10,341 10,871
-------------------------------------------------------------------
Total 35,382 36,480 39,558 42,140 39,805
===================================================================
- ------------------------------------------------------------------------------------------------------------------------------------
Customers at End of Period (Excluding Transportation/Other):
Residential 158,705 157,135 155,859 154,457 152,873
Commercial 21,661 21,530 21,431 21,364 21,193
Industrial 383 398 399 417 404
-------------------------------------------------------------------
Total 180,749 179,063 177,689 176,238 174,470
===================================================================
- ------------------------------------------------------------------------------------------------------------------------------------
Other Selected Gas Data:
Revenue per dekatherm sold
(excluding transportation/other) $5.58 $5.45 $6.12 $4.94 $4.62
Purchased gas cost per dekatherm sold
(excluding transportation/other) $3.51 $3.36 $4.33 $3.27 $3.15
- ------------------------------------------------------------------------------------------------------------------------------------
Wisconsin Power and Light Company
- ------------------------------------------------------------------------------------------------------------------------------------
1999 1998 1997 1996 1995
- ------------------------------------------------------------------------------------------------------------------------------------
Gas Operating Information
- ------------------------------------------------------------------------------------------------------------------------------------
Operating Revenues (000s):
Residential $69,662 $65,173 $84,513 $90,382 $70,382
Commercial 35,570 33,898 45,456 46,703 35,411
Industrial 6,077 5,896 8,378 11,410 17,984
Transportation/other 9,461 6,770 17,536 17,132 15,388
-------------------------------------------------------------------
Total $120,770 $111,737 $155,883 $165,627 $139,165
===================================================================
- ------------------------------------------------------------------------------------------------------------------------------------
Gas Sales (000s Dekatherms):
Residential 12,070 10,936 12,770 14,297 12,690
Commercial 7,771 7,285 8,592 9,167 8,245
Industrial 1,520 1,422 1,714 1,997 2,144
Transportation/other 13,237 12,948 17,595 18,567 16,870
-------------------------------------------------------------------
Total 34,598 32,591 40,671 44,028 39,949
===================================================================
- ------------------------------------------------------------------------------------------------------------------------------------
Customers at End of Period (Excluding Transportation/Other):
Residential 144,015 141,065 137,827 133,580 129,576
Commercial 17,380 17,058 16,653 16,083 15,724
Industrial 576 506 488 529 566
-------------------------------------------------------------------
Total 161,971 158,629 154,968 150,192 145,866
===================================================================
- ------------------------------------------------------------------------------------------------------------------------------------
Other Selected Gas Data:
Revenue per dekatherm sold
(excluding transportation/other) $5.21 $5.34 $6.00 $5.83 $5.36
Purchased gas cost per dekatherm sold
(excluding transportation/other) $3.00 $3.13 $4.30 $4.12 $3.64
- ------------------------------------------------------------------------------------------------------------------------------------
18
D. INFORMATION RELATING TO NON-REGULATED OPERATIONS
- ---------------------------------------------------
Resources is a holding company whose wholly-owned subsidiaries at
December 31, 1999 included Investments, Transportation, Capital Square,
International and ISCO. Resources is managed through five distinct
platforms: Investments, International, Industrial Services,
Cargill-Alliant and Mass Markets.
Investments Platform - Investments is a holding company whose primary
wholly-owned subsidiaries include Heartland Properties, Inc. (HPI), Iowa
Land and Building Company (Iowa Land) and Village Lakeshares Inc.
(Lakeshares). HPI is responsible for performing asset management and
facilitating the development and financing of high quality, affordable
housing in Alliant Energy's utility service territory. HPI has a
majority ownership interest in approximately 60 such properties. Capital
Square provides mortgage-banking services to facilitate HPI's development
and financing efforts in the affordable housing market. Iowa Land is
organized to pursue real estate and economic development activities in
IESU's service territory. Lakeshares is a holding company for resort
properties in Iowa. Investments also has direct and indirect equity
interests in various real estate ventures, primarily concentrated in
Cedar Rapids, and holds other passive investments including an equity
interest in McLeod. Refer to Note 10 of the "Notes to Consolidated
Financial Statements" for a further discussion of the McLeod investment.
Whiting is organized to purchase, develop and produce crude oil and
natural gas. (Although Whiting is a wholly-owned subsidiary of ISCO,
Whiting is identified under the Investments platform for management
purposes.) Transportation is a holding company whose wholly-owned
subsidiaries include the Cedar Rapids and Iowa City Railway Company
(CRANDIC), Williams Bulk Transfer Inc. (Williams) and Transfer Services,
Inc. (Transfer). CRANDIC is a short-line railway that renders freight
service between Cedar Rapids and Iowa City. Williams' and Transfer's
operations include transloading and storage services. Transportation
also has a 75% equity investment in IEI Barge Services, Inc. (Barge)
which provides barge terminal and hauling service on the Mississippi
River.
International Platform - International is a holding company for
Resources' international investments whose wholly-owned subsidiaries
include Alliant International New Zealand Limited (New Zealand), Alliant
Energy Australia Pty Ltd. (Australia), Grandelight Holding Ltd.
(Grandelight), Interstate Energy Corporation Pte Ltd. (IECP), Alliant
Energy Renewable Resources Ltd. (AERR), Alliant Energy Brazil, Inc.
(Brazil) and Alliant Energy de Mexico L.L.C. (Mexico). New Zealand has
equity investments in several New Zealand utility entities. Australia
has an equity investment in a holding company whose primary investments
are infrastructure and utility companies in Australia. Grandelight has a
67% equity investment in Peak Pacific Investment Company Ltd. (Peak
Pacific). Peak Pacific has been formed to develop investment
opportunities in generation infrastructure projects in China. IECP has a
50% equity investment in two individual cogeneration facilities in
China. AERR has been formed for the purpose of investing in
international renewable resource projects. Mexico is organized to
provide utility-related services to a resort community in Mexico, of
which International has an investment in secured debentures. Refer to
Note 16 of the "Notes to Consolidated Financial Statements" for a
discussion of Alliant Energy's investment in Brazil completed in early
2000.
Industrial Services Platform - ISCO is a holding company for Resources'
industrial service companies whose primary wholly-owned subsidiaries
include Industrial Energy Applications, Inc. (IEA), Heartland Energy
Group, Inc. (HEG) and RMT, Inc. (RMT). IEA offers facilities-based
energy services for customers, including standby generation,
cogeneration, steam production and propane air systems. IEA also
provides energy consulting services for customers and owns natural gas
and oil gathering systems, both in Texas. HEG offers commodities-based
energy services primarily related to supplying natural gas. RMT is a
Madison, Wisconsin based environmental and engineering consulting company
that serves clients nationwide in a variety of industrial market
segments. RMT specializes in consulting on solid and hazardous waste
management, ground water quality protection, industrial design and
hygiene engineering, and air and water pollution control.
Cargill-Alliant Platform - Alliant Energy also has a 50% ownership
interest, which Resources manages, in a joint venture with Cargill, named
Cargill-Alliant, to market electricity and risk management services to
wholesale customers.
Mass Markets Platform - Mass markets is a business unit of Resources
which provides products and services designed to meet the comfort,
security and productivity needs of residential and small commercial
customers.
19
ITEM 2. PROPERTIES
WP&L
WP&L's principal electric generating stations at December 31, 1999, were
as follows:
Name and Location Primary Fuel 1999 Summer Capability
of Station Type in Kilowatts
- ------------------------------------------------------ --------------- -----------------------------------------
Kewaunee Nuclear Power Plant, Kewaunee, WI Nuclear 207,100 (1)
Nelson Dewey Generating Station, Cassville, WI Coal 226,000
Edgewater Generating Station #3, Sheboygan, WI Coal 76,000
Edgewater Generating Station #4, Sheboygan, WI Coal 237,300 (2)
Edgewater Generating Station #5, Sheboygan, WI Coal 306,000 (3)
Columbia Energy Center, Portage, WI Coal 494,400 (4)
-------------
Total Coal 1,339,700
Blackhawk Generating Station, Beloit, WI Gas 58,000
Rock River Generating Station, Beloit, WI Gas 164,000
Rock River Combustion Turbine, Beloit, WI Gas 148,000
South Fond du Lac Combustion Turbine
Units 2 and 3, Fond du Lac, WI Gas 169,000
Sheepskin Combustion Turbine, Edgerton, WI Gas 37,000
-------------
Total Gas 576,000
Kilbourn Hydro Plant, Wisconsin Dells, WI Hydro 9,000
Prairie du Sac Hydro Plant, Prairie du Sac, WI Hydro 30,000
Petenwell/Castle Rock Hydro Plants,
Wisconsin Rapids, WI Hydro 13,300 (5)
Shawano Hydro, Shawano, WI Hydro 409
-------------
Total Hydro 52,709
-------------
Total generating capability 2,175,509
=============
All KWs shown below represent the 1999 summer generating capability.
(1) Represents WP&L's 41% ownership interest in this 505,000 KW generating station, which is operated by WPSC.
(2) Represents WP&L's 68.2% ownership interest in this 348,000 KW generating station, which is operated by WP&L.
(3) Represents WP&L's 75% ownership interest in this 408,000 KW generating station, which is operated by WP&L.
(4) Represents WP&L's 46.2% ownership interest in this 1,070,000 KW generating station, which is operated by WP&L.
(5) Represents WP&L's 33.3% ownership interest in this 40,000 KW hydro plant, which is operated by Wisconsin River
Power Company.
WP&L owns 2,787 miles of electric transmission lines and 279 substations located
adjacent to the communities served, of which substantially all are in Wisconsin.
Substantially all of WP&L's facilities are subject to the lien of its First
Mortgage Bond indenture and are suitable for their intended use.
20
IESU
IESU's principal electric generating stations at December 31, 1999, were
as follows:
Name and Location Primary Fuel 1999 Summer Capability
of Station Type in Kilowatts
- -------------------------------------------------- ---- --------------- ----------------------------------------
Duane Arnold Energy Center, Palo, Iowa Nuclear 364,000 (1)
Ottumwa Generating Station, Ottumwa, Iowa Coal 324,000 (2)
Prairie Creek Station, Cedar Rapids, Iowa Coal 214,750
Sutherland Station, Marshalltown, Iowa Coal 143,000
Sixth Street Station, Cedar Rapids, Iowa Coal 65,000
Burlington Generating Station, Burlington, Iowa Coal 211,800
George Neal Unit 3, Sioux City, Iowa Coal 144,200 (3)
-------------
Total Coal 1,102,750
Peaking Turbines, Marshalltown, Iowa Oil 216,400
Centerville Combustion Turbines, Centerville, Iowa Oil 62,000
Diesel Stations, all in Iowa Oil 8,300
-------------
Total Oil 286,700
Grinnell Station, Grinnell, Iowa Gas 30,000
Agency Street Combustion Turbines,
West Burlington, Iowa Gas 76,700
Burlington Combustion Turbines, Burlington, Iowa Gas 68,000
Red Cedar Combustion Turbine, Cedar Rapids, IA Gas 22,700
-------------
Total Gas 197,400
-------------
Total generating capability 1,950,850
=============
All KWs shown below represent the 1999 summer generating capability.
(1) Represents IESU's 70% ownership interest in this 520,000 KW generating station, which is operated by IESU.
(2) Represents IESU's 48% ownership interest in this 675,000 KW generating station, which is operated by IESU.
(3) Represents IESU's 28% ownership interest in this 515,000 KW generating station, which is operated by
MidAmerican Energy Company.
IESU owns 4,448 miles of electric transmission lines and 578 substations,
substantially all located in Iowa. IESU's principal properties are suitable for
their intended use and are held subject to liens of indentures relating to its
bonds.
21
IPC
IPC's principal electric generating stations at December 31, 1999, were
as follows:
Name and Location Primary Fuel 1999 Summer Capability
of Station Type in Kilowatts
- ------------------------------------------------------------- --------------- -------------------------------------
Dubuque Units 2, 3 and 4, Dubuque, IA Coal 81,500
M. L. Kapp Plant Units 1 and 2, Clinton, IA Coal 254,900
Lansing Units 1, 2, 3 and 4, Lansing, IA Coal 321,000
George Neal Unit 4, Sioux City, IA Coal 141,900 (1)
Louisa Unit 1, Louisa, IA Coal 28,400 (2)
-------------
Total Coal 827,700
Fox Lake Plant Units 1, 2 and 3, Sherburn, MN Gas 113,500
Montgomery Combustion Turbine Unit 1, Montgomery, MN Oil 22,200
Fox Lake Plant Combustion Turbine Unit 4, Sherburn, MN Oil 21,300
Lime Creek Plant Combustion Turbine
Units 1 and 2, Mason City, IA Oil 70,400
Dubuque Diesel Units 1 and 2, Dubuque, IA Oil 4,600
Hills Diesel Units 1 and 2, Hills, MN Oil 4,000
Lansing Diesel Units 1 and 2, Lansing, IA Oil 2,000
New Albin Diesel Unit 1, New Albin, IA Oil 700
-------------
Total Oil 125,200
-------------
Total generating capability 1,066,400
=============
All KWs shown below represent the 1999 summer generating capability.
(1) Represents IPC's 21.5% ownership interest in this 660,000 KW generating station, which is operated by
MidAmerican Energy Company.
(2) Represents IPC's 4% ownership interest in this 710,000 KW generating station, which is operated by
MidAmerican Energy Company.
IPC owns 2,562 miles of electric transmission lines and 224 substations located
in Iowa, Illinois and Minnesota. Substantially all of IPC's facilities are
subject to the lien of its bond indenture securing IPC's outstanding First
Mortgage Bonds and are suitable for their intended use.
Resources
Resources' principal properties as of December 31, 1999 were as follows:
Whiting - owns oil and gas properties at various locations within the
U.S. Proven developed reserves were 9.6 million barrels of oil and
97.4 million Dth of gas.
HPI - provides affordable housing in Wisconsin and the Midwest and
has a majority ownership in approximately 60 properties.
IEA - offers standby generation, cogeneration, steam production and
propane air systems. IEA's natural gas gathering system and oil
gathering system had 66 miles and 188 miles, respectively, of
pipeline in Texas.
CRANDIC - has 107 railroad track miles all located within Iowa.
Investments - has real estate ventures with 248,000 square feet of
office space primarily in Cedar Rapids, Iowa.
22
ITEM 3. LEGAL PROCEEDINGS
Alliant Energy
On July 15, 1999, the PSCW found that Alliant Energy was in violation of
the PSCW's merger order because after Alliant Energy exercised its right
to withdraw from the Midwest ISO, it had no proposal on file with the
PSCW either to be in an ISO or to spin off its transmission assets
(Alliant Energy has subsequently rejoined the Midwest ISO). The PSCW
deferred consideration of any remedies. Both Alliant Energy and the
intervenors in the proceeding had appealed the PSCW's decision to the
Dane County Circuit Court however the intervenors have since withdrawn
their appeal. Alliant Energy's appeal is still pending.
Alliant Energy received an adverse ruling in 1999 from a U.S. district
court judge dealing with an income tax refund claim Alliant Energy filed
relating to capital losses disallowed under audit by the IRS. The
district court judge also disallowed certain related deductions allowed
by the IRS as an offset against a tax refund due to Alliant Energy.
Alliant Energy has appealed the district court's ruling and such appeal
is pending. The IRS has appealed the decision which led to the tax
refund due to Alliant Energy and this appeal is also pending. Alliant
Energy believes the resolution of these issues will not have a material
adverse impact on its financial condition or results of operations.
WP&L
In the second quarter of 1999, WP&L received a demand for arbitration
from MG&E pursuant to the terms of joint plant operating agreements
between the parties regarding issues of ownership and operation of the
Columbia Energy Center. In September 1999, a Wisconsin Circuit Court
judge ruled that some of MG&E's claims were arbitrable. The parties have
selected the arbitrators and the procedural schedule is being developed.
WP&L believes MG&E's claims are without merit and will be vigorously
defending its position.
Environmental Matters
The information required by Item 3 with regards to environmental matters
is included in Notes 12(f) and 12(g) of Item 8. "Notes to Consolidated
Financial Statements," and "Other Matters - Environmental" in Item 7.
MD&A, which information is incorporated herein by reference.
Rate Matters
The information required by Item 3 with regards to rate matters is
included in "Liquidity and Capital Resources - Rates and Regulatory
Matters" in Item 7. MD&A, which information is incorporated herein by
reference.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
None.
EXECUTIVE OFFICERS OF THE REGISTRANTS
Information relating to the executive officers of Alliant Energy, IESU
and WP&L is included in Item 10. Directors and Executive Officers of the
Registrants.
23
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
Alliant Energy's common stock trades on the New York Stock Exchange under
the symbol "LNT." Quarterly sales price ranges and dividends with respect
to Alliant Energy's common stock were as follows (amounts for periods prior
to the consummation of the merger represent data for WPLH):
1999 1998
-------------------------------------------- -------------------------------------------
Quarter High Low Dividend High Low Dividend
First $32 3/8 $26 3/8 $0.50 $33 7/8 $31 1/2 $0.50
Second 30 7/8 26 1/2 0.50 35 3/8 29 5/8 0.50
Third 30 1/16 26 3/4 0.50 32 1/8 28 0.50
Fourth 28 13/16 25 3/16 0.50 34 29 3/4 0.50
----------- ----------- ------------- ----------- ----------- -----------
Year $32 3/8 $25 3/16 $2.00 $35 3/8 $28 $2.00
=========== =========== ============= =========== =========== ===========
Stock closing price at December 31, 1999: $27 1/2
Although Alliant Energy's practice has been to pay common stock dividends
quarterly, the timing of payment and amount of future dividends are
necessarily dependent upon earnings, financial requirements and other
factors.
At December 31, 1999, there were approximately 66,886 holders of record of
Alliant Energy's stock including underlying holders in Alliant Energy's
Shareowner Direct Plan.
Alliant Energy is the sole common shareowner of all 13,370,788 shares of
IESU Common Stock currently outstanding. During 1999, 1998 and 1997, IESU
declared dividends on its common stock of $88 million, $19 million and $56
million, respectively, to its parent. No dividend payments were made in
the last three quarters of 1998 due to merger-related tax considerations.
As a result, the dividend payment in the first quarter of 1999 was larger
than IESU's historical quarterly payment. IESU has the right under the
terms of its Subordinated Deferrable Interest Debentures, so long as an
Event of Default (as defined therein) has not occurred and is not
continuing, to extend the interest payment period at any time and from time
to time on the Subordinated Deferrable Interest Debentures to a period not
exceeding 20 consecutive quarters. If IESU exercises its right to extend
the interest payment period, IESU may not, during any such extended
interest payment period, declare or pay dividends on, or redeem, purchase
or acquire, or make any liquidation payment with respect to, any of its
capital stock or make any guarantee payment with respect to the foregoing.
IESU does not intend to exercise its right to extend the interest payment
period.
Alliant Energy is the sole common shareowner of all 13,236,601 shares of
WP&L common stock currently outstanding. During 1999, 1998 and 1997, WP&L
paid dividends on its common stock of $58 million each year to its parent.
WP&L's common stock dividends are restricted to the extent that such
dividends would reduce the common stock equity ratio to less than 25%.
Under rate order UR-110, the PSCW ordered that it must approve the payment
of dividends by WP&L to Alliant Energy that are in excess of the level
forecasted in the rate order ($58.3 million), if such dividends would
reduce WP&L's average common equity ratio below 52.00% of total
capitalization. The dividends paid by WP&L to Alliant Energy since the
rate order was issued have not exceeded the level forecasted in the rate
order.
Alliant Energy's utility subsidiaries each have common stock dividend
restrictions based on their respective bond indentures and articles of
incorporation. Each utility has restrictions on the payment of common
stock dividends that are commonly found with preferred stock. In addition,
IESU's and IPC's ability to pay common stock dividends is restricted based
on requirements associated with sinking funds.
24
ITEM 6. SELECTED FINANCIAL DATA
Alliant Energy Corporation
- ------------------------------------------------------------------------------------------------------------------------------------
1999 (1) 1998 (2) 1997 1996 1995
- ------------------------------------------------------------------------------------------------------------------------------------
Financial Information
(Dollars in thousands except for per share data)
- ------------------------------------------------------------------------------------------------------------------------------------
Income Statement Data:
Operating revenues $2,197,963 $2,130,874 $2,300,627 $2,232,840 $1,976,807
Operating expenses 1,821,428 1,847,572 1,964,244 1,867,401 1,611,875
Operating income 376,535 283,302 336,383 365,439 364,932
Income from continuing operations 196,581 96,675 144,578 157,088 159,157
Discontinued operations -- -- -- (1,297) (13,186)
Net income 196,581 96,675 144,578 155,791 145,971
- ------------------------------------------------------------------------------------------------------------------------------------
Common Stock Data:
Weighted average common shares outstanding (000s) 78,352 76,912 76,210 75,481 74,680
Return on average common equity (3) 10.5% 6.0% 9.5% 11.0% 10.5%
Per Share Data:
Income from continuing operations $2.51 $1.26 $1.90 $2.08 $2.13
Discontinued operations -- -- -- ($0.02) ($0.18)
Earnings per average common share (basic and diluted) $2.51 $1.26 $1.90 $2.06 $1.95
Dividends declared per common share (4) $2.00 $2.00 $2.00 $1.97 $1.94
Book value at year-end (3) $27.29 $20.69 $21.24 $18.91 $18.70
Market value at year-end (4) $27.50 $32.25 $33.13 $28.13 $30.63
- ------------------------------------------------------------------------------------------------------------------------------------
Other Selected Financial Data:
Construction and acquisition expenditures $478,573 $372,058 $328,040 $412,274 $375,184
Total assets at year-end (3) $6,075,683 $4,959,337 $4,923,550 $4,639,826 $4,476,406
Long-term obligations, net $1,660,558 $1,713,649 $1,604,305 $1,444,355 $1,357,755
Times interest earned before income taxes (5) 3.38X 2.25X 2.90X 3.38X 3.36X
Capitalization Ratios:
Common equity (3) 57% 49% 51% 52% 51%
Preferred and preference stock 3% 4% 3% 4% 4%
Long-term debt, excluding current portion 40% 47% 46% 44% 45%
---------------------------------------------------------------------
Total 100% 100% 100% 100% 100%
=====================================================================
- ------------------------------------------------------------------------------------------------------------------------------------
(1) The 1999 financial results reflect pre-tax gains of $40 million realized from sales of McLeod stock.
(2) The 1998 financial results reflect the recording of $54 million of pre-tax merger-related charges.
(3) In the third quarter of 1997, Alliant Energy began adjusting the carrying value of its investments in McLeod to its estimated
fair value, pursuant to the applicable accounting rules. At December 31, 1999, the adjustment reflected an unrealized gain of
approximately $1.1 billion with a net of tax increase to common equity of $640 million. At December 31, 1998, the adjustment
reflected an unrealized gain of approximately $291 million with a net of tax increase to common equity of $170 million.
(4) Represents data for WPLH for periods prior to the consummation of the merger.
(5) Represents income before income taxes plus preferred dividend requirements of subsidiaries plus interest expense divided by
interest expense.
25
IESU
Year Ended December 31,
1999 1998 1997 1996 1995
--------------------------------------------------------------------------------
(in thousands)
Operating revenues $800,696 $806,930 $813,978 $754,979 $709,826
Earnings available for common stock 65,532 60,996 57,879 62,815 58,364
Cash dividends declared on common stock 87,951 18,840 56,000 44,000 43,000
Total assets 1,755,808 1,788,978 1,768,929 1,765,044 1,697,803
Long-term obligations, net 641,559 677,804 688,719 560,199 517,538
The 1998 financial results reflect the recording of $17 million of pre-tax merger-related charges.
WP&L
Year Ended December 31,
1999 1998 1997 1996 1995
-------------------------------------------------------------------------------
(in thousands)
Operating revenues $752,505 $731,448 $794,717 $759,275 $689,672
Earnings available for common stock 67,520 32,264 67,924 79,175 75,342
Cash dividends declared on common stock 58,353 58,341 58,343 66,087 56,778
Total assets 1,766,135 1,685,150 1,664,604 1,677,814 1,641,165
Long-term obligations, net 471,648 471,554 420,414 370,634 375,574
The 1998 financial results reflect the recording of $17 million of pre-tax merger-related charges.
26
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
Alliant Energy was formed as the result of a three-way merger involving WPLH,
IES and IPC that was completed in April 1998. The primary first tier
subsidiaries of Alliant Energy include: WP&L, IESU, IPC, Resources and
Corporate Services. Among various other regulatory constraints, Alliant
Energy is operating as a registered public utility holding company subject to
the limitations imposed by PUHCA. This MD&A includes information relating to
Alliant Energy, IESU and WP&L (as well as IPC, Resources and Corporate
Services). Where appropriate, information relating to a specific entity has
been segregated and labeled as such.
FORWARD-LOOKING STATEMENTS
Statements contained in this report (including MD&A) that are not of
historical fact are forward-looking statements intended to qualify for the
safe harbors from liability established by the Private Securities Litigation
Reform Act of 1995. From time to time, Alliant Energy, IESU or WP&L may make
other forward-looking statements within the meaning of the federal securities
laws that involve judgments, assumptions and other uncertainties beyond the
control of such companies. These forward-looking statements may include,
among others, statements concerning revenue and cost trends, cost recovery,
cost reduction strategies and anticipated outcomes, pricing strategies,
changes in the utility industry, planned capital expenditures, financing needs
and availability, statements of expectations, beliefs, future plans and
strategies, anticipated events or trends and similar comments concerning
matters that are not historical facts. Investors and other users of the
forward-looking statements are cautioned that such statements are not a
guarantee of future performance and that such forward-looking statements are
subject to risks and uncertainties that could cause actual results to differ
materially from those expressed in, or implied by, such statements. Some, but
not all, of the risks and uncertainties include weather effects on sales and
revenues, competitive factors, general economic conditions in the relevant
service territory, federal and state regulatory or government actions,
including issues associated with the deregulation of the utility industry,
unanticipated construction and acquisition expenditures, issues related to
stranded costs and the recovery thereof, the operations of Alliant Energy's
nuclear facilities, unanticipated costs associated with certain environmental
remediation efforts being undertaken by Alliant Energy, unanticipated issues
relating to establishing a transmission company, material changes in the value
of Alliant Energy's investment in McLeod, technological developments, employee
workforce factors, including changes in key executives, collective bargaining
agreements or work stoppages, political, legal and economic conditions in
foreign countries Alliant Energy has investments in and changes in the rate of
inflation.
UTILITY INDUSTRY OUTLOOK
As a holding company with significant utility assets, Alliant Energy competes
in an ever-changing utility industry. Set forth below is an overview of this
evolving marketplace.
Electric energy generation, transmission and distribution are in a period of
fundamental change in the manner in which customers obtain, and energy
suppliers provide, energy services. As legislative, regulatory, economic and
technological changes occur, electric utilities are facing increased numbers
of alternative suppliers. Such competitive pressures could result in loss of
customers and an incurrence of stranded costs (i.e., assets and other costs
rendered unrecoverable as the result of competitive pricing). To the extent
stranded costs cannot be recovered from customers, they would be borne by
security holders.
Across the nation, approximately half of the states (including Illinois) have
passed legislation or issued regulatory rulings granting customers the right
to choose their electric energy supplier. Legislation that would allow
customers to choose their electric energy supplier is expected to be
introduced in Iowa in 2000. At the federal level, a number of proposals to
restructure the electric industry are currently under consideration. However,
there continues to be a lack of consensus over how restructuring should be
implemented and how much control the federal government should have over this
process. Until one of the proposals gains significant bipartisan support,
there is unlikely to be final federal action to either facilitate or force
states to open electricity markets to competition.
27
Alliant Energy realized 55%, 40%, 3% and 2% of its electric utility revenues
in 1999 in Iowa, Wisconsin, Minnesota and Illinois, respectively.
Approximately 90% of the electric revenues were regulated by the respective
state commissions while the other 10% were regulated by the FERC. Alliant
Energy realized 57%, 37%, 3% and 3% of its gas utility revenues in Iowa,
Wisconsin, Minnesota and Illinois, respectively, during the same period.
IESU realized 100% of its electric and gas utility retail revenues in 1999 in
Iowa. Approximately 95% of the electric revenues in 1999 were regulated by
the IUB while the other 5% were regulated by the FERC. WP&L realized 98% of
its electric utility revenues in 1999 in Wisconsin and 2% in Illinois.
Approximately 84% of the electric revenues in 1999 were regulated by the PSCW
or the ICC while the other 16% were regulated by the FERC. WP&L realized 96%
of its gas utility revenues in 1999 in Wisconsin and 4% in Illinois.
Federal Regulation
IESU, WP&L and IPC are subject to regulation by the FERC. NEPA addresses
several matters designed to promote competition in the electric wholesale
power generation market. FERC has issued final rules (FERC Orders 888/888-A
and 889/889-A) requiring electric utilities to open their transmission lines
to other wholesale buyers and sellers of electricity. In response to FERC
Orders 888 and 888-A, Corporate Services, on behalf of IESU, WP&L and IPC, has
filed Open Access Transmission Tariffs that comply with the orders. In
response to FERC Orders 889 and 889-A, IESU, WP&L and IPC are participating in
a regional Open Access Same-Time Information System.
FERC Order 888 permits utilities to seek recovery of legitimate, prudent and
verifiable stranded costs associated with providing open access transmission
services. FERC does not have jurisdiction over retail distribution and,
consequently, the final FERC rules do not provide for the recovery of stranded
costs resulting from retail competition. The various states retain
jurisdiction over the question of whether to permit retail competition, the
terms of such retail competition, and the recovery of any portion of stranded
costs that are ultimately determined to have resulted from retail competition.
In May 1999, FERC issued a NOPR concerning the development of RTOs. The
proposed rules outline the requirements for utilities to voluntarily turn over
control of their transmission system to a regional entity either by leasing
the system to an RTO or by outright divestiture. In December 1999, FERC
issued Order 2000 which implemented the proposed rules with minor
modifications. FERC's timeline is to have the RTOs in operation by the end of
2001. Alliant Energy is involved with other utilities and industry groups in
reviewing Order 2000 and has submitted a joint petition to FERC seeking
further clarification of the operating and ownership limitations that will be
imposed on the RTOs. Alliant Energy's current plans to contribute its
Wisconsin transmission assets to ATC, in exchange for an equity interest, and
participate in the Midwest ISO are expected to comply with the provisions of
Order 2000.
Alliant Energy and the utility subsidiaries cannot predict the long-term
consequences of these rules on their financial condition or results of
operations.
State Regulation
Iowa - IESU and IPC are subject to regulation by the IUB. The IUB has been
- ----
reviewing all forms of competition in the electric utility industry for
several years. A group comprised of the IUB, Alliant Energy, MidAmerican
Energy Company, rural electric cooperatives, municipal utilities and Iowans
for Choice in Electricity (a diverse group of industrial customers, marketers,
such as Enron, and a low income customer representative, among others)
endorsed a bill to allow for such competition that was introduced in the Iowa
Legislature in March 1999. The bill was opposed by the OCA, which is charged
by Iowa law with representation of all consumers generally. While the bill
did not pass, by operation of House rules, it was re-referred to the House
Commerce Committee and was again inserted into the legislative process in the
Second Regular Session of the 78th General Assembly (2000). As of March 1,
2000, the bill has been approved by both the Iowa House and Senate Commerce
Committees and will be addressed by the legislature in full.
The bill would allow choice of electric suppliers for all customers on October
1, 2002. It would freeze IESU's and IPC's Iowa regulated prices at January
2000 levels. It would allow, however, for investor-owned utilities to propose
28
increases due to exogenous factors (for example, environmental compliance
costs) in the generation cost component. Assigned service territories would
be maintained for the delivery function. Delivery prices would be regulated,
with the option available to propose performance based rate making. Prices
for generation and other retail services would not be regulated, except for
SOS pricing starting October 2002 for all residential customers and
non-residential customers with annual usage of fewer than 75,000 KWHs.
Pricing for SOS would initially be at levels equivalent to prices as they
exist today and would remain at such levels until at least December 31, 2005
for SOS customers. The IUB would be able to terminate SOS if it were to
determine several conditions existed, including, most importantly, that
effective competition existed such that regulation was no longer necessary.
If the IUB continues SOS past December 31, 2005, then prices would be based
upon competitive bids. There are no price protections for non-residential
customers with usage greater than 75,000 KWH annually, with the exception of
transitional service. Transitional service would exist for no longer than one
year, until October 1, 2003, at prices the IUB determines to be "just and
reasonable." Currently existing automatic fuel adjustment clauses for
recovery of fuel costs would be eliminated no later than October 2002. A
"nuclear-only" fuel adjustment would be permitted with increased prices
effective if an electric company's nuclear plant is not operational due to
exogenous factors.
Transition or stranded cost is the difference between the revenues that would
have been collected pursuant to an electric company's revenue requirement
existing as of January 1, 2000, and market prices for the period 2002 through
2005. These differences would be afforded 80% recovery in the first twelve
months of choice, with 70%, 60%, and 50% in each subsequent twelve-month
period. Effective October 1, 2006, transition cost recovery would end. In
lieu of accepting this transition cost recovery mechanism, an electric utility
would be entitled under the proposed legislation to elect to divest itself of
its generation assets, including power supply contracts. In such case, the
utility would be given an opportunity to be "made whole" for recovery of
embedded costs with the possibility for shareowners to retain 50% of the
amount realized from the sale of the assets beyond the sum of depreciated book
value and unfunded decommissioning. A divestiture plan would be filed with
the IUB no later than January 1, 2001, with IUB approval or modification by
July 1, 2001. The utility would have until September 30, 2001 to revoke its
election.
Costs of start-up, including computer systems and employee transition costs,
would be recoverable over a ten-year period, as approved by the IUB. The
difference between regulatory assets and liabilities would be fully
recoverable as a delivery charge. Nuclear decommissioning costs would be
fully recoverable. While Alliant Energy supports the proposed legislation in
its current form, it is unable to predict if this legislation will be enacted
in 2000, what modifications, if any, may be made to the proposed bill or what
actions Alliant Energy may take in response to the legislation should it be
enacted.
In the first quarter of 1999, the IUB conducted workshops concerning the
unbundling of natural gas rates for all Iowa customers as well as allowing
choice of the supplier of the natural gas for the small volume natural gas
customers. IESU's and IPC's natural gas costs are a "flow-through cost item"
in that they are automatically reflected in future billings to customers.
Such collections are reconciled on an annual basis to ensure that they neither
over- nor under-collect their actual gas commodity costs. Consequently,
Alliant Energy does not currently realize any margins or income with respect
to its provision of the gas commodity. Alliant Energy expects to continue to
be made whole for such gas costs if the gas rates are unbundled. Even if
Alliant Energy's gas commodity sales were to decline in a customer choice
environment, its margins and income would not be expected to be impacted by
such decreases in commodity sales. The delivery function of Alliant Energy's
gas business in Iowa will likely continue to be regulated on a cost of service
basis, as currently is the case. As a result, assuming no significant change
in the regulatory posture, the delivery function would continue to generate
comparable margins and income to that currently generated, regardless of what
entity provides the gas commodity to the customer. On March 3, 2000, the IUB
issued an order indicating that the IUB prefers to allow each utility to
design a tariff in order to remove barriers to a competitive option for small
volume customers. The IUB will also seek comments from the utility companies
before approving any tariff filings.
Wisconsin - WP&L is subject to regulation by the PSCW. The PSCW's inquiries
- ---------
into the future structure of the natural gas and electric utility industries
are ongoing. The stated goal of the PSCW regarding natural gas service is "to
accommodate competition but not create it." The PSCW has followed a measured
approach to restructuring the natural gas industry in Wisconsin. The PSCW has
determined that customer classes will be deregulated (i.e., the gas utility
would no longer have an obligation to procure gas commodity for customers, but
29
would still have a delivery obligation) in a step-wise manner, after each
class has been demonstrated to have a sufficient number of gas suppliers
available. The short-term goals of the PSCW's electric restructuring process
are to ensure reliability of the state's electric system and development of a
robust wholesale electric market. The long-term goal is to establish
prerequisite safeguards to protect customers prior to allowing retail customer
choice. There are no other restructuring working groups currently active in
Wisconsin.
In May 1998, the PSCW reactivated Docket No. 05-BU-101 with the objective of
examining the degree of separation which should be required as a matter of
policy between utility and non-utility activities involving the various state
utilities. Final hearings were held in February 2000 and the PSCW ruled that
utilities can continue to offer non-utility services to customers and
affiliates and that utilities must continue to fully allocate their costs to
such non-utility activities.
It is anticipated that there will be legislative proposals introduced in the
2001-2002 legislative session on issues dealing with restructuring of the
electric utility industry. It is not possible to predict at this time the
scope or the possibility of enactment of such proposals.
"Reliability 2000" legislation was enacted in Wisconsin in 1999. This
legislation included, among other items, a relaxation of the non-utility asset
limitations included in the WUHCA and the formation of a Wisconsin
transmission company for those Wisconsin utility holding companies who elect
to take advantage of the new asset cap law. Alliant Energy has agreed to
contribute WP&L's transmission assets to the transmission company (American
Transmission Company, or ATC) in exchange for an equity interest in ATC. WP&L
made several federal and state regulatory filings and commitments in the
fourth quarter of 1999 relating to its participation in ATC.
ATC's sole business will be to provide reliable, economic transmission service
to all customers in a fair and equitable manner. ATC will plan, construct,
operate, maintain and expand transmission facilities it will own to provide
for adequate and reliable transmission of power. It will provide comparable
service to all customers, including Alliant Energy, and it will support
effective competition in energy markets without favoring any market
participant. Formation of the company will require federal and state
regulatory approvals. ATC will be regulated by FERC for all rate terms and
conditions of service. ATC will be a transmission-owning member of the
Midwest ISO and will transfer operational control of the transmission systems
to the Midwest ISO.
ATC will be a public utility, as defined under Wisconsin law, with a board of
directors comprised of one representative from each utility having at least a
10% ownership interest in ATC. Smaller utilities could combine their
transmission assets with others to reach the minimum level for board
membership. In addition, the shareowners of ATC will select four at-large
directors that can not be employed or engaged in energy businesses.
The PSCW has not yet determined the exact scope of the assets that must be
transferred to the ATC. Pending the final determination by the PSCW, WP&L
estimates it will transfer approximately $150 million in plant assets at net
book value to the ATC when it becomes operational in late 2000. Alliant
Energy is also reviewing the possible contribution of IESU's and IPC's
transmission assets to ATC as well. Alliant Energy estimates the net book
value of such plant assets to approximate $220 million. While Alliant Energy
will realize its proportionate share of ATC's earnings, it is not yet known
what the overall financial impact of Alliant Energy's participation in ATC
will be.
Minnesota - IPC is subject to regulation by the MPUC. The MPUC established an
- ---------
Electric Competition Working Group in April 1995. On October 28, 1997, the
Working Group issued a report and recommendations on retail competition. The
MPUC reviewed the report and directed its staff to develop an electric utility
restructuring plan and timeline. The MPUC has recently solicited comments on
restructuring principles from stakeholders in the process. It does not appear
that any comprehensive restructuring legislation will be passed in 2000. The
MPUC has also initiated Docket E-999/CI-1261 to investigate the appropriate
classification of transmission assets in Minnesota.
Illinois - WP&L and IPC are subject to regulation by the ICC. In December
- --------
1997, the State of Illinois passed electric deregulation legislation requiring
customer choice of electric suppliers for non-residential customers with loads
of four MW or larger and for approximately one-third of all other
non-residential customers starting October 1, 1999. All remaining
non-residential customers will be eligible for customer choice beginning
30
December 31, 2000 and all residential customers will be eligible for customer
choice beginning May 1, 2002. The new legislation is not expected to have a
significant impact on Alliant Energy's financial condition or results of
operations given the relatively small size of Alliant Energy's Illinois
operations. As of December 31, 1999, no eligible Alliant Energy customer had
selected another electric supplier.
Accounting Implications
Each of the utilities complies with the provisions of SFAS 71, "Accounting for
the Effects of Certain Types of Regulation." SFAS 71 provides that
rate-regulated public utilities record certain costs and credits allowed in
the rate making process in different periods than for non-regulated entities.
These are deferred as regulatory assets or regulatory liabilities and are
recognized in the consolidated statements of income at the time they are
reflected in rates. If a portion of the utility subsidiaries' operations
becomes no longer subject to the provisions of SFAS 71 as a result of
competitive restructurings or otherwise, a write-down of related regulatory
assets and possibly other charges would be required, unless some form of
transition cost recovery is established by the appropriate regulatory body
that would meet the requirements under generally accepted accounting
principles for continued accounting as regulatory assets during such recovery
period. In addition, each utility subsidiary would be required to determine
any impairment of other assets and write-down any impaired assets to their
fair value. The utility subsidiaries believe they currently meet the
requirements of SFAS 71 and will continue to monitor and assess this as the
various utility industry restructuring initiatives progress.
Positioning for a Competitive Environment
Alliant Energy and its subsidiaries cannot currently predict the long-term
consequences of the competitive and restructuring issues described above on
their financial condition or results of operations. The major objective is to
allow the company to compete successfully in a competitive, deregulated
utility industry. The strategy for dealing with these emerging issues
includes seeking growth opportunities, forming strategic alliances with other
energy-related businesses, continuing to offer quality customer service,
initiating ongoing cost reductions and productivity enhancements and
developing new products and services.
As competitive forces shape the energy-services industry, energy providers are
being challenged to increase growth and profits. Because Alliant Energy
expects consumption of electricity and natural gas to grow only modestly
within Alliant Energy's domestic utility service territories, Alliant Energy
has entered several energy-services markets that it expects will provide
opportunities for new sources of growth. Alliant Energy, through its
subsidiary Resources, has established new distinct platforms to complement its
existing non-regulated investments, which are designed to meet customer
needs. These platforms and existing investments include:
Investments: Resources' existing investments include an oil and gas
-----------
production company, a short-line railroad, a barge company, an
affordable housing company, various real estate joint ventures and an
equity stake in an independent telecommunications provider.
International: International is a partner in developing, or seeking to
-------------
develop, energy generation and infrastructure in New Zealand, Australia,
China, Mexico and Brazil, markets which have been selected because of
their growth potential.
Industrial Services: ISCO is a provider of energy and environmental
--------------------
services designed to maximize productivity for industrial and large
commercial customers. This platform consists of four units: Energy
Planning; Energy Management; Energy Applications, which provides
facilities-based and commodities-based energy solutions; and RMT, Inc.,
an environmental management and engineering firm with offices throughout
the U.S. and the United Kingdom.
Cargill-Alliant: Alliant Energy has an energy-trading joint venture with
---------------
Cargill that combines the risk-management and commodity trading
expertise of Cargill with Alliant Energy's low-cost electricity
generation and transmission business experience. Cargill-Alliant
officially began operations in 1997 and has an initial term though
October 2002. The term automatically renews for successive five-year
periods unless either party notifies the other at least one year prior
to the then expiring term.
Mass Markets: Resources is a provider of products and services designed
-------------
to meet the comfort, security and productivity needs of residential and
small commercial customers. Resources currently offers home appliance
and furnace warranties and a variety of home energy, safety and security
products through its "Power House" catalog. Such products are marketed
directly to customers, through the mail with the catalog and over the
Internet. Resources expects to continue pursuing opportunities in these
markets, which it believes has a growth potential as industry
deregulation allows more customers to choose their energy suppliers in
an open market.
31
Alliant Energy believes that each of these platforms provide prospects for
growth both individually and collectively as the competitive energy-services
marketplace evolves. Alliant Energy expects that these strategies will
contribute significantly to its annual earnings growth target of 4-6% from its
business operations. Resources is expected to contribute 25% of such earnings
within the next 3-5 years.
ALLIANT ENERGY RESULTS OF OPERATIONS
Overview - Alliant Energy's earnings for each of the last three years were as
- --------
follows (in thousands, except per share amounts):
1999 1998 1997
-------------- ------------- --------------
Net income $196,581 $96,675 $144,578
Average number of common shares outstanding 78,352 76,912 76,210
Earnings per average common share (basic and diluted) $2.51 $1.26 $1.90
Pre-tax merger expenses -- $54,045 $2,448
The significant increase in Alliant Energy's 1999 earnings compared to 1998
was due to increased earnings from non-regulated operations of $0.60 per share
(of which $0.32 per share was attributable to sales of McLeod stock), higher
electric and natural gas margins from utility operations and lower utility
operation and maintenance expenses. Higher depreciation (excluding hedge
losses in WP&L's nuclear decommissioning trust fund) and interest expenses
partially offset these items. The 1998 results also included approximately
$54 million of pre-tax merger-related expenses ($0.45 per share).
The 1999 utility earnings were $161.1 million ($2.06 per share) compared to
$109.5 million ($1.42 per share) for 1998. The increase in utility earnings
resulted primarily from higher electric and natural gas margins ($0.24 and
$0.04 per share, respectively), lower operation and maintenance expenses
($0.09 per share) and income realized from weather hedges ($0.04 per share).
Higher depreciation (excluding hedge losses in WP&L's nuclear decommissioning
trust fund) and interest expenses ($0.10 and $0.02 per share, respectively)
and a higher effective income tax rate ($0.02 per share) partially offset
these items. The 1998 utility results included approximately $0.42 per share
of merger-related expenses.
Resources reported net income of $37.8 million ($0.48 per share) in 1999
compared to a net loss of $8.9 million (($0.12) per share) for 1998. The 1999
earnings included gains realized from several asset sales, including
approximately 7% of Alliant Energy's investment in McLeod ($0.32 per share),
oil and gas properties at Whiting ($0.08 per share) and certain New Zealand
electric distribution investments ($0.05 per share). Earnings from Alliant
Energy's electricity trading joint venture ($0.06 per share), improved
operating results from Whiting ($0.03 per share) and improved earnings from
Alliant Energy's other non-regulated businesses ($0.03 per share) also
contributed to the increased earnings. The 1998 results for Resources also
included merger-related expenses ($0.03 per share).
The 1998 utility earnings were $109.5 million compared to $152.5 million for
1997. The decrease in 1998 utility earnings resulted primarily from
merger-related expenses, higher purchased-power and transmission costs at
WP&L, a 15.7% decrease in retail natural gas sales largely due to milder
weather conditions in 1998 compared to 1997, a $9 million regulatory asset
write-off at IESU, increased expenses for Year 2000 readiness efforts, higher
insurance-related expenses and increased depreciation expenses. These
decreases were partially offset by a 2% increase in retail electricity sales
volumes, largely due to continued economic growth within Alliant Energy's
service territory, lower purchased-power capacity costs at IESU and IPC,
reduced employee benefits costs and lower costs in 1998 due to merger-related
operating efficiencies. A loss incurred on the disposition of an investment
in 1997 at IESU also enhanced the 1998 earnings compared to 1997.
32
Resources reported net losses of $8.9 million and $4.0 million in 1998 and
1997, respectively. The increased loss in 1998 was due to merger-related
expenses, lower oil and gas prices at Whiting, continuing expenses for new
business development in international and domestic markets, higher interest
expense to fund Alliant Energy's growth and a modest loss from Alliant
Energy's electricity trading joint venture. A tax benefit realized in 1997
from a donation of securities to Alliant Energy's charitable foundation also
contributed to the lower earnings in 1998 compared to 1997. Increased
earnings from Alliant Energy's industrial services businesses as well as gains
realized on asset sales partially offset these items.
Electric Utility Operations - Electric margins and MWH sales for Alliant
- ----------------------------
Energy for 1999, 1998 and 1997 were as follows:
Revenues and Costs MWHs Sold
(in thousands) (in thousands)
--------------------------------------------------- --------------------------------------------
1999 1998 * 1997 ** 1999 1998 * 1997 **
------------ ------------ ------- ----------- ----- --------- --------- ------- -------- ------
Residential $541,714 $532,676 2% $521,574 2% 7,024 6,826 3% 6,851 --
Commercial 329,487 317,704 4% 307,941 3% 5,260 4,943 6% 4,844 2%
Industrial 476,140 477,241 -- 455,912 5% 13,036 12,718 3% 12,320 3%
------------ ------------ ----------- --------- --------- --------
Total from ultimate
customers 1,347,341 1,327,621 1% 1,285,427 3% 25,320 24,487 3% 24,015 2%
Sales for resale 155,801 199,128 (22%) 192,346 4% 5,566 7,189 (23%) 6,768 6%
Other 45,796 40,693 13% 37,980 7% 162 158 3% 161 (2%)
------------ ------------ -----------
--------- --------- --------
Total revenues 1,548,938 1,567,442 (1%) 1,515,753 3% 31,048 31,834 (2%) 30,944 3%
========= ========= ========
Electric production
fuels expense 247,136 283,866 (13%) 265,105 7%
Purchased power
expense 255,446 255,332 -- 256,306 --
------------ ------------ -----------
Margin $1,046,356 $1,028,244 2% $994,342 3%
============ ============ ===========
* Reflects the % change from 1998 to 1999.
** Reflects the % change from 1997 to 1998.
Electric margin increased $18.1 million, or 2%, and $33.9 million, or 3%, for
1999 and 1998, respectively. The 1999 increase was primarily due to separate
$15 million annual rate adjustments implemented at WP&L in July 1998 and March
1999 to recover higher purchased-power and transmission costs, a favorable $9
million change in estimate of Alliant Energy's utility services rendered but
unbilled at month-end based on refinements made to Alliant Energy's estimation
process in 1999 and an increase in retail sales of 3% due to more favorable
weather conditions and economic growth in the service territory. Partially
offsetting these increases were reduced recoveries of approximately $14
million in concurrent and previously deferred expenditures for Iowa-mandated
energy efficiency programs, lower sales to off-system and wholesale customers,
higher purchased-power capacity costs in Iowa and $3.2 million of revenues
collected from WP&L customers in 1998 for a surcharge related to Kewaunee.
The recovery for energy efficiency programs in Iowa is in accordance with IUB
orders (a portion of these recoveries is offset as they are also amortized to
expense in other operation expense). The lower sales to off-system and
wholesale customers were primarily due to lower wholesale customer contractual
commitments and transmission constraints.
The increase in electric margin for 1998 was primarily due to the increased
recovery of $26 million of concurrent and previously deferred expenditures for
Iowa-mandated energy efficiency programs, reduced purchased-power capacity
costs at IESU and IPC, higher sales volumes to retail customers and WP&L's
reliance on more costly purchased-power in the first six months of 1997 due to
various power plant outages, particularly Kewaunee. The increased sales
volumes were primarily due to continued economic growth within the Alliant
Energy service territory. These increases were partially offset by a lower
margin at WP&L and a rate decrease implemented at IPC in 1997. The lower
margin at WP&L was due to the regulatory lag associated with the rate recovery
of higher purchased-power and transmission costs, a rate decrease implemented
in 1997 and lower off-system sales income.
33
IESU's and IPC's electric tariffs include EAC's that are designed to currently
recover the costs of fuel and the energy portion of purchased-power billings
(see Note 1(j) of the "Notes to Consolidated Financial Statements" for
discussion of the EAC).
Gas Utility Operations - Gas margins and Dth sales for Alliant Energy for
- ----------------------
1999, 1998 and 1997 were as follows:
Revenues and Costs Dekatherms Sold
(in thousands) (in thousands)
-------------------------------------------------- -----------------------------------------------
1999 1998 * 1997 ** 1999 1998 * 1997 **
----------- ---------- ------ ----------- ------- --------- --------- ------- ---------- --------
Residential $185,090 $175,603 5% $225,542 (22%) 30,309 28,378 7% 33,894 (16%)
Commercial 89,118 85,842 4% 115,858 (26%) 18,349 17,760 3% 21,142 (16%)
Industrial 21,855 20,204 8% 27,393 (26%) 5,963 5,507 8% 6,217 (11%)
Transportation/other 18,256 13,941 31% 25,114 (44%) 46,954 52,389 (10%) 56,719 (8%)
----------- ---------- -----------
--------- --------- ----------
Total revenues 314,319 295,590 6% 393,907 (25%) 101,575 104,034 (2%) 117,972 (12%)
========= ========= ==========
Cost of gas sold 180,519 166,453 8% 259,222 (36%)
----------- ---------- -----------
Margin $133,800 $129,137 4% $134,685 (4%)
=========== ========== ===========
* Reflects the % change from 1998 to 1999.
** Reflects the % change from 1997 to 1998.
Gas margin increased $4.7 million, or 4%, and decreased $5.5 million, or 4%,
for 1999 and 1998, respectively. The 1999 increase was primarily due to
higher retail sales due to customer growth and more favorable weather
conditions in 1999. The sales increase was partially offset by decreased
recoveries of $2.6 million from the recovery of concurrent and previously
deferred energy efficiency expenditures for Iowa-mandated energy efficiency
program costs in accordance with IUB orders (a portion of these recoveries is
offset as they are also amortized to expense in other operation expense).
Refer to "Interest Expense and Other" for a discussion of income realized from
two gas weather hedges at WP&L in 1999. The decrease in gas margin in 1998
was primarily due to a 12% decrease in Dth sales, largely due to milder
weather, and a rate reduction implemented in April 1997 at WP&L. An increase
in revenues of $6.3 million from the recovery of energy efficiency
expenditures in Iowa and gas cost adjustments at IPC partially offset the
sales decrease.
IESU's and IPC's gas tariffs include PGA clauses that are designed to
currently recover the cost of utility gas sold (see Note 1(j) of the "Notes to
Consolidated Financial Statements" for a discussion of the PGA).
Non-regulated and Other Revenues - Non-regulated and other revenues for 1999,
- --------------------------------
1998 and 1997 were as follows (in millions):
1999 1998 1997
--------- --------- ---------
ISCO $196 $127 $245
Oil and gas (Whiting) 63 65 69
Steam 28 27 29
Transportation 22 22 21
Other 26 27 27
--------- --------- ---------
$335 $268 $391
========= ========= =========
The revenues for ISCO increased significantly in 1999 primarily due to the
second quarter 1999 acquisition of an oil gathering and transportation
business in Texas and increased demand for environmental and engineering
services. Such increases were partially offset by reduced activity in the
energy marketing business. The revenues for ISCO declined significantly in
1998 compared to 1997 primarily due to decreased low-margin gas marketing
activities and the transfer of the electricity trading business to the Cargill
joint venture in July 1997. Alliant Energy's investment in the joint venture
is accounted for under the equity method of accounting.
34
Other Operating Expenses - Other operation expenses for 1999, 1998 and 1997
- --------------------------
were as follows (in millions):
1999 1998 1997
---------- --------- ---------
Utility - IESU / WP&L / IPC $366 $421 $358
ISCO 183 117 239
Oil and gas (Whiting) 35 38 40
Transportation 8 8 8
Other 32 36 37
---------- --------- ---------
$624 $620 $682
========== ========= =========
Other operation expenses at the utility subsidiaries decreased $55 million in
1999 primarily due to the nonrecurrence of $34 million of merger-related
expenses incurred in 1998, lower energy efficiency expenses of $17 million in
Iowa, a 1998 write-off of $9 million of certain employee benefits related
regulatory assets at IESU, decreased transmission and distribution expenses,
lower operating costs at Alliant Energy's generating plants, reduced
insurance-related expenses and lower costs in 1999 due to merger-related
operating efficiencies. The merger-related expenses were primarily for
employee retirements ($15 million), separations ($13 million) and relocations
($4 million). These decreases were partially offset by higher costs for
employee incentive compensation, energy conservation expense at WP&L and
employee benefits.
Other operation expenses at ISCO increased $66 million in 1999 primarily due
to expenses associated with the acquisition of the oil gathering and
transportation business and the increased demand for environmental and
engineering services, partially offset by lower operation expenses in the
energy marketing business. Other operation expenses at ISCO decreased $122
million in 1998 primarily due to the formation of the Cargill joint venture.
Other operation expenses at the utility subsidiaries increased $63 million in
1998 primarily due to the merger-related expenses, increased energy efficiency
expenses in Iowa, the regulatory asset write-off at IESU, higher
administrative and general expenses at WP&L, higher insurance-related expenses
and increased expenses for Year 2000 readiness efforts. The increase was
partially offset by reduced employee benefit expenses, reduced energy
conservation expense at WP&L, lower costs resulting from merger-related
operating efficiencies and reduced nuclear operation expenses at IESU. The
regulatory asset write-off resulted from IESU assessing in the fourth quarter
of 1998 how certain employee benefit costs were recovered in the rate making
process in Iowa. Based on such review, IESU concluded it could no longer meet
the required "probable" standard for SFAS 71.
The 1999 decrease in maintenance expenses was primarily due to reduced nuclear
and transmission and distribution maintenance expenses. Such decreases were
partially offset by increased expenses for Alliant Energy's Year 2000
readiness program and higher expenses at Alliant Energy's fossil-fueled
generating plants. Maintenance expenses were flat in 1998 primarily due to
reduced expenses at fossil-fueled plants, which were virtually offset by
increased maintenance at the nuclear plants.
Depreciation and amortization expense decreased $0.4 million and increased
$19.8 million in 1999 and 1998, respectively. The 1999 decrease was primarily
due to reduced earnings in WP&L's nuclear decommissioning trust fund (offset
entirely in "Miscellaneous, net"), lower depletion expense at Whiting and the
$3.2 million Kewaunee surcharge in 1998 at WP&L (recorded in depreciation and
amortization expense with a corresponding increase in revenues resulting in no
earnings impact). These items were largely offset by increases in
depreciation expense due to utility property additions. The increase in 1998
was due to utility property additions and the Kewaunee surcharge.
35
Interest Expense and Other - Interest expense increased $6.9 million and $6.8
- --------------------------
million in 1999 and 1998, respectively, due to higher utility and
non-regulated borrowings. Also contributing to the 1999 increase was higher
nuclear decommissioning trust fund interest expense at IESU, which was offset
entirely in "Miscellaneous, net." Contributing to the 1998 increase was an
adjustment to decrease interest expense in 1997 relating to a tax audit
settlement at WP&L.
The accounting for earnings on the nuclear decommissioning trust funds results
in no net income impact. Miscellaneous, net income increases for earnings on
the nuclear decommissioning funds at both WP&L and IESU. In accordance with
their respective regulatory requirements, the corresponding offset is recorded
through depreciation expense at WP&L and interest expense at IESU.
Alliant Energy sold approximately 7% (1.4 million shares, as adjusted for
McLeod's 2-for-1 stock split in July 1999) of its investment in McLeod in
1999, resulting in pre-tax gains of approximately $40 million.
Miscellaneous, net income increased $35.2 million and decreased $13.2 million
in 1999 and 1998, respectively. The 1999 increase was due to the following
factors:
(a) $17 million of merger-related expenses incurred in 1998 for the services
of Alliant Energy's advisors and costs related to Alliant Energy's
merger-related name change.
(b) Gains of $10 million and $6 million realized from the sales of several
oil and gas properties at Whiting and certain New Zealand electric
distribution investments, respectively.
(c) A $7 million increase in pre-tax earnings from Alliant Energy's
electricity trading joint venture.
(d) $5 million of income realized from weather hedges at WP&L. Refer to
Note 11(d) of the "Notes to Consolidated Financial Statements" for a
further discussion.
(e) These items were partially offset by a decrease of $11 million in
earnings on Alliant Energy's nuclear decommissioning trust funds.
The 1998 decrease in miscellaneous, net income was due to the merger-related
expenses and a modest loss from Alliant Energy's electricity trading joint
venture, partially offset by gains on asset sales in 1998. The 1997 results
also included a loss incurred on the disposition of an investment at IESU.
Income Taxes - The effective income tax rates for Alliant Energy were 37.2%,
- -------------
36.0% and 35.1% in 1999, 1998 and 1997, respectively. See Note 6 of the
"Notes to Consolidated Financial Statements" for a discussion of the changes.
IESU RESULTS OF OPERATIONS
Overview - IESU's earnings available for common stock increased $4.5 million
- ---------
and $3.1 million in 1999 and 1998, respectively. The increased earnings for
1999 were primarily due to $17 million of merger-related expenses in 1998, a
$9 million regulatory asset write-off in 1998, a change in estimate of IESU's
unbilled revenues and reduced maintenance expenses. Such increases were
partially offset by higher depreciation and amortization expense, increased
administrative and general expenses and a higher effective income tax rate.
The increased earnings for 1998 were primarily due to a 2% increase in retail
electric sales volumes, largely due to continued economic growth in IESU's
service territory, lower purchased-power capacity costs, reduced employee
benefits costs and lower costs in 1998 due to merger-related operating
efficiencies. A loss incurred on the disposition of an investment in 1997
also improved 1998 earnings compared to 1997. Partially offsetting the higher
1998 earnings were merger-related expenses, the regulatory asset write-off
described above, decreased retail natural gas sales resulting from milder
weather, increased depreciation and amortization expenses and increased
expenses for Year 2000 readiness efforts.
36
Electric Utility Operations - Electric margins and MWH sales for IESU for
- ---------------------------
1999, 1998 and 1997 were as follows:
Revenues and Costs MWHs Sold
(in thousands) (in thousands)
-------------------------------------------------- --------------------------------------------
1999 1998 * 1997 ** 1999 1998 * 1997 **
---------- ---------- ------- ----------- ------ -------- --------- ------- -------- ------
Residential $230,422 $232,662 (1%) $227,496 2% 2,685 2,661 1% 2,682 (1%)
Commercial 176,251 168,672 4% 162,626 4% 2,658 2,465 8% 2,378 4%
Industrial 181,740 181,369 -- 177,890 2% 5,072 4,872 4% 4,743 3%
---------- ---------- ----------- -------- --------- --------
Total from ultimate
customers 588,413 582,703 1% 568,012 3% 10,415 9,998 4% 9,803 2%
Sales for resale 28,479 45,453 (37%) 25,719 77% 1,392 1,763 (21%) 794 122%
Other 11,058 11,267 (2%) 10,539 7% 40 42 (5%) 43 (2%)
---------- ---------- -----------
-------- --------- --------
Total revenues 627,950 639,423 (2%) 604,270 6% 11,847 11,803 -- 10,640 11%
======== ========= ========
Electric production
fuels expense 80,079 99,362 (19%) 92,891 7%
Purchased power
expense 82,402 71,637 15% 74,098 (3%)
---------- ---------- -----------
Margin $465,469 $468,424 (1%) $437,281 7%
========== ========== ===========
* Reflects the % change from 1998 to 1999.
** Reflects the % change from 1997 to 1998.
Electric margin decreased $3.0 million, or 1%, and increased $31.1 million, or
7%, for 1999 and 1998, respectively. The 1999 decrease was primarily due to
reduced recoveries of approximately $4 million in concurrent and previously
deferred expenditures for Iowa-mandated energy efficiency programs and
increased purchased-power capacity costs. The recovery for energy efficiency
programs in Iowa is in accordance with IUB orders (a portion of these
recoveries is offset as they are also amortized to expense in other operation
expense). Sales for resale decreased significantly in 1999 primarily due to
various resale customers of IESU selecting another utility as their
electricity provider effective in early 1999. The loss of such customers has
not had a material impact on IESU's electric margins. Sales to retail
customers increased primarily due to continued economic growth in IESU's
service territory and more favorable weather conditions. The 1999 electric
margin also benefited from a favorable $5 million change in estimate of IESU's
utility services rendered but unbilled at month-end based on refinements made
to IESU's estimation process in 1999.
The 1998 increase was primarily due to the increased recovery of approximately
$15 million of concurrent and previously deferred expenditures for
Iowa-mandated energy efficiency programs, increases in sales volumes to retail
customers due to economic growth in the service territory and reduced
purchased-power capacity costs. Sales for resale increased significantly for
1998 as a result of the implementation of a merger-related joint sales
agreement during the second quarter of 1998 (off-system sales revenues are
passed through IESU's energy adjustment clause and therefore have no impact on
electric margin). Refer to "Liquidity and Capital Resources - Rates and
Regulatory Matters" for a further discussion.
IESU's electric tariffs include EAC's that are designed to currently recover
the costs of fuel and the energy portion of purchased-power billings. Refer
to Note 1(j) of Alliant Energy's "Notes to Consolidated Financial Statements"
for discussion of the EAC.
37
Gas Utility Operations - Gas margins and Dth sales for IESU for 1999, 1998 and
- ----------------------
1997 were as follows:
Revenues and Costs Dekatherms Sold
(in thousands) (in thousands)
------------------------------------------------ -------------------------------------------
1999 1998 * 1997 ** 1999 1998 * 1997 **
--------- --------- ------ ----------- ------- ------- ------- ------- -------- --------
Residential $88,302 $86,821 2% $110,663 (22%) 13,778 13,803 -- 16,317 (15%)
Commercial 40,459 39,928 1% 54,383 (27%) 8,077 8,272 (2%) 9,602 (14%)
Industrial 11,543 10,422 11% 13,961 (25%) 3,291 3,089 7% 3,318 (7%)
Transportation/other 5,521 4,108 34% 4,510 (9%) 10,236 11,316 (10%) 10,321 10%
--------- --------- -----------
------- ------- --------
Total revenues 145,825 141,279 3% 183,517 (23%) 35,382 36,480 (3%) 39,558 (8%)
======= ======= ========
Cost of gas sold 88,308 84,642 4% 126,631 (33%)
--------- --------- -----------
Margin $57,517 $56,637 2% $56,886 --
========= ========= ===========
* Reflects the % change from 1998 to 1999.
** Reflects the % change from 1997 to 1998.
Gas margin increased $0.9 million, or 2%, and decreased $0.2 million for 1999
and 1998, respectively. The 1999 increase was primarily due to increased
retail sales from more favorable weather conditions in 1999. The decrease in
1998 was primarily from reduced sales as a result of milder weather, which was
substantially offset by the increased recovery of $4.2 million of concurrent
and previously deferred energy efficiency expenditures for Iowa-mandated
energy efficiency program costs in accordance with IUB orders (a portion of
these recoveries is offset as they are also amortized to expense in other
operation expenses).
IESU's gas tariffs include PGA clauses that are designed to currently recover
the cost of gas sold. Refer to Alliant Energy's Note 1(j) of the "Notes to
Consolidated Financial Statements" for discussion of the PGA.
Other Operating Expenses - IESU's other operation expenses decreased $13.5
- ------------------------
million and increased $26.5 million for 1999 and 1998, respectively. The 1999
decrease was primarily due to $10.5 million of merger-related expenses in
1998, a $9 million regulatory asset write-off in 1998, a $4 million decrease
in energy efficiency expenses and merger-related operating efficiencies
realized in 1999. The merger-related expenses were primarily for employee
retirements, separations and relocations. The regulatory asset write-off
resulted from IESU assessing in the fourth quarter of 1998 how certain
employee benefit costs were recovered in the rate making process in Iowa.
Based on such review, IESU concluded it could no longer meet the required
"probable" standard for SFAS 71. Such decreases were partially offset by
increased costs for employee incentive compensation and higher employee
benefit costs. The 1998 increase was primarily due to higher merger-related
expenses, increased energy efficiency expenses, the regulatory asset write-off
mentioned above and increased Year 2000 readiness costs. These items were
partially offset by lower nuclear operation expenses, reduced employee pension
and benefit costs and lower costs resulting from merger-related operating
efficiencies.
Maintenance expenses decreased $3.5 million and $1.8 million in 1999 and 1998,
respectively. The decrease in 1999 was primarily due to reduced nuclear
maintenance expenses and lower transmission and distribution maintenance
expenses, partially offset by increased Year 2000 readiness costs and higher
fossil-fueled maintenance expenses. The decrease in 1998 was due to reduced
fossil-fueled maintenance expenses, which were partially offset by higher
nuclear maintenance expenses.
Depreciation and amortization expenses increased $7.1 million and $4.2 million
for 1999 and 1998, respectively, primarily due to property additions and
amortization of software.
38
Interest Expense and Other - Interest expense decreased $0.5 million and $0.4
- --------------------------
million in 1999 and 1998, respectively. The 1999 decrease was primarily due
to lower average amounts of debt outstanding which was partially offset by
higher nuclear decommissioning trust fund interest expense, which was offset
entirely in "Miscellaneous, net."
The accounting for earnings on the nuclear decommissioning trust funds results
in no net income impact. Miscellaneous, net income increases for earnings on
the trust fund and the corresponding offset is recorded as interest expense.
Miscellaneous, net income increased $6.4 million and decreased $0.3 million
for 1999 and 1998, respectively. The increase in 1999 resulted primarily from
$6.0 million of merger-related expenses in 1998 and higher nuclear
decommissioning trust fund earnings, which were partially offset by a gain on
an asset sale in 1998. The 1998 decrease resulted primarily from
merger-related expenses, which were substantially offset by the loss incurred
on disposition of an investment in 1997 and a gain on an asset sale in 1998.
Income Taxes - The effective income tax rates were 42.6%, 40.1% and 41.8% in
- ------------
1999, 1998 and 1997, respectively. See Note 6 of the "Notes to Consolidated
Financial Statements" for a discussion of the changes.
WP&L RESULTS OF OPERATIONS
Overview - WP&L's earnings available for common stock increased $35.3 million
- ---------
and decreased $35.7 million in 1999 and 1998, respectively. The increased
earnings for 1999 were primarily due to $17.3 million of merger-related
expenses in 1998, higher electric and natural gas margins, reduced other
operation and maintenance expenses and income realized from weather hedges.
Such increases were partially offset by increased depreciation and
amortization expense (excluding hedge losses in WP&L's nuclear decommissioning
trust fund) and higher interest expense. The decreased earnings for 1998 were
primarily due to merger-related expenses, higher purchased-power and
transmission costs, higher depreciation and amortization expenses, decreased
retail natural gas sales largely due to milder weather, higher
insurance-related expenses, higher interest expense and a higher effective tax
rate. These decreases were partially offset by a 3% increase in retail
electric sales volumes, largely due to continued economic growth in the
service territory, reduced employee pension and benefit costs and lower costs
in 1998 due to merger-related operating efficiencies.
Electric Utility Operations - Electric margins and MWH sales for WP&L for
- ---------------------------
1999, 1998 and 1997 were as follows:
Revenues and Costs MWHs Sold
(in thousands) (in thousands)
--------------------------------------------------- -------------------------------------------
1999 1998 * 1997 ** 1999 1998 * 1997 **
---------- ---------- ------- ----------- -------- -------- -------- ------- -------- -------
Residential $213,496 $198,770 7% $199,633 -- 3,111 2,964 5% 2,974 --
Commercial 116,947 108,724 8% 107,132 1% 1,980 1,898 4% 1,878 1%
Industrial 171,118 162,771 5% 152,073 7% 4,570 4,493 2% 4,256 6%
---------- ---------- ----------- -------- -------- --------
Total from ultimate
customers 501,561 470,265 7% 458,838 2% 9,661 9,355 3% 9,108 3%
Sales for resale 102,751 128,536 (20%) 160,917 (20%) 3,252 4,492 (28%) 5,824 (23%)
Other 22,295 15,903 40% 14,388 11% 54 59 (8%) 60 (2%)
---------- ---------- -----------
-------- -------- --------
Total revenues 626,607 614,704 2% 634,143 (3%) 12,967 13,906 (7%) 14,992 (7%)
======== ======== ========
Electric production
fuels expense 110,521 120,485 (8%) 116,812 3%
Purchased power expense 107,598 113,936 (6%) 125,438 (9%)
---------- ---------- -----------
Margin $408,488 $380,283 7% $391,893 (3%)
========== ========== ===========
* Reflects the % change from 1998 to 1999.
** Reflects the % change from 1997 to 1998.
Electric margin increased $28.2 million, or 7%, and decreased $11.6 million,
or 3%, during 1999 and 1998, respectively. The 1999 increase was primarily
due to separate $15 million annual rate adjustments implemented at WP&L in
39
July 1998 and March 1999 to recover higher purchased-power and transmission
costs. An increase in retail sales of 3% due to more favorable weather and
economic growth within WP&L's service territory also contributed to the
increase. Partially offsetting the 1999 increase were lower sales to
off-system and wholesale customers due to transmission constraints and
decreased contractual commitments and $3.2 million of revenues collected in
1998 for a surcharge related to Kewaunee.
The 1998 decline in margin was due to regulatory lag associated with rate
recovery of higher purchased-power and transmission costs, a rate decrease of
2.4% implemented in April 1997 and lower off-system sales income. These items
were partially offset by WP&L's reliance on more costly purchased-power in the
first six months of 1997 due to various power plant outages, particularly
Kewaunee, and a 3% increase in retail sales.
Gas Utility Operations - Gas margins and Dth sales for WP&L for 1999, 1998 and
- ----------------------
1997 were as follows:
Revenues and Costs Dekatherms Sold
(in thousands) (in thousands)
----------------------------------------------- ----------------------------------------
1999 1998 * 1997 ** 1999 1998 * 1997 **
--------- ---------- ------ ---------- ------- ------- -------- ------ ------- -------
Residential $69,662 $65,173 7% $84,513 (23%) 12,070 10,936 10% 12,770 (14%)
Commercial 35,570 33,898 5% 45,456 (25%) 7,771 7,285 7% 8,592 (15%)
Industrial 6,077 5,896 3% 8,378 (30%) 1,520 1,422 7% 1,714 (17%)
Transportation/other 9,461 6,770 40% 17,536 (61%) 13,237 12,948 2% 17,595 (26%)
--------- ---------- ----------
------- -------- -------
Total revenues 120,770 111,737 8% 155,883 (28%) 34,598 32,591 6% 40,671 (20%)
======= ======== =======
Cost of gas sold 64,073 61,409 4% 99,267 (38%)
--------- ---------- ----------
Margin $56,697 $50,328 13% $56,616 (11%)
========= ========== ==========
* Reflects the % change from 1998 to 1999.
** Reflects the % change from 1997 to 1998.
Gas margin increased $6.4 million, or 13%, and declined $6.3 million, or 11%,
during 1999 and 1998, respectively. The 1999 increase was due to increased
sales resulting from customer growth of approximately 2% and more favorable
weather conditions in 1999. The 1998 decrease was primarily due to a
reduction in sales resulting from milder weather and an average retail rate
reduction of 2.2% implemented in April 1997. Refer to Note 1(i) of Alliant
Energy's "Notes to Consolidated Financial Statements" for discussion of an
accounting change implemented in 1998. Refer to "Interest Expense and Other"
for a discussion of income realized from two gas weather hedges in 1999.
Refer to Note 1(j) of Alliant Energy's "Notes to Consolidated Financial
Statements" for a discussion of a gas cost adjustment mechanism in place at
WP&L. The impact on the results of operations from such mechanism was not
significant in any of the periods presented.
Other Operating Expenses - Other operation expenses decreased $17.2 million
- ------------------------
and increased $12.3 million for 1999 and 1998, respectively. The 1999
decrease was primarily due to $11.2 million of merger-related expenses in 1998
for employee retirements, separations and relocations, reduced
insurance-related expenses, lower operating costs at WP&L's generating plants,
lower transmission and distribution expenses and lower costs due to
merger-related operating efficiencies. Such items were partially offset by
increased costs for energy conservation, employee incentive compensation and
employee benefits expenses. The 1998 increase was primarily due to
merger-related expenses, higher insurance-related expenses and an increase in
other administrative and general expenses. Such items were partially offset
by reduced employee pension and benefits expenses, reduced conservation
expense and lower costs from merger-related operating efficiencies.
Maintenance expenses decreased $4.3 million in 1999. The decrease was
primarily due to lower nuclear expenses and reduced transmission and
distribution maintenance expenses. Such decreases were partially offset by
increased expenses associated with Year 2000 readiness efforts.
40
Depreciation and amortization expense decreased $6.2 million and increased
$14.9 million for 1999 and 1998, respectively. The 1999 decrease was due to
reduced earnings in the nuclear decommissioning trust fund (offset entirely in
"Miscellaneous, net") and the $3.2 million Kewaunee surcharge in 1998. These
items were partially offset by the impact of property additions. The 1998
increase was due to property additions, higher Kewaunee depreciation (refer to
"Liquidity and Capital Resources - Capital Requirements - Nuclear Facilities"
for additional information) and the Kewaunee surcharge.
The accounting for earnings on the nuclear decommissioning trust funds results
in no net income impact. Miscellaneous, net income is increased for earnings
on the trust fund, which is offset in depreciation expense.
Interest Expense and Other - Interest expense increased $4.4 million and $4.0
- --------------------------
million in 1999 and 1998, respectively. The 1999 increase was primarily due
to higher short-term borrowings and the 1998 increase was primarily due to an
adjustment to decrease interest expense in 1997 relating to a tax audit
settlement and increased borrowings during 1998.
Miscellaneous, net income decreased $3.0 million and $2.7 million in 1999 and
1998, respectively. The 1999 decrease was primarily due to lower earnings on
the nuclear decommissioning trust fund, partially offset by $6.1 million of
merger-related expenses in 1998 and pre-tax income of $5 million recognized in
1999 associated with the settlement of gas weather hedges. See Note 11(d) of
the "Notes to Consolidated Financial Statements" for additional information
relating to the gas weather hedges. The 1998 decrease was primarily due to
merger-related expenses, which was partially offset by higher earnings on the
nuclear decommissioning trust fund.
Income Taxes - The effective income tax rates were 39.2%, 41.0% and 37.0% in
- -------------
1999, 1998 and 1997, respectively. See Note 6 of the "Notes to Consolidated
Financial Statements" for a discussion of the changes.
LIQUIDITY AND CAPITAL RESOURCES
Cash flows from operating activities at Alliant Energy decreased $45 million
for the year ended December 31, 1999, compared with the same period in 1998,
primarily due to changes in working capital. Cash flows used for financing
activities decreased $161 million for the year ended December 31, 1999,
compared with the same period in 1998, primarily as a result of changes in the
amount of debt outstanding. Cash flows used for investing activities
increased $39 million for the year ended December 31, 1999, compared with the
same period in 1998, due to increased levels of construction and acquisition
expenditures, which were partially offset by increased proceeds from
dispositions of assets.
Cash flows from operating activities at IESU decreased $44 million for the
year ended December 31, 1999, compared with the same period in 1998, primarily
due to changes in working capital. Cash flows used for financing activities
increased $71 million for the year ended December 31, 1999, compared with the
same period in 1998, due to increased common stock dividends in 1999 as no
dividend payments were made in the last three quarters of 1998 due to
merger-related tax considerations. As a result, the dividend payment in the
first quarter of 1999 was larger than IESU's historical quarterly payment.
Cash flows used for investing activities decreased $6 million for the year
ended December 31, 1999, compared with the same period in 1998, due to
decreased levels of construction expenditures.
Cash flows from operating activities at WP&L decreased $14 million for the
year ended December 31, 1999, compared with the same period in 1998, primarily
due to changes in working capital, partially offset by higher net income.
Cash flows used for financing activities decreased $34 million for the year
ended December 31, 1999, compared with the same period in 1998, primarily due
to a capital contribution of $30 million from Alliant Energy. Cash flows used
for investing activities increased $17 million for the year ended December 31,
1999, compared with the same period in 1998, primarily due to increased
construction expenditures.
Future Considerations
The capital requirements of Alliant Energy are primarily attributable to its
utility subsidiaries' construction and acquisition programs, its debt
maturities and business opportunities of Resources. It is anticipated that
future capital requirements of Alliant Energy will be met by cash generated
from operations, sale of investments and external financing. The level of
cash generated from operations is partially dependent upon economic
41
conditions, legislative activities, environmental matters and timely
regulatory recovery of utility costs. Alliant Energy's liquidity and capital
resources will be affected by costs associated with environmental and
regulatory issues. Emerging competition in the utility industry could also
impact Alliant Energy's liquidity and capital resources, as discussed
previously in the "Utility Industry Outlook" section.
Alliant Energy had certain off-balance sheet financial guarantees and
commitments outstanding at December 31, 1999. They generally consist of
third-party borrowing arrangements and lending commitments, guarantees of
financial performance of syndicated affordable housing properties and
guarantees relating to Alliant Energy's electricity trading joint venture.
Refer to Note 12(d) of the "Notes to Consolidated Financial Statements" for
additional details.
Under PUHCA, certain investments of Alliant Energy in exempt wholesale
generators and foreign utility companies are limited to 50% of Alliant
Energy's consolidated retained earnings. Alliant Energy is pursuing making the
necessary regulatory filings requesting an increase in this limitation. Under
WUHCA, there historically was an asset cap provision that had generally
limited non-utility assets in a utility holding company to 25% of utility
assets. This provision limited Alliant Energy's ability to make additional
investments in its non-utility businesses. The Reliability 2000 legislation
that was enacted in Wisconsin in 1999 provides Wisconsin utility holding
companies significant asset cap relief once they meet certain conditions
relating to the formation of a transmission company, as discussed in the
"Utility Industry Outlook" section. Alliant Energy believes it has met all
such conditions and is now operating under the new law. Under the provisions
of the new law, assets related to the provision of various energy-related,
environmental engineering and telecommunications services are no longer
included in the calculation of either utility or non-utility assets.
Alliant Energy expects to pursue various potential business development
opportunities, including international as well as domestic investments, and is
devoting resources to such efforts. Foreign investments may carry a higher
level of risk than Alliant Energy's traditional domestic utility investments
or Resources' domestic investments. Such risks could include foreign
government actions, foreign economic and currency risks and others. It is
anticipated that Alliant Energy will strive to select investments where the
international and other risks are both understood and manageable. At December
31, 1999, Resources had approximately $198 million of investments in foreign
entities. At December 31, 1999, IESU, WP&L and IPC did not have any foreign
investments.
On February 1, 2000, Resources completed a private placement of exchangeable
senior notes due 2030, which were issued in the original aggregate principal
amount of $402.5 million. The exchangeable senior notes have an interest rate
of 7.25% through February 15, 2003 and 2.5% thereafter. The exchangeable
senior notes are exchangeable for cash based upon a percentage of the value of
McLeod Class A Common Stock. Alliant Energy has agreed to fully and
unconditionally guarantee the payment of principal and interest on the
exchangeable senior notes. The proceeds will be used to repay commercial
paper issued to capitalize Resources' wholly-owned exempt telecommunications
company and, indirectly through an internal transfer of assets, to assist in
funding the recent investment in Brazil, as well as for general corporate
purposes.
The exchangeable senior notes may have certain accounting consequences for
Alliant Energy that may affect reported earnings. As disclosed in Note 10 of
the "Notes to Consolidated Financial Statements," Alliant Energy records its
investment in McLeod stock at its fair value, with changes in fair value, net
of income tax effects, recorded directly to the common equity section of the
Consolidated Balance Sheets as a component of "Accumulated other comprehensive
income." Any such changes in fair value are reflected in current earnings
only at the time they are actually realized through a sale. However,
applicable accounting rules require Alliant Energy to record in its
Consolidated Statements of Income any increase or decrease in the settlement
value (i.e., the amount payable upon maturity) of the exchangeable senior
notes that results from changes in the market value of McLeod stock. The
settlement value of the exchangeable senior notes at any point in time is
generally (assuming no deferrals of interest payments) the higher of: (a) the
original principal amount plus accrued interest less cash dividends or other
distributions on the McLeod stock; or (b) the current market value of the
shares of McLeod stock attributable to the exchangeable senior notes.
Accordingly, any increase or decrease in the settlement value of the
exchangeable senior notes will be recorded as subtractions from, or additions
to, Alliant Energy's reported net income.
42
The market price of the McLeod stock has been volatile and has fluctuated over
a wide range since the initial public offering. A significant increase in the
market value of McLeod stock would significantly decrease Alliant Energy's
reported net income. Similarly, a significant decrease in the market value of
McLeod stock would significantly increase Alliant Energy's reported net
income, subject to the condition that the settlement value of the exchangeable
senior notes will not be reduced below the original principal amount plus
accrued interest less cash dividends or other distributions on the McLeod
stock. These increases and decreases in reported investment income in Alliant
Energy's Consolidated Statements of Income will be non-cash in nature and will
be reflected on Alliant Energy's Consolidated Balance Sheets as increases and
decreases in long-term debt. Alliant Energy would recognize a non-cash charge
to net income of approximately $3.3 million for each $1/share increase in
McLeod's stock price above $77.23/share as relates to the 5.2 million shares
of McLeod stock attributable to the exchangeable senior notes. This impact on
earnings will be mitigated somewhat once Alliant Energy adopts SFAS 133,
"Accounting for Derivative Instruments and Hedging Activities," as discussed
further below.
Alliant Energy may choose to adopt SFAS 133 early. See "Other Matters -
Accounting Pronouncements" for additional information relating to SFAS 133.
SFAS 133 will require Alliant Energy to split the value of the exchangeable
senior notes into a debt component and a derivative component. Any changes in
the fair value of the derivative component subsequent to the SFAS 133 adoption
date will be reflected as an increase or decrease in Alliant Energy's reported
net income. At the date of initial adoption, SFAS 133 provides Alliant Energy
a one-time ability to transfer any of Alliant Energy's available-for-sale
securities, including a portion of its shares of McLeod stock, to the trading
category. At the date of any such transfer from available-for-sale to
trading, Alliant Energy would recognize in income the appreciation in the
shares transferred. Although Alliant Energy is not required to hold a number
of shares of McLeod stock equal to the number of exchangeable senior notes
outstanding, if Alliant Energy does so and if Alliant Energy elects to make
this transfer from available-for-sale to trading, changes subsequent to the
SFAS 133 adoption date in the fair value of the shares of McLeod stock so
transferred will be reflected as an increase or decrease in Alliant Energy's
reported net income. Changes in the market value of the McLeod stock are
expected to at least partially offset changes in the fair value of the
derivative component of the exchangeable senior notes; however, there may be
periods with significant non-cash increases or decreases to Alliant Energy's
net income pertaining to the exchangeable senior notes and the related shares
of McLeod stock.
On January 25, 2000, Resources acquired a stake in four Brazilian electric
utilities serving more than 820,000 customers for a total investment of
approximately $347 million. As part of this investment, Resources acquired a
49.1% ownership interest in Companhia Forca e Luz Cataguazes-Leopoldina
(Cataguazes), an electric utility. Cataguazes owns a majority stake in CENF,
another electric utility company, as well as a majority interest in Energisa
S.A., an energy development company. As part of the same investment,
Resources directly acquired a 45.6% interest in Energisa S.A. itself, which
holds majority stakes in two regulated utilities (Energipe and Celb). As part
owner of Cataguazes, Resources will hold both indirect and direct interests in
Energisa S.A. The investment is anticipated to dilute Alliant Energy's
earnings per share by approximately 3% in 2000, with positive contributions to
earnings expected in subsequent years. Resources, through its wholly owned
subsidiary, International, initially financed the Brazil investment with cash
made available through the internal transfer of existing non-regulated
corporate assets. Resources has entered into a shareholders agreement with
the Brazilian companies, which would allow it to name two directors to the
boards of each company and its subsidiaries. The agreement will also provide
Resources with a role in selecting each company's management team, along with
voting rights relating to critical issues at the Brazilian companies and their
subsidiaries. The investment will be accounted for under the equity method.
Alliant Energy entered into an agreement in November 1998, as amended, with
McLeod whereby Alliant Energy's ability to sell the McLeod stock is subject to
various restrictions. The agreement provides that until December 31, 2001,
Alliant Energy and its affiliates generally may not sell or otherwise dispose
of shares of McLeod stock beneficially owned by Alliant Energy and its
affiliates, other than to a subsidiary of Alliant Energy, without the prior
written consent of the Board of Directors of McLeod. However, the amended
agreement provides that the Board of Directors of McLeod may permit Alliant
Energy and its affiliates to sell a specified number of shares of McLeod stock
per quarter during specified time periods. In addition, if Alliant Energy and
its affiliates are not provided the opportunity to sell, on an annual basis,
an aggregate number of shares of McLeod stock equal to 15% of the shares of
McLeod stock owned by Alliant Energy and its affiliates as of December 31,
1998, then Alliant Energy may terminate the amended November 1998 agreement.
43
In the first quarter of 2000, the Alliant Energy Board of Directors approved a
draft Agreement and Plan of Merger to merge IESU and IPC. The new company
will be named Interstate Power and Light Company and it is anticipated the
merger will be completed by late 2000 or early 2001. Alliant Energy expects
to be able to achieve cost savings and enhanced customer service from the
merger.
Financing and Capital Structure
Access to the long-term and short-term capital and credit markets, and costs
of external financing, are dependent on creditworthiness. The debt ratings of
Alliant Energy and certain subsidiaries by Moody's and Standard & Poor's are
as follows:
Moody's Standard & Poor's
----------------- -------------------
IESU - Secured long-term debt A2 A+
- Unsecured long-term debt A3 A
WP&L - Secured long-term debt Aa2 AA
- Unsecured long-term debt Aa3 A+
IPC - Secured long-term debt A1 A+
Resources - Commercial paper (a) P1 A1
- Unsecured long-term debt (a) A3 A
Alliant Energy - Commercial paper (b) P1 A1
(a) Resources' debt is fully and unconditionally guaranteed by Alliant Energy.
(b) IESU, WP&L and IPC participate in a utility money pool that is funded,
as needed, through the issuance of commercial paper by Alliant Energy.
Interest expense and other fees are allocated based on borrowing amounts.
The PSCW has restricted WP&L from lending money to non-utility affiliates
and non-Wisconsin utilities. As a result, WP&L is prohibited from lending
money to the utility money pool but is able to borrow money from the
utility money pool.
On November 9, 1999, Resources issued $250 million of 7-3/8% senior notes due
2009 in a private placement. The notes are fully and unconditionally
guaranteed by Alliant Energy. The net proceeds from the debt offering have
been used to repay outstanding commercial paper, as it becomes due, that has
been backed by Resources' 3-Year Credit Agreement.
Other than periodic sinking fund requirements, which will not require
additional cash expenditures, the following long-term debt (in millions) will
mature prior to December 31, 2004:
IESU WP&L Alliant Energy-Parent Resources IPC Total
- ---------------------------------------------------------------------------
$137.4 $63.9 $24.0 $12.6 $1.0 $238.9
Depending upon market conditions, it is currently anticipated that a majority
of the maturing debt will be refinanced with the issuance of long-term
securities.
On August 24, 1999, WP&L filed an application with the PSCW for authority to
issue up to $100 million of debentures for the purpose of refinancing existing
debt. Approval was granted in February 2000 and the senior unsecured
debentures were issued in March 2000 at a fixed interest rate of 7-5/8%, due
2010. The amount of short-term borrowings authorized by the PSCW will be
reduced by the same $100 million.
On November 25, 1998, IESU and IPC received authority from the SEC under PUHCA
to issue $200 million and $80 million of long-term debt securities,
respectively. The companies continually evaluate their future financing needs
and will make any necessary regulatory filings as needed.
The various charter provisions of the entities identified below authorize and
limit the aggregate amount of additional shares of Cumulative Preferred Stock
and Cumulative Preference Stock that may be issued. At December 31, 1999, the
companies could have issued the following additional shares of Cumulative
Preferred or Preference Stock:
IESU WP&L IPC
-----------------------------------
Cumulative Preferred 100,000 2,700,775 1,238,619
Cumulative Preference 700,000 -- 2,000,000
44
For interim financing, IESU, WP&L and IPC were authorized by the applicable
federal or state regulatory agency to issue short-term debt at December 31,
1999 as follows (in millions):
IESU WP&L IPC
-----------------------------
Regulatory authorization $150 $128 $50
Short-term debt outstanding - money pool $57 $126 $39
At December 31, 1999, there was no short-term debt outstanding with external
parties at the utility subsidiaries. In addition to the $222 million of
commercial paper Alliant Energy issued to fund the utility money pool and $139
million of commercial paper at Resources, Alliant Energy had an additional $64
million of short-term debt outstanding at December 31, 1999. In addition to
providing for ongoing working capital needs, this availability of short-term
financing provides the companies flexibility in the issuance of long-term
securities. The level of short-term borrowing fluctuates based on seasonal
corporate needs, the timing of long-term financing and capital market
conditions. To maintain flexibility in its capital structure and to take
advantage of favorable short-term rates, IESU and WP&L also use proceeds from
the sale of accounts receivable and unbilled revenues to finance a portion of
their long-term cash needs. Alliant Energy anticipates that short-term debt
will continue to be available at reasonable costs due to current ratings by
independent utility analysts and credit rating services.
In December 1999, Alliant Energy, IESU, WP&L and IPC filed an application with
the SEC for approval of a combined accounts receivable program whereby each
utility will sell their respective receivables through wholly-owned special
purpose entities to an affiliated financing entity, which in turn will sell
the receivables to an outside investor. The new program would replace the
existing programs for IESU and WP&L, and would function the same in most
respects. Approvals from the SEC and the necessary state commissions are
expected in the second quarter of 2000.
Resources is a party to a revolving 3-Year Credit Agreement with various
banking institutions. The agreement extends through October 2000, with
one-year extensions available upon agreement by the parties. Unused borrowing
availability under this agreement is also used to support Resources'
commercial paper program. A combined maximum of $450 million of borrowings
under this agreement and the commercial paper program may be outstanding at
any one time. Interest rates and maturities are set at the time of
borrowing. The rates are based upon quoted market prices and the maturities
are less than one year. At December 31, 1999, Resources had $139 million of
commercial paper outstanding and backed by its 3-Year Credit Agreement with
discount rates ranging from 5.90%-6.32%. Resources intends to continue
issuing commercial paper backed by this facility, and no conditions existed at
December 31, 1999, that would prevent the issuance of commercial paper or
direct borrowings on its bank lines. As a result, Alliant Energy had been
classifying this debt as long-term. However, since this agreement expires in
October 2000, beginning in October 1999 this debt (including commercial paper
backed by this facility) was classified as short-term.
In October 1999, Resources extended its revolving 364-Day Credit Agreement
with various banking institutions through October 2000. The unborrowed
portion of this agreement is also used to support Resources' commercial paper
program. A combined maximum of $150 million of borrowings under this
agreement and commercial paper backed by this facility may be outstanding at
any one time. Interest rates and maturities are set at the time of
borrowing. The rates are based upon quoted market prices and the maturities
are less than one year. There were no borrowings outstanding under this
facility at December 31, 1999 and no conditions existed that would prevent the
issuance of commercial paper or direct borrowings under this agreement.
In addition to the aforementioned borrowing capability under Resources' credit
agreements, Alliant Energy has $250 million of committed bank lines of credit,
of which none was utilized at December 31, 1999, available for direct
borrowing or to support commercial paper. Commitment fees are paid to
maintain these lines and there are no conditions which restrict the unused
lines of credit. From time to time, Alliant Energy may borrow from banks and
other financial institutions on uncommitted "as-offered" credit lines in lieu
of commercial paper, and has agreements with several financial institutions
for such borrowings. There are no commitment fees associated with these
agreements and there were no borrowings outstanding under these agreements at
December 31, 1999.
45
Alliant Energy made a filing with the SEC in February 1999 under PUHCA to
provide Alliant Energy with, among other things, broad authorization over the
next three years to issue stock and debt, provide guarantees, acquire
energy-related assets and enter into interest rate hedging transactions.
Approval of the filing was received from the SEC in August 1999.
Given the above financing flexibility, including Alliant Energy's access to
both the debt and equity securities markets, management believes it has the
necessary financing capabilities in place to adequately finance its capital
requirements for the foreseeable future.
Capital Requirements
General - Capital expenditure and investment and financing plans are subject
- -------
to continual review and change. The capital expenditure and investment
programs may be revised significantly as a result of many considerations,
including changes in economic conditions, variations in actual sales and load
growth compared to forecasts, requirements of environmental, nuclear and other
regulatory authorities, acquisition and business combination opportunities,
the availability of alternate energy and purchased-power sources, the ability
to obtain adequate and timely rate relief, escalations in construction costs
and conservation and energy efficiency programs.
Construction and acquisition expenditures for Alliant Energy for the year
ended December 31, 1999 and 1998 were $479 million and $372 million,
respectively. Alliant Energy's anticipated construction and acquisition
expenditures for 2000 are estimated to be approximately $939 million,
consisting of approximately $484 million for energy-related international
investments, $319 million in its utility operations and $136 million for new
business development initiatives at Resources. The significant increase in
construction and acquisition expenditures in international investments relates
to Resources' recent investment in Brazil. See "Liquidity and Capital
Resources - Future Considerations" for information relating to the Brazil
investment. Alliant Energy's anticipated utility construction and acquisition
expenditures for 2000 is made up of 46% for electric transmission and
distribution, 23% for electric generation, 17% for information technology and
14% for miscellaneous electric, gas, water and steam projects. The level of
2000 domestic and international investments could vary significantly from the
estimates noted here depending on actual investment opportunities, timing of
the opportunities and the receipt of regulatory approvals to exceed
limitations in place under PUHCA. It is expected that Alliant Energy will
spend approximately $1.4 billion on utility construction and acquisition
expenditures during 2001-2004, including expenditures to comply with NOx
emissions reductions in Wisconsin as discussed in "Other Matters -
Environmental." It is expected that Resources will invest in energy products
and services in domestic and international markets, industrial services
initiatives and other strategic initiatives during 2001-2004.
IESU's construction and acquisition expenditures for the years ended December
31, 1999 and 1998 were $107 million and $115 million, respectively. IESU's
anticipated construction and acquisition expenditures for 2000 are estimated
to be approximately $115 million, of which 45% is for electric transmission
and distribution, 26% for electric generation, 15% for information technology
and the remaining 14% represents miscellaneous electric, gas, steam and
general expenditures. IESU's levels of utility construction and acquisition
expenditures are projected to be $127 million in 2001, $117 million in 2002,
$118 million in 2003 and $123 million in 2004.
WP&L's construction and acquisition expenditures for the years ended December
31, 1999 and 1998 were $132 million and $117 million, respectively. WP&L's
anticipated construction and acquisition expenditures for 2000 are estimated
to be approximately $143 million, of which 45% is for electric transmission
and distribution, 25% for electric generation, 15% for information technology
and the remaining 15% represents miscellaneous electric, gas, water and
general expenditures. WP&L's construction and acquisition expenditures are
projected to be $166 million in 2001, $181 million in 2002, $192 million in
2003 and $136 million in 2004, which include expenditures to comply with NOx
emissions reductions as discussed in "Other Matters - Environmental."
Alliant Energy anticipates financing utility construction expenditures during
2000-2004 through internally generated funds supplemented, when required, by
outside financing. Funding of Resources' construction and acquisition
expenditures over that same period of time is expected to be completed with a
combination of external financings, sales of investments and internally
generated funds.
46
Nuclear Facilities - Alliant Energy owns interests in two nuclear facilities,
- --------------------
Kewaunee and DAEC. Kewaunee, a 532 MW pressurized water reactor plant, is
operated by WPSC and is jointly owned by WPSC (41.2%), WP&L (41.0%), and MG&E
(17.8%). The Kewaunee operating license expires in 2013. DAEC, a 535 MW
boiling water reactor plant, is operated by IESU which has a 70% ownership
interest in the plant. The DAEC operating license expires in 2014.
On April 7, 1998, the PSCW approved WPSC's application for replacement of the
two steam generators at Kewaunee. The total cost of replacing the steam
generators will be approximately $90.7 million, with WP&L's share of the cost
being approximately $37.2 million. The replacement work originally planned
for the spring of 2000 is now scheduled for the fall of 2001 and will take
approximately 60 days. The delay is attributable to the inability of the
steam generator manufacturer to meet the spring 2000 delivery schedule.
Delays in meeting the delivery schedule did not allow for steam generator
replacement to occur prior to the start of the summer weather in 2000.
Therefore, the decision was made to store the steam generators after they are
received and wait until the next scheduled refueling outage in the fall of
2001. It is anticipated that the delay will not adversely impact the
reliability of Kewaunee in the interim. Plans to shutdown the plant for a
spring 2000 refueling remain unchanged.
On July 2, 1998, the PSCW approved an agreement between the owners of Kewaunee
which provides for WPSC to assume the 17.8% Kewaunee ownership share currently
held by MG&E prior to work beginning on the replacement of steam generators.
On September 29, 1998, WPSC and MG&E finalized an arrangement in which WPSC
will acquire MG&E's 17.8% share of Kewaunee. This agreement, the closing of
which is contingent upon regulatory approval and the steam generator
replacement in the fall of 2001, will give WPSC 59.0% ownership in Kewaunee.
After the change in ownership, WPSC and WP&L will be responsible for the
decommissioning of the plant. WPSC and WP&L are discussing revisions to the
joint power supply agreement which will govern operation of the plant after
the ownership change takes place. Prior to the July 2, 1998 PSCW decision,
the PSCW had directed the owners of Kewaunee to record depreciation and
decommissioning cost levels based on an expected plant end-of-life of 2002
versus a license end-of-life of 2013. This was prompted by the uncertainty
regarding the expected useful life of the plant without steam generator
replacement. This level of depreciation will remain in effect until the steam
generator replacement is completed at which time the entire plant will be
depreciated over 8.5 years using an accelerated method.
In February 1999, Alliant Energy, NSP, WPSC and WEPCO announced the formation
of the NMC to sustain long-term safety, optimize reliability and improve the
operational performance of their nuclear generating plants. Combined, the NMC
members operate seven nuclear generating units at five plants. In October
1999, Alliant Energy received approval from the SEC, under PUHCA, to form
Alliant Energy Nuclear LLC, whose purpose is solely to invest in the NMC.
Such investment has been made and Alliant Energy Nuclear LLC now has a 25%
ownership interest in the NMC. In November 1999, the NMC members applied to
the NRC to allow the NMC to operate the plants owned or co-owned by the four
utilities. Applications to the PSCW, MPUC and the SEC to allow the purchase
of operating services were also made at that time. These approvals are
required if the applicable utilities choose to transfer their operating
license to, and take operating services from, the NMC. As presently proposed,
the NMC would operate the plants, but the utilities would continue to own
their plants, be entitled to energy generated at the plants and retain the
financial obligations for the safe operation, maintenance and decommissioning
of the plants.
For additional information related to Kewaunee and DAEC, see Notes 1, 3, 10,
12 and 13 of the "Notes to Consolidated Financial Statements." Refer to the
"Other Matters - Environmental" section for a discussion of various issues
impacting Alliant Energy's future capital requirements.
Rates and Regulatory Matters
FERC - In November 1997, as part of its merger approval, FERC accepted a
- ------
proposal by IESU, WP&L, and IPC, which provides for a four-year freeze on
wholesale electric prices beginning with the effective date of the merger.
In association with the merger, IESU, WP&L and IPC entered into a System
Coordination and Operating Agreement which became effective with the
consummation of the merger. The agreement, which has been approved by the
FERC, provides a contractual basis for coordinated planning, construction,
operation and maintenance of the interconnected electric generation and
47
transmission systems of the three utility companies. In addition, the
agreement allows the interconnected system to be operated as a single control
area with off-system capacity sales and purchases made to market excess system
capability or to meet system capability deficiencies. Such sales and
purchases are allocated among the three utility companies based on procedures
included in the agreement. The procedures were approved by both the FERC and
all state regulatory bodies having jurisdiction over these sales.
IESU - In September 1997, IESU agreed with the IUB to provide Iowa customers a
- ----
four-year retail electric and gas price freeze commencing on the effective
date of the merger. The agreement excluded price changes due to
government-mandated programs (such as energy efficiency cost recovery), the
electric fuel adjustment clause and PGA clause and unforeseen dramatic changes
in operations. In addition, the price freeze does not preclude a review by
either the IUB or OCA into whether IESU is exceeding a reasonable return on
common equity. Refer to the "Utility Industry Outlook" section for a
discussion of legislation introduced in Iowa regarding restructuring the
electric utility industry.
In the first quarter of 2000, the OCA requested certain financial information
related to the electric utility operations within the state of Iowa for IESU.
IESU is in the process of preparing responses to the data requests. While
IESU cannot predict the outcome of this process, such data requests could lead
to an effort by the OCA to seek an electric rate reduction for IESU in Iowa.
IESU has received similar requests from the OCA in the past.
Under provisions of the IUB rules, IESU is currently recovering the costs it
has incurred for its energy efficiency programs. Generally, the costs
incurred through July 1997 are being recovered over various four-year
periods. Statutory changes implemented by the IUB in 1997 allowed IESU to
begin concurrent recovery of its prospective expenditures on August 1, 1997.
The implementation of these changes will gradually eliminate the regulatory
asset that was created under the prior rate making mechanism as these costs
are recovered.
WP&L - In connection with its approval of the merger, the PSCW accepted a WP&L
- ----
proposal to freeze rates for four years commencing on the effective date of
the merger. A re-opening of an investigation into WP&L's rates during the
rate freeze period, for both cost increases and decreases, may occur only for
single events that are not merger-related and have a revenue requirement
impact of $4.5 million or more. In addition, the electric fuel adjustment
clause and PGA clause are not affected by the rate freezes.
In February 2000, the PSCW issued an order allowing WP&L to defer certain
incremental costs it incurs after February 16, 2000 relating to the development
of the ATC.
The retail electric rates are based in part on forecasted fuel and
purchased-power costs. Under PSCW rules, Wisconsin utilities can seek
emergency rate increases if the annual costs are more than 3% higher than the
estimated costs used to establish rates. In March 1998, WP&L requested an
electric rate increase to cover purchased-power and transmission costs that
had increased due to transmission constraints and electric reliability
concerns in the Midwest. Effective July 16, 1998, the PSCW granted a retail
electric rate increase of $14.8 million annually. In November 1998, WP&L
requested an electric rate increase to cover additional increases in
purchased-power and transmission costs. In early March 1999, the PSCW granted
a retail electric rate increase of $14.5 million annually. If WP&L's earnings
exceed its authorized return on equity, the incremental revenues collected
causing the excessive return are subject to refund. In December 1999, WP&L
requested a $26 million retail electric rate increase to reflect higher
purchased power costs and to cover transmission costs that have increased due
to transmission constraints. While the most current request is still pending,
WP&L anticipates receiving an order in the second quarter of 2000.
In May 1998, the PSCW approved the deferral by WP&L of certain costs
associated with its Year 2000 program. In November 1998, WP&L filed for rate
recovery of the Wisconsin retail portion of its Year 2000 costs. In
accordance with the order received from the PSCW, WP&L began deferring its
Year 2000 project costs, other than internal labor and associated overheads.
In November 1999, the PSCW allowed WP&L rate recovery of $6.3 million of its
Year 2000 program expenditures, but it denied rate recovery of the first $4.5
million. These costs were expensed in 1999. The PSCW's decision has been
appealed by certain intervenors in Dane County district court and such appeal
is pending.
48
In January 1999, WP&L made a filing with the PSCW proposing to begin
deferring, on January 1, 1999, all costs associated with the EPA's required
NOx emission reductions. In connection with a statewide docket to investigate
compliance issues associated with the EPA's NOx emission reductions, on March
30, 1999, the PSCW authorized deferral of all non-labor related costs incurred
after March 30, 1999. However, the utilities are not allowed to defer costs
of replacement power associated with NOx compliance. WP&L requested expedited
approval to start construction of NOx reduction investments at several
generating units operated by WP&L and in the third quarter of 1999 received
approval from the PSCW for limited NOx related expenditures at one of its
generating units. WP&L has also requested recovery of all the NOx reduction
costs through a surcharge mechanism. In March 2000, the PSCW issued an order
approving WP&L's NOx compliance plans and granted the recovery of costs
incurred to comply with EPA NOx regulations over ten years using a
straight-line depreciation method. Recovery of such costs will begin with
rate changes after the rate freeze expires. The depreciation lives will be
reviewed every two years. Refer to the "Other Matters - Environmental"
section for a further discussion of the NOx issue.
In rate order UR-110, the PSCW approved new rates effective April 29, 1997.
On average, WP&L's retail electric rates under the new rate order declined by
2.4% and retail gas rates declined by 2.2%.
Refer to "Capital Requirements - Nuclear Facilities" for a discussion of
several PSCW rulings regarding Kewaunee.
IPC - In September 1997, IPC agreed with the IUB to provide Iowa customers a
- ---
four-year retail electric and gas price freeze commencing on the effective
date of the merger. The agreement excluded price changes due to
government-mandated programs (such as energy efficiency cost recovery), the
electric fuel adjustment clause and PGA clause and unforeseen dramatic changes
in operations. In addition, the price freeze does not preclude a review by
either the IUB or OCA into whether IPC is exceeding a reasonable return on
common equity. IPC also agreed with the MPUC and ICC to four-year and
three-year rate freezes, respectively, commencing on the effective date of the
merger. Refer to the "Utility Industry Outlook" section for a discussion of
legislation introduced in Iowa regarding restructuring the electric utility
industry.
IPC is also recovering its energy efficiency costs in Iowa in a similar manner
as IESU and began its concurrent cost recovery in October 1997.
Assuming capture of the merger-related synergies and no significant
legislative or regulatory changes negatively affecting its utility
subsidiaries, Alliant Energy does not expect the merger-related electric and
gas price freezes to have a material adverse effect on its financial condition
or results of operations.
OTHER MATTERS
Year 2000
Alliant Energy had no significant embedded equipment, computer system or other
malfunctions during the critical December 31, 1999 to January 1, 2000 date
rollover or the February 28, 2000 to February 29, 2000 date rollover. Alliant
Energy will continue to monitor for any supply chain issues into the second
quarter of 2000.
Alliant Energy's historical Year 2000 project expenditures were as follows
(incremental costs, in millions):
Description Total IESU WP&L Other
- -------------------------------------------- ------------- ----------- ----------- ------------
Costs incurred from 1/1/98 - 12/31/98 $8.7 $4.8 $3.2 $0.7
Costs incurred from 1/1/99 - 12/31/99 18.6 7.6 7.1 3.9
------------- ----------- ----------- ------------
Total $27.3 $12.4 $10.3 $4.6
============= =========== =========== ============
In addition, Alliant Energy estimates it incurred $7 million and $3 million in
1999 and 1998, respectively, of costs for internal labor and associated
overheads. Alliant Energy does not expect to incur any significant
incremental costs in 2000 on its Year 2000 readiness program. Refer to
"Liquidity and Capital Resources - Rates and Regulatory Matters" for a
discussion of the filing WP&L made with the PSCW for rate recovery of a
portion of its Year 2000 program costs.
49
Labor Issues
The status of the collective bargaining agreements at each of the utilities at
December 31, 1999 was as follows:
IESU WP&L IPC
----------------------
Number of collective bargaining agreements 6 1 3
Percentage of workforce covered by agreements 61% 93% 83%
The collective bargaining agreements at Alliant Energy cover approximately 51%
of all Alliant Energy employees. In 1999, eight agreements expired and four
of these agreements have been ratified and four are still being negotiated
(three at IPC and one at IESU). The agreements still being negotiated have
been extended and represent 42% of employees covered under bargaining
agreements and 22% of total Alliant Energy employees. In 2000, two contracts
expire representing approximately 1% of employees covered under bargaining
agreements and less than 1% of total Alliant Energy employees. Alliant Energy
has not experienced any significant work stoppage problems in the past. While
negotiations are continuing, Alliant Energy is currently unable to predict the
outcome of these negotiations.
Market Risk Sensitive Instruments and Positions
Alliant Energy's primary market risk exposures are associated with interest
rates, commodity prices, equity prices and currency exchange rates. Alliant
Energy has risk management policies to monitor and assist in controlling these
market risks and uses derivative instruments to manage some of the exposures.
Interest Rate Risk - Alliant Energy is exposed to risk resulting from changes
- ------------------
in interest rates as a result of its issuance of variable-rate debt. Alliant
Energy manages its interest rate risk by limiting its variable interest rate
exposure and by continuously monitoring the effects of market changes in
interest rates. Alliant Energy has also historically used interest rate swap
and interest rate forward agreements to assist in the management of its
interest exposure. If variable interest rates were to average 1% higher
(lower) in 2000 than in 1999, interest expense and pre-tax earnings would
increase (decrease) by approximately $5.1 million. Comparatively, if variable
interest rates had averaged 1% higher (lower) in 1999 than in 1998, interest
expense and pre-tax earnings would have increased (decreased) by approximately
$4.5 million. These amounts were determined by considering the impact of a
hypothetical 1% increase (decrease) in interest rates on the variable-rate
debt and related derivative instruments held by Alliant Energy as of December
31, 1999 and 1998. In the event of significant interest rate fluctuations,
management would take actions to minimize the effect of such changes on
Alliant Energy's results of operations. However, due to the uncertainty of
the specific actions that would be taken and their possible effects, the
sensitivity analysis assumes no change in Alliant Energy's financial structure.
Commodity Risk - Non-trading - Alliant Energy is exposed to the impact of
- ----------------------------
market fluctuations in the commodity price and transportation costs of
electricity, natural gas and oil products it markets. Alliant Energy employs
established policies and procedures to manage its risks associated with these
market fluctuations including the use of various commodity derivatives.
Alliant Energy's exposure to commodity price risks in its utility business is
significantly mitigated by the current rate making structures in place for the
recovery of its electric fuel and purchased energy costs as well as its cost
of natural gas purchased for resale. Refer to Note 1(j) of the "Notes to
Consolidated Financial Statements" for a further discussion.
From time to time, WP&L utilizes gas commodity swap arrangements for the
purpose of mitigating the impact of price fluctuations on gas purchased and
injected into storage during the summer months and withdrawn and sold at
current prices during the winter months. The gas commodity swaps in place
approximate the forecasted storage withdrawal plan during this period.
Therefore, market price fluctuations that result in an increase or decrease in
the value of the physical commodity are offset by changes in the value of the
gas commodity swaps. A 10% increase/decrease in the price of gas would have
an insignificant impact on the combined fair market value of the gas in
storage and related swap arrangements in place as of December 31, 1999 and
1998.
Whiting is exposed to market risk in the pricing of its oil and gas
production. Historically, prices received for oil and gas production have
been volatile because of seasonal weather patterns, supply and demand factors,
transportation availability and price, and general economic conditions.
50
Worldwide political developments have historically also had an impact on oil
prices. Periodically, Alliant Energy utilizes oil and gas swaps and forward
contracts to mitigate the impact of oil and gas price fluctuations. Based on
Whiting's estimated gas and crude oil sales in 2000, and the swaps and forward
contracts in place at December 31, 1999, a 10% increase/decrease in gas and
crude oil prices for that period would impact Alliant Energy's pre-tax 2000
earnings by approximately $3.8 million. A 10% increase/decrease in prices
during 1999 would have impacted Alliant Energy's 1999 pre-tax earnings by
approximately $3.0 million as relates to the commodity derivative instruments
outstanding during 1999.
Commodity Risk - Trading - Alliant Energy is exposed to market risks through
- --------------
its electricity commodity trading business, which is primarily conducted
through Alliant Energy's 50/50 joint venture with Cargill. The joint
venture's trading activities principally consist of marketing and trading
over-the-counter forward contracts for the purchase and sale of electricity.
The majority of the forward contracts represent commitments to purchase or
sell electricity at fixed prices in the future and require settlement by
physical delivery of electricity or are netted out in accordance with industry
trading standards. The market prices used to determine fair values reflect
the joint ventures' best estimate considering various factors, including
closing exchanges and over-the-counter quotations, time value and volatility
factors. The joint venture manages the market risks inherent in its trading
activities through established trading and risk management policies and
tools. The principal tool utilized is a one-day variance/covariance
value-at-risk model with assessment adjustments made based on weather,
transmission availability, generation outages and other factors. The
estimated one-day market Value at Risk (VAR) for the joint venture as of
December 31, 1999 and 1998 was $0.3 million and $0.7 million, respectively,
which were calculated with a 99% confidence level. The low, average and high
VAR in 1999 were $0.1 million, $0.3 million and $1.5 million, respectively.
Equity Price Risk - Alliant Energy maintains trust funds at IESU and WP&L to
- -----------------
fund its anticipated nuclear decommissioning costs. As of December 31, 1999
and 1998, these funds were invested primarily in domestic equity and debt
instruments. WP&L has entered into an equity collar that uses options to
mitigate the effect of significant market fluctuations on its common stock
investments. Alliant Energy's exposure to fluctuations in equity prices or
interest rates will not affect its consolidated results of operations as such
fluctuations are recorded in equally offsetting amounts of investment income
and depreciation (WP&L) or interest (IESU) expense when they are realized.
At December 31, 1999 and 1998, Alliant Energy had an investment in the stock
of McLeod, a publicly traded telecommunications company, valued at $1,124
million and $320 million, respectively. A 10% increase (decrease) in the
quoted market price at December 31 would have increased (decreased) the value
of the investment at December 31, 1999 and 1998 by approximately $112 million
and $32 million, respectively. Refer to Note 10 of the "Notes to Consolidated
Financial Statements" for a discussion of how Alliant Energy accounts for its
investment in McLeod.
At December 31, 1999 and 1998, Alliant Energy had various investments,
accounted for under the cost method of accounting, in publicly traded utility
companies in New Zealand and Australia which were valued at $97 million and $3
million, respectively. A 10% increase (decrease) in the quoted market prices
at December 31 would have increased (decreased) the value of the investment at
December 31, 1999 and 1998 by approximately $9.7 million and $0.3 million,
respectively.
Currency Risk - Alliant Energy has investments in various countries where the
- --------------
net investments are not hedged, including Australia, Brazil, China, New
Zealand, and Singapore. As a result, these investments are subject to
currency exchange risk with fluctuations in currency exchange rates. At
December 31, 1999 and 1998, Alliant Energy had a cumulative foreign currency
translation loss of $9.6 million and $7.1 million, respectively, recorded in
"Accumulated other comprehensive income" on its Consolidated Balance Sheets
that primarily related to decreases in value of the New Zealand dollar in
relation to the U.S. Dollar. Based on Alliant Energy's investments at
December 31, 1999 and 1998, a 10% sustained increase/decrease over the next
twelve months in the foreign exchange rates of Australia, Brazil, China, New
Zealand and Singapore would decrease/increase the cumulative foreign currency
translation loss by $17.2 million and $6.4 million, respectively.
Refer to Notes 1(n) and 11 of the "Notes to Consolidated Financial Statements"
for a further discussion of Alliant Energy's derivative financial instruments.
51
Accounting Pronouncements
In June 1998, the FASB issued SFAS 133. The Statement establishes accounting
and reporting standards requiring that every derivative instrument be recorded
on the balance sheet as either an asset or liability measured at its fair
value. The Statement requires that changes in the derivative's fair value be
recognized currently in earnings unless specific hedge accounting criteria are
met. Special accounting for qualifying hedges allows a derivative's gains and
losses to offset related results on the hedged item in the income statement,
and requires that a company must formally document, designate, and assess the
effectiveness of transactions that receive hedge accounting.
SFAS 133 is effective for fiscal years beginning after June 15, 2000 and must
be applied to (a) derivative instruments and (b) certain derivative
instruments embedded in hybrid contracts that were issued, acquired or
substantively modified after December 31, 1998 (effective dates noted are as
amended by SFAS 137). Alliant Energy has organized a cross-functional project
team to assist in implementing SFAS 133. The team consists of both Alliant
Energy employees and a consultant that has been engaged to support the
project. The team has begun to inventory financial instruments, commodity
contracts and other commitments with the purpose of identifying and assessing
all of Alliant Energy's derivatives. Although the impact of implementing SFAS
133 has not yet been quantified, it could increase volatility in earnings and
other comprehensive income. Alliant Energy is analyzing various alternatives
relating to the possible early adoption of SFAS 133 in 2000. SFAS 133 may
only be adopted on the first day of any quarter prior to the required adoption
date.
Accounting for Obligations Associated with the Retirement of Long-Lived Assets
The staff of the SEC has questioned certain of the current accounting
practices of the electric utility industry, including IESU and WP&L, regarding
the recognition, measurement and classification of decommissioning costs for
nuclear generating stations in financial statements of electric utilities. In
response to these questions, the FASB has a project on its agenda to review
the accounting for obligations associated with the retirement of long-lived
assets, including decommissioning of nuclear power plants. If current
electric utility industry accounting practices for nuclear power plant
decommissioning are changed, the annual provision for decommissioning could
increase relative to 1999, and the estimated cost for decommissioning could be
recorded as a liability (rather than as accumulated depreciation), with
recognition of an increase in the cost of the related nuclear power plant.
Assuming no significant change in regulatory treatment, IESU and WP&L do not
believe that such changes, if required, would have an adverse effect on their
financial condition or results of operations due to their ability to recover
decommissioning costs through rates.
Inflation
Alliant Energy, IESU and WP&L do not expect the effects of inflation at
current levels to have a significant effect on their financial condition or
results of operations.
Environmental
The pollution abatement programs of IESU, WP&L, IPC and Resources are subject
to continuing review and are revised from time to time due to changes in
environmental regulations, changes in construction plans and escalation of
construction costs. While management cannot precisely forecast the effect of
future environmental regulations on Alliant Energy's operations, it has taken
steps to anticipate the future while also meeting the requirements of current
environmental regulations.
The Clean Air Act Amendments of 1990 (Act) require emission reductions of SO2,
NOx and other air pollutants to achieve reductions of atmospheric chemicals
believed to cause acid rain. IESU, WP&L and IPC have met the provisions of
Phase I of the Act and Phase II of the Act. The Act also governs SO2
allowances, which are defined as an authorization for an owner to emit one ton
of SO2 into the atmosphere. IESU, WP&L and IPC are reviewing their options to
ensure they will have sufficient allowances to offset their emissions in the
future and believe that the potential costs of complying with these provisions
of Title IV of the Act will not have a material adverse impact on their
financial condition or results of operations.
The Act and other federal laws also require the EPA to study and regulate, if
necessary, additional issues that potentially affect the electric utility
industry, including emissions relating to ozone transport, mercury and
particulate control as well as modifications to the PCB rules. In July 1997,
52
the EPA issued final rules that would tighten the National Ambient Air Quality
Standards for ozone and particulate matter emissions and in June 1998, the EPA
modified the PCB rules. Alliant Energy cannot predict the long-term
consequences of these rules on its financial condition or results of
operations.
In October 1998, the EPA issued a final rule requiring 22 states, including
Wisconsin, to modify their state implementation plans to address the ozone
transport issue. However, on May 25, 1999, a federal appeals court delayed
indefinitely the implementation of the rule. On March 3, 2000, the federal
appeals court affirmed EPA's NOx rule for the affected states. However, the
court found that the EPA had failed to explain how Wisconsin contributes
significantly to non-attainment in any other state thus it has vacated the
rule as relates to Wisconsin. Given the EPA could still appeal this decision,
and Alliant Energy is still reviewing the recent court order, Alliant Energy
is unable to predict the final outcome of this issue. The implementation of
the rule would likely require WP&L to reduce its NOx emissions at all of its
plants to a fleet average of .15 lbs/mmbtu by 2003. WP&L is following this
issue closely and continues to evaluate various options to meet the emission
levels. Based on existing technology, the preliminary estimates indicate that
capital investments would be in the range of $150 million to $215 million.
Refer to the "Liquidity and Capital Resources - Rates and Regulatory Matters"
section for a discussion of a filing WP&L made with the PSCW regarding seeking
rate recovery of these costs.
Revisions to the Wisconsin Administrative Code have been proposed that could
have a significant impact on WP&L's operation of the Rock River Generating
Station in Beloit, Wisconsin. The proposed revisions will affect the amount
of heat that the generating station can discharge into the Rock River. WP&L
cannot presently predict the final outcome of the rule, but believes that, as
the rule is currently proposed, the capital investments and/or modifications
required to meet the proposed discharge limits could be significant.
On February 28, 1998, the EPA issued the final report to Congress on the Study
of Hazardous Air Pollutant Emissions from Electric Utility Steam Generating
Units regarding hazardous air pollutant emissions from electric utilities (the
HAPs report). The HAPs report concluded that mercury emissions from
coal-fired generating plants were a concern. However, the EPA does not
believe it has sufficient information regarding such emissions. To remedy
this lack of information, the EPA required IESU, WP&L, IPC and all other
applicable electric utilities in the U.S. to start collecting information
regarding the types and amount of mercury emitted as of January 1, 1999. To
better understand mercury emissions, the EPA required WP&L to conduct stack
tests at several of its generating stations. Both stations selected have
completed their stack testing. Although the control of mercury emissions from
generating plants is uncertain at this time, Alliant Energy believes that the
capital investments and/or modifications required to control mercury emissions
could be significant.
Pursuant to an internal review of operations in 1998, IPC discovered that Unit
No. 6 at its generating facility in Dubuque, Iowa required a Clean Air Act
Acid Rain permit and CEMS. IPC has informed its environmental regulators and
has installed the CEMS and obtained the permit. Pursuant to its internal
review, IPC also identified and disclosed to regulators a potentially similar
situation at its Lansing, Iowa generating facility. In the second quarter of
1999, the EPA determined that Lansing units 1 and 2 are affected units.
Therefore, in the third quarter of 1999, IPC installed the CEMS at both of
these facilities and in December 1999 IPC submitted its certification to the
EPA for the Lansing facility. IPC has received a settlement offer from the
EPA, dated December 3, 1999, to settle the matter for $550,000. IPC has since
responded with a counter offer and negotiations continue.
On February 4, 1999, Whiting received a Notice of Violation letter from the
ADEQ, citing Whiting for flaring sour gas in excess of permit limits and not
having a valid permit. In June 1999, the ADEQ sent Whiting a Consent
Administrative Order proposing a voluntary civil penalty of $225,000 for
Whiting's alleged emission violations. The consent agreement was finalized on
November 9, 1999, resulting in a civil penalty of $99,000, Whiting performing
two mitigation projects, installing an air monitor to run for one full year
and submitting a Title V permit.
WP&L has been notified by the EPA that it is a PRP with respect to
environmental impacts identified at the MIG/DeWane Landfill Superfund Site.
WP&L is participating in the initiation of an alternate dispute resolution
process to allocate liability associated with the investigation and
remediation of the site. Management believes that any likely action resulting
from this matter will not have a material adverse effect on WP&L's financial
condition or results of operations.
53
IPC has been notified by the EPA that it is a PRP with respect to
environmental impacts identified at the Missouri Electric Works, Inc. (MEW)
site in Cape Girardeau, Missouri. IPC has been served with a complaint filed
by the MEW Site Trust Fund, the PRP group involved in investigating and
remediating the site, for response costs incurred by the PRP group. IPC
believes that it is not liable as a PRP for this site because it did not
arrange for the disposal of any waste materials at the site. IPC has filed an
answer to the complaint, discovery is ongoing and settlement discussions
continue.
WP&L has been notified by Monroe County, Wisconsin that it is a PRP with
respect to environmental impacts identified at the Monroe County Interim
Landfill in Sparta, Wisconsin. WP&L has provided a summary of records and
documents relating to waste disposal at the landfill to Monroe County. WP&L
cannot currently estimate what liability, if any, it may have with respect to
this site.
A global treaty has been negotiated that could require reductions of
greenhouse gas emissions from utility plants. In November 1998, the U.S.
signed the treaty and agreed with the other countries to resolve all remaining
issues by the end of 2000. At this time, management is unable to predict
whether the U.S. Congress will ratify the treaty. Given the uncertainty of
the treaty ratification and the ultimate terms of the final regulations,
management cannot currently estimate the impact the implementation of the
treaty would have on Alliant Energy's operations.
The Low-Level Radioactive Waste Policy Amendments Act of 1985 mandates that
each state must take responsibility for the storage of low-level radioactive
waste produced within its borders. The States of Iowa and Wisconsin are
members of the six-state Midwest Interstate Low-Level Radioactive Waste
Compact (Compact) which is responsible for development of any new disposal
capability within the Compact member states. In June 1997, the Compact
commissioners voted to discontinue work on a proposed waste disposal facility
in the State of Ohio because the expected cost of such a facility was
comparably higher than other options currently available. Dwindling waste
volumes and continued access to existing disposal facilities were also reasons
cited for the decision. A disposal facility located near Barnwell, South
Carolina continues to accept the low-level waste and IESU and WP&L currently
ship the waste each produces to such site, thereby minimizing the amount of
low-level waste stored on-site. Given technological advances, waste
compaction and the reduction in the amount of waste generated, DAEC and
Kewaunee each have on-site storage capability sufficient to store low-level
waste expected to be generated over at least the next ten years. While
Alliant Energy is unable to predict how long the Barnwell facility will
continue to accept its waste, continuing access to this facility expands
Alliant Energy's on-site storage capability indefinitely.
See Notes 12(f) and 12(g) of the "Notes to Consolidated Financial Statements"
for a further discussion of Alliant Energy's environmental issues.
Power Supply
Wisconsin enacted electric reliability legislation in 1998 (Wisconsin
Reliability Act) with the goal of assuring reliable electric energy for
Wisconsin. The law allows the construction of merchant power plants in the
state and streamlines the regulatory approval process for building new
generation and transmission facilities. As a requirement of the legislation,
the PSCW completed a regional transmission constraint study. The PSCW is
authorized to order construction of new transmission facilities, based on the
findings of its constraint study, through December 31, 2004.
On September 24, 1997, the PSCW ordered WP&L and two other Wisconsin utilities
to arrange for additional electric capacity to help maintain reliable service
for their customers. In July 1998, Alliant Energy and SkyGen announced an
agreement whereby SkyGen would build, own and operate a power plant in
Wisconsin capable of producing up to 450 MW of electricity. Under the
agreement, Alliant Energy will purchase the capacity to meet the electric
needs of its utility customers, as outlined by the Wisconsin Reliability Act.
A third party filed an appeal to the EPA Appeals Board on the issue of NOx
mitigation. In the fourth quarter of 1999, the WDNR issued a revised air
permit which was appealed again by the third party. In March 2000, the EPA
denied the third party's final appeal which finalizes the air permitting
process and allows for construction of the plant.
The EPA appeal process resulted in the SkyGen project being delayed until the
summer of 2001. Alliant Energy has made other contractual commitments to
54
ensure an 18% reserve margin in 2000, as required for Wisconsin. Part of this
effort includes purchased power contracts at higher costs than the SkyGen
power, including purchasing power from 54 portable diesel generators that will
be located at various substation locations within WP&L's service territory.
These higher costs are included in a rate increase requested by WP&L in
December 1999 as discussed in "Liquidity and Capital Resources - Rates and
Regulatory Matters - WP&L."
IESU and IPC are currently exploring the possibility of transitioning from the
MAPP reliability region to MAIN so all of Alliant Energy will belong to the
same reliability region. Alliant Energy is unable to predict the outcome of
this issue at this time.
Alliant Energy notes that it will take time for new transmission and power
plant projects to be approved and built in Wisconsin. While Alliant Energy
currently expects to meet customer demands in 2000, unanticipated reliability
issues could still arise in the event Wisconsin experiences unexpected power
plant outages, transmission system outages or extended periods of extremely
hot weather.
55
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Quantitative and Qualitative Disclosures About Market Risk are reported
under Item 7. MD&A "Other Matters - Market Risk Sensitive Instruments and
Positions."
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
INDEX TO FINANCIAL STATEMENTS
Alliant Energy Page Number
Report of Management 57
Report of Independent Public Accountants 58
Consolidated Statements of Income for the Years Ended
December 31, 1999, 1998 and 1997 59
Consolidated Balance Sheets as of December 31, 1999 and 1998 60
Consolidated Statements of Cash Flows for the Years Ended
December 31, 1999, 1998 and 1997 62
Consolidated Statements of Capitalization as of December 31, 1999 and 1998 63
Consolidated Statements of Changes in Common Equity for the Years Ended
December 31, 1999, 1998 and 1997 65
Notes to Consolidated Financial Statements 66
IESU
Report of Independent Public Accountants 88
Consolidated Statements of Income and Retained Earnings for the Years Ended
December 31, 1999, 1998 and 1997 89
Consolidated Balance Sheets as of December 31, 1999 and 1998 90
Consolidated Statements of Cash Flows for the Years Ended
December 31, 1999, 1998 and 1997 92
Consolidated Statements of Capitalization as of December 31, 1999 and 1998 93
Notes to Consolidated Financial Statements 94
WP&L
Report of Independent Public Accountants 102
Consolidated Statements of Income and Retained Earnings for the Years Ended
December 31, 1999, 1998 and 1997 103
Consolidated Balance Sheets as of December 31, 1999 and 1998 104
Consolidated Statements of Cash Flows for the Years Ended
December 31, 1999, 1998 and 1997 106
Consolidated Statements of Capitalization as of December 31, 1999 and 1998 107
Notes to Consolidated Financial Statements 108
Refer to Note 15 of Alliant Energy's, IESU's and WP&L's "Notes to
Consolidated Financial Statements" for the quarterly financial data
required by this Item.
56
ALLIANT ENERGY CORPORATION REPORT ON THE FINANCIAL INFORMATION
Alliant Energy Corporation management is responsible for the
information and representations contained in the financial
statements and in other sections of this Annual Report. The
consolidated financial statements that follow have been prepared in
accordance with generally accepted accounting principles. In
addition to selecting appropriate accounting principles, management
is responsible for the manner of presentation and for the
reliability of the financial information. In fulfilling that
responsibility, it is necessary for management to make estimates
based on currently available information and judgments of current
conditions and circumstances.
Through a well-developed system of internal controls, management
seeks to ensure the integrity and objectivity of the financial
information presented in this report. This system of internal
controls is designed to provide reasonable assurance that the
assets of the company are safeguarded and that the transactions are
executed according to management's authorizations and are recorded
in accordance with the appropriate accounting principles.
The Board of Directors participates in the financial information
reporting process through its Audit Committee.
/s/ Erroll B. Davis Jr.
Erroll B. Davis Jr.
President and Chief Executive Officer
/s/ Thomas M. Walker
Thomas M. Walker
Executive Vice President and Chief Financial Officer
/s/ Daniel A. Doyle
Daniel A. Doyle
Vice President - Chief Accounting and Financial Planning Officer
January 28, 2000
57
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Shareowners of Alliant Energy Corporation:
We have audited the accompanying consolidated balance sheets and
statements of capitalization of Alliant Energy Corporation (a Wisconsin
Corporation) and subsidiaries as of December 31, 1999 and 1998, and the
related consolidated statements of income, cash flows and changes in
common equity for each of the three years in the period ended December
31, 1999. These financial statements and the supplemental schedule
referred to below are the responsibility of the Company's management.
Our responsibility is to express an opinion on these financial statements
and supplemental schedule based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to
obtain reasonable assurance about whether the financial statements are
free of material misstatement. An audit includes examining, on a test
basis, evidence supporting the amounts and disclosures in the financial
statements. An audit also includes assessing the accounting principles
used and significant estimates made by management, as well as evaluating
the overall financial statement presentation. We believe that our audits
provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present
fairly, in all material respects, the financial position of Alliant
Energy Corporation and subsidiaries as of December 31, 1999 and 1998, and
the results of their operations and their cash flows for each of the
three years in the period ended December 31,1999, in conformity with
generally accepted accounting principles.
Our audit was made for the purpose of forming an opinion on the basic
financial statements taken as a whole. The schedule listed in Item
14(a)(2) is presented for purposes of complying with the Securities and
Exchange Commission's rules and is not part of the basic financial
statements. This schedule has been subjected to the auditing procedures
applied in the audit of the basic financial statements and, in our
opinion, fairly states in all material respects the financial data
required to be set forth therein in relation to the basic financial
statements taken as a whole.
/s/ ARTHUR ANDERSEN LLP
ARTHUR ANDERSEN LLP
Milwaukee, Wisconsin
January 28, 2000
58
ALLIANT ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF INCOME
Year Ended December 31,
1999 1998 1997
- -------------------------------------------------------------------------------------------------------------------------------
(in thousands, except per share amounts)
Operating revenues:
Electric utility $1,548,938 $1,567,442 $1,515,753
Gas utility 314,319 295,590 393,907
Non-regulated and other 334,706 267,842 390,967
----------------- ----------------- ------------------
2,197,963 2,130,874 2,300,627
----------------- ----------------- ------------------
- -------------------------------------------------------------------------------------------------------------------------------
Operating expenses:
Electric and steam production fuels 262,305 297,685 280,558
Purchased power 255,446 255,332 256,306
Cost of utility gas sold 180,519 166,453 259,222
Other operation 623,687 620,234 681,977
Maintenance 115,414 122,737 123,121
Depreciation and amortization 279,088 279,505 259,663
Taxes other than income taxes 104,969 105,626 103,397
----------------- ----------------- ------------------
1,821,428 1,847,572 1,964,244
----------------- ----------------- ------------------
- -------------------------------------------------------------------------------------------------------------------------------
Operating income 376,535 283,302 336,383
----------------- ----------------- ------------------
- -------------------------------------------------------------------------------------------------------------------------------
Interest expense and other:
Interest expense 136,229 129,363 122,563
Allowance for funds used during construction (7,292) (6,812) (5,274)
Preferred dividend requirements of subsidiaries 6,706 6,699 6,693
Gains on sales of McLeodUSA Inc. stock (40,272) - -
Miscellaneous, net (35,903) (736) (13,910)
----------------- ----------------- ------------------
59,468 128,514 110,072
----------------- ----------------- ------------------
- -------------------------------------------------------------------------------------------------------------------------------
Income before income taxes 317,067 154,788 226,311
----------------- ----------------- ------------------
- -------------------------------------------------------------------------------------------------------------------------------
Income taxes 120,486 58,113 81,733
----------------- ----------------- ------------------
- -------------------------------------------------------------------------------------------------------------------------------
Net income $196,581 $96,675 $144,578
================= ================= ==================
- -------------------------------------------------------------------------------------------------------------------------------
Average number of common shares outstanding 78,352 76,912 76,210
================= ================= ==================
- -------------------------------------------------------------------------------------------------------------------------------
Earnings per average common share (basic and diluted) $2.51 $1.26 $1.90
================= ================= ==================
- -------------------------------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
59
ALLIANT ENERGY CORPORATION
CONSOLIDATED BALANCE SHEETS
December 31,
ASSETS 1999 1998
- -------------------------------------------------------------------------------------------------------------------
(in thousands)
Property, plant and equipment:
Utility -
Plant in service -
Electric $5,032,675 $4,866,152
Gas 540,874 515,074
Other 458,547 409,711
---------------- ----------------
6,032,096 5,790,937
Less - Accumulated depreciation 3,077,459 2,852,605
---------------- ----------------
2,954,637 2,938,332
Construction work in progress 119,276 119,032
Nuclear fuel, net of amortization 54,363 44,316
---------------- ----------------
3,128,276 3,101,680
Other property, plant and equipment, net of accumulated
depreciation and amortization of $184,722 and $178,248, respectively 357,758 355,100
---------------- ----------------
3,486,034 3,456,780
---------------- ----------------
- -------------------------------------------------------------------------------------------------------------------
Current assets:
Cash and temporary cash investments 113,669 31,827
Accounts receivable:
Customer, less allowance for doubtful accounts
of $2,253 and $2,518, respectively 67,299 47,952
Unbilled utility revenues 48,033 55,014
Other, less allowance for doubtful accounts
of $954 and $490, respectively 30,095 26,054
Notes receivable, less allowance for doubtful
accounts of $153 and $120, respectively 6,328 13,392
Income tax refunds receivable 14,611 14,826
Production fuel, at average cost 49,657 54,140
Materials and supplies, at average cost 52,440 53,490
Gas stored underground, at average cost 23,151 26,013
Regulatory assets 33,439 30,796
Prepaid gross receipts tax 20,864 22,222
Other 26,400 15,941
---------------- ----------------
485,986 391,667
---------------- ----------------
- -------------------------------------------------------------------------------------------------------------------
Investments:
Investment in McLeodUSA Inc. 1,123,790 320,280
Nuclear decommissioning trust funds 271,258 225,803
Investments in foreign entities 198,055 68,882
Other 59,866 54,776
---------------- ----------------
1,652,969 669,741
---------------- ----------------
- -------------------------------------------------------------------------------------------------------------------
Other assets:
Regulatory assets 263,610 284,467
Deferred charges and other 187,084 156,682
---------------- ----------------
450,694 441,149
---------------- ----------------
- -------------------------------------------------------------------------------------------------------------------
Total assets $6,075,683 $4,959,337
================ ================
- -------------------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
60
ALLIANT ENERGY CORPORATION
CONSOLIDATED BALANCE SHEETS (Continued)
December 31,
CAPITALIZATION AND LIABILITIES 1999 1998
- ----------------------------------------------------------------------------------------------------------------------------
(in thousands)
Capitalization (See Consolidated Statements of Capitalization):
Common stock $790 $776
Additional paid-in capital 942,408 905,130
Retained earnings 577,464 537,372
Accumulated other comprehensive income 634,903 163,017
------------------ ------------------
Total common equity 2,155,565 1,606,295
------------------ ------------------
Cumulative preferred stock of subsidiaries, net 113,638 113,498
Long-term debt (excluding current portion) 1,486,765 1,543,131
------------------ ------------------
3,755,968 3,262,924
------------------ ------------------
- ----------------------------------------------------------------------------------------------------------------------------
Current liabilities:
Current maturities and sinking funds 54,795 63,414
Variable rate demand bonds 55,100 56,975
Commercial paper 374,673 64,500
Notes payable 50,046 51,784
Capital lease obligations 13,321 11,978
Accounts payable 191,149 204,297
Accrued taxes 78,825 84,921
Other 115,716 111,685
------------------ ------------------
933,625 649,554
------------------ ------------------
- ----------------------------------------------------------------------------------------------------------------------------
Other long-term liabilities and deferred credits:
Accumulated deferred income taxes 1,018,482 691,624
Accumulated deferred investment tax credits 71,857 77,313
Environmental liabilities 65,327 68,399
Customer advances 38,096 37,171
Capital lease obligations 26,041 13,755
Other 166,287 158,597
------------------ ------------------
1,386,090 1,046,859
------------------ ------------------
- ----------------------------------------------------------------------------------------------------------------------------
Commitments and Contingencies (Note 12)
- ----------------------------------------------------------------------------------------------------------------------------
Total capitalization and liabilities $6,075,683 $4,959,337
================== ==================
- ----------------------------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
61
ALLIANT ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
Year Ended December 31,
1999 1998 1997
- ---------------------------------------------------------------------------------------------------------------
(in thousands)
Cash flows from operating activities:
Net income $196,581 $96,675 $144,578
Adjustments to reconcile net income to net cash flows
from operating activities:
Depreciation and amortization 279,088 279,505 259,663
Amortization of nuclear fuel 17,494 17,869 18,308
Amortization of deferred energy efficiency expenditures 25,435 27,083 15,786
Deferred taxes and investment tax credits (16,258) (27,720) (11,661)
Refueling outage provision (5,150) (4,001) 9,290
Impairment of oil and gas properties 3,276 9,678 9,902
Impairment of regulatory assets - 8,969 -
Gain on disposition of assets, net (61,667) (6,505) (1,463)
Other 902 2,889 6,931
Other changes in assets and liabilities:
Accounts receivable (16,407) 15,349 18,638
Notes receivable 7,064 10,018 (3,621)
Production fuel 4,483 (13,484) 2,814
Accounts payable (13,148) 11,663 (27,726)
Accrued taxes (6,096) 5,998 13,375
Benefit obligations and other 7,532 33,776 8,675
-------------- -------------- --------------
Net cash flows from operating activities 423,129 467,762 463,489
-------------- -------------- --------------
- ---------------------------------------------------------------------------------------------------------------
Cash flows from (used for) financing activities:
Common stock dividends declared (156,489) (140,679) (145,631)
Dividends payable 13 (15,458) 285
Proceeds from issuance of common stock 36,491 33,832 15,535
Net change in Resources' credit facility (113,657) 70,492 9,908
Proceeds from issuance of other long-term debt 281,299 77,544 295,000
Reductions in other long-term debt (95,520) (27,663) (146,590)
Net change in other short-term borrowings 169,587 (40,216) (109,884)
Principal payments under capital lease obligations (12,887) (13,250) (12,964)
Other (5,744) (2,333) (2,410)
-------------- -------------- --------------
Net cash flows from (used for) financing activities 103,093 (57,731) (96,751)
-------------- -------------- --------------
- ---------------------------------------------------------------------------------------------------------------
Cash flows used for investing activities:
Construction and acquisition expenditures:
Utility (285,668) (269,133) (256,760)
Non-regulated businesses (192,905) (102,925) (71,280)
Deferred energy efficiency expenditures - - (13,344)
Nuclear decommissioning trust funds (22,100) (20,305) (17,435)
Proceeds from disposition of assets 93,443 16,677 15,993
Shared savings program (35,846) (27,780) (17,610)
Other (1,304) (2,067) (1,790)
-------------- -------------- --------------
Net cash flows used for investing activities (444,380) (405,533) (362,226)
-------------- -------------- --------------
- ---------------------------------------------------------------------------------------------------------------
Net increase in cash and temporary cash investments 81,842 4,498 4,512
-------------- -------------- --------------
- ---------------------------------------------------------------------------------------------------------------
Cash and temporary cash investments at beginning of period 31,827 27,329 22,817
-------------- -------------- --------------
- ---------------------------------------------------------------------------------------------------------------
Cash and temporary cash investments at end of period $113,669 $31,827 $27,329
============== ============== ==============
- ---------------------------------------------------------------------------------------------------------------
Supplemental cash flow information:
Cash paid during the period for:
Interest $130,214 $126,376 $117,255
============== ============== ==============
Income taxes $141,150 $84,916 $69,272
============== ============== ==============
Noncash investing and financing activities:
Capital lease obligations incurred $25,040 $1,426 $16,781
============== ============== ==============
- ---------------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
62
ALLIANT ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF CAPITALIZATION
December 31,
1999 1998
- --------------------------------------------------------------------------- ------------------------------------
(in thousands, except share amounts)
Common equity:
Common stock - $.01 par value - authorized 200,000,000 shares;
outstanding 78,984,014 and 77,630,043 shares, respectively $790 $776
Additional paid-in capital 942,408 905,130
Retained earnings 577,464 537,372
Accumulated other comprehensive income 634,903 163,017
---------------- -----------------
2,155,565 1,606,295
---------------- -----------------
- ------------------------------------------------------------------------------------------------------------------
Cumulative preferred stock of subsidiaries:
Par/Stated Authorized Shares Mandatory
Value Shares Outstanding Series Redemption
$ 100 * 449,765 4.40% - 6.20% No 44,977 44,977
$ 25 * 599,460 6.50% No 14,986 14,986
$ 50 466,406 366,406 4.30% - 6.10% No 18,320 18,320
$ 50 ** 216,381 4.36% - 7.76% No 10,819 10,819
$ 50 ** 545,000 6.40% Yes *** 27,250 27,250
---------------- -----------------
116,352 116,352
Less: unamortized expenses (2,714) (2,854)
---------------- -----------------
113,638 113,498
---------------- -----------------
* 3,750,000 authorized shares in total
** 2,000,000 authorized shares in total
*** $53.20 mandatory redemption price
- ------------------------------------------------------------------------------------------------------------------
Long-term debt:
IES Utilities Inc. -
Collateral Trust Bonds:
7.65% series, due 2000 50,000 50,000
7.25% series, due 2006 60,000 60,000
6-7/8% series, due 2007 55,000 55,000
6% series, due 2008 50,000 50,000
7% series, due 2023 50,000 50,000
5.5% series, due 2023 19,400 19,400
---------------- -----------------
284,400 284,400
First Mortgage Bonds:
Series Y, 8-5/8%, due 2001 60,000 60,000
Series Z, 7.6%, retired in 1999 - 50,000
9-1/8% series, due 2001 21,000 21,000
7-1/4% series, due 2007 30,000 30,000
---------------- -----------------
111,000 161,000
Pollution control obligations:
5.75%, due serially 2000 to 2003 2,996 3,136
Variable rate (5.45% at December 31, 1999), due 2000 to 2010 11,100 11,100
Variable/fixed rate series 1998 (4.25% through 2003), due 2023 10,000 10,000
---------------- -----------------
24,096 24,236
Subordinated Deferrable Interest Debentures, 7-7/8%, due 2025 50,000 50,000
Senior Debentures, 6-5/8%, due 2009 135,000 135,000
---------------- -----------------
Total IES Utilities Inc. 604,496 654,636
---------------- -----------------
63
ALLIANT ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF CAPITALIZATION (Continued)
December 31,
1999 1998
- ---------------------------------------------------------------------------------------------------------------------------
(in thousands)
Wisconsin Power and Light Company -
First Mortgage Bonds:
1984 Series A, variable rate (5.00% at December 31, 1999), due 2014 $8,500 $8,500
1988 Series A, variable rate (5.60% at December 31, 1999), due 2015 14,600 14,600
1990 Series V, 9.3%, due 2025 27,000 27,000
1991 Series A-D, variable rate (4.75% at December 31, 1999), due 2000 to 2015 33,875 33,875
1992 Series W, 8.6%, due 2027 90,000 90,000
1992 Series X, 7.75%, due 2004 62,000 62,000
1992 Series Y, 7.6%, due 2005 72,000 72,000
----------------- ----------------
307,975 307,975
Unsecured Debt:
Debentures, 7%, due 2007 105,000 105,000
Debentures, 5.7%, due 2008 60,000 60,000
----------------- ----------------
Total Wisconsin Power and Light Company 472,975 472,975
----------------- ----------------
Interstate Power Company -
First Mortgage Bonds:
8% series, due 2007 25,000 25,000
8-5/8% series, due 2021 25,000 25,000
7-5/8% series, due 2023 94,000 94,000
----------------- ----------------
144,000 144,000
Pollution Control Revenue Bonds:
6-3/8%, retired in 1999 - 10,950
5.75%, due 2003 1,000 1,000
6.25%, due 2009 1,000 1,000
6.30%, due 2010 5,600 5,600
6.35%, due 2012 5,650 5,650
Variable/fixed rate series 1998 (4.30% through 2003), due 2005 to 2008 4,950 4,950
Variable/fixed rate series 1999 (4.05% through 2004), due 2010 3,250 -
Variable/fixed rate series 1999 (4.20% through 2004), due 2013 7,700 -
----------------- ----------------
29,150 29,150
----------------- ----------------
Total Interstate Power Company 173,150 173,150
----------------- ----------------
Alliant Energy Resources, Inc. -
Credit facility - 252,505
7-3/8% senior notes, due 2009 250,000 -
Multifamily Housing Revenue Bonds issued by various housing and
community development authorities, 4.75% - 7.55%, due 2000 to 2036 34,095 35,494
Other subsidiaries' debt, 0% - 10.75%, due 2000 to 2042 45,926 57,579
----------------- ----------------
Total Alliant Energy Resources, Inc. 330,021 345,578
----------------- ----------------
Alliant Energy Corporation -
8.59% senior notes, due 2004 24,000 24,000
----------------- ----------------
1,604,642 1,670,339
----------------- ----------------
Less:
Current maturities (54,795) (63,414)
Variable rate demand bonds (55,100) (56,975)
Unamortized debt premium and (discount), net (7,982) (6,819)
----------------- ----------------
Total long-term debt 1,486,765 1,543,131
----------------- ----------------
- ---------------------------------------------------------------------------------------------------------------------------
Total capitalization $3,755,968 $3,262,924
================= ================
- ---------------------------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
64
ALLIANT ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF CHANGES IN COMMON EQUITY
Accumulated
Additional Other Total
Common Paid-In Retained Comprehensive Common
Stock Capital Earnings Income (Loss) Equity
- -----------------------------------------------------------------------------------------------------------------------------------
(in thousands)
1997:
Beginning balance (a) $758 $850,848 $582,429 ($809) $1,433,226
Comprehensive income:
Net income 144,578 144,578
Other comprehensive income (loss):
Unrealized gains on securities, net of tax (b) 174,688 174,688
Foreign currency translation adjustments (20) (20)
Minimum pension liability adjustment, net of tax (c) (347) (347)
-------------
Total comprehensive income 318,899
Common stock dividends (145,631) (145,631)
Common stock issued 7 18,138 18,145
Treasury stock (83) (83)
-------------- ------------- ------------- --------------- -------------
Ending balance 765 868,903 581,376 173,512 1,624,556
1998:
Comprehensive income:
Net income 96,675 96,675
Other comprehensive income (loss):
Unrealized losses on securities, net of tax (b) (4,589) (4,589)
Foreign currency translation adjustments (7,062) (7,062)
Minimum pension liability adjustment, net of tax (c) 1,156 1,156
-------------
Total comprehensive income 86,180
Common stock dividends (140,679) (140,679)
Common stock issued 11 36,263 36,274
Treasury stock (36) (36)
-------------- ------------- ------------- --------------- -------------
Ending balance 776 905,130 537,372 163,017 1,606,295
1999:
Comprehensive income:
Net income 196,581 196,581
Other comprehensive income (loss):
Unrealized gains on securities:
Unrealized holding gains arising
during period, net of tax (b) 499,668 499,668
Less: reclassification adjustment for gains
included in net income, net of tax of $14,986 (25,286) (25,286)
--------------- -------------
Net unrealized gains 474,382 474,382
--------------- -------------
Foreign currency translation adjustments (2,496) (2,496)
-------------
Total comprehensive income 668,467
Common stock dividends (156,489) (156,489)
Common stock issued 14 37,278 37,292
-------------- ------------- ------------- --------------- -------------
Ending balance $790 $942,408 $577,464 $634,903 $2,155,565
============== ============= ============= =============== =============
- -----------------------------------------------------------------------------------------------------------------------------------
(a) The beginning accumulated other comprehensive income (loss) balance was all
related to Alliant Energy's minimum pension liability adjustment.
(b) Net of tax expense (benefit) of $124,271, ($3,218) and $351,314 in 1997, 1998 and 1999, respectively.
(c) Net of tax expense (benefit) of ($243) and $808 in 1997 and 1998, respectively.
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
65
ALLIANT ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
(a) General - The Consolidated Financial Statements include the accounts of
Alliant Energy and its consolidated subsidiaries. Alliant Energy is an
investor-owned holding company, incorporated in Wisconsin, whose primary
subsidiaries are IESU, WP&L, IPC, Resources and Corporate Services. IESU,
WP&L and IPC are engaged principally in the generation, transmission,
distribution and sale of electric energy; the purchase, distribution,
transportation and sale of natural gas; and water and steam services in
selective markets. The principal markets of IESU, WP&L and IPC are located in
Iowa, Wisconsin, Minnesota and Illinois. Resources (through its numerous
direct and indirect subsidiaries) provides energy products and services to
domestic and international markets; provides industrial services including
environmental, engineering and transportation services; invests in affordable
housing initiatives; and invests in various other strategic initiatives.
Corporate Services is the subsidiary formed to provide administrative services
to Alliant Energy and its subsidiaries as required under PUHCA.
The consolidated financial statements reflect investments in controlled
subsidiaries on a consolidated basis. All significant intercompany balances
and transactions, other than certain energy-related transactions affecting
IESU, WP&L and IPC, have been eliminated from the Consolidated Financial
Statements. Such energy-related transactions are made at prices that
approximate market value and the associated costs are recoverable from
customers through the rate making process. The financial statements are
prepared in conformity with generally accepted accounting principles, which
give recognition to the rate making and accounting practices of FERC and state
commissions having regulatory jurisdiction. Certain prior period amounts have
been reclassified on a basis consistent with the current year presentation.
Unconsolidated investments for which Alliant Energy has at least a 20% voting
interest are generally accounted for under the equity method of accounting.
These investments are stated at acquisition cost, increased or decreased for
Alliant Energy's equity in net income or loss, which is included in
"Miscellaneous, net" in the Consolidated Statements of Income and decreased for
any dividends received. Investments that do not meet the criteria for
consolidation or the equity method of accounting are accounted for under the
cost method.
The preparation of the financial statements requires management to make
estimates and assumptions that affect: a) the reported amounts of assets and
liabilities and the disclosure of contingent assets and liabilities at the
date of the financial statements; and b) the reported amounts of revenues and
expenses during the reporting period. Actual results could differ from those
estimates.
(b) Regulation - Alliant Energy is a registered public utility holding
company subject to regulation by the SEC under PUHCA. IESU, WP&L and IPC are
subject to regulation by the FERC and their respective state regulatory
commissions (IUB, PSCW, MPUC and ICC).
(c) Regulatory Assets - IESU, WP&L and IPC are subject to the provisions of
SFAS 71, "Accounting for the Effects of Certain Types of Regulation." SFAS 71
provides that rate-regulated public utilities record certain costs and credits
allowed in the rate making process in different periods than for unregulated
entities. These are deferred as regulatory assets or regulatory liabilities
and are recognized in the Consolidated Statements of Income at the time they
are reflected in rates. At December 31, 1999 and 1998, regulatory assets of
$297.0 million and $315.3 million, respectively, were comprised of the
following items (in millions):
IESU WP&L IPC
-------------------- --------------------- ------------------
1999 1998 1999 1998 1999 1998
---------- --------- ---------- ---------- -------- ---------
Tax-related (Note 1(d)) $83.0 $81.4 $43.4 $49.3 $29.7 $29.8
Energy efficiency program costs 22.2 39.8 7.0 -- 23.9 25.9
Environmental liabilities (Note 12(f)) 32.4 35.2 19.1 19.5 15.7 17.5
Other 4.0 5.0 16.4 11.2 0.2 0.7
---------- --------- ---------- ---------- -------- ---------
$141.6 $161.4 $85.9 $80.0 $69.5 $73.9
========== ========= ========== ========== ======== =========
66
Refer to the individual notes referenced above for a further discussion of
certain items reflected in regulatory assets. If a portion of IESU's, WP&L's
or IPC's operations become no longer subject to the provisions of SFAS 71 as a
result of competitive restructuring or otherwise, a write-down of related
regulatory assets would be required, unless some form of transition cost
recovery is established by the appropriate regulatory body that would meet the
requirements under generally accepted accounting principles for continued
accounting as regulatory assets during such recovery period. In addition,
IESU, WP&L or IPC would be required to determine any impairment to other
assets and write-down such assets to their fair value.
(d) Income Taxes - Alliant Energy follows the liability method of accounting
for deferred income taxes, which requires the establishment of deferred tax
assets and liabilities, as appropriate, for all temporary differences between
the tax basis of assets and liabilities and the amounts reported in the
financial statements. Deferred taxes are recorded using currently enacted tax
rates.
Except as noted below, income tax expense includes provisions for deferred
taxes to reflect the tax effects of temporary differences between the time
when certain costs are recorded in the accounts and when they are deducted for
tax return purposes. As temporary differences reverse, the related
accumulated deferred income taxes are reversed to income. Investment tax
credits have been deferred and are subsequently credited to income over the
average lives of the related property. As part of the affordable housing and
oil and gas production businesses, Alliant Energy is eligible to claim certain
tax credits. These tax credits reduce current federal taxes to the extent
Alliant Energy has consolidated taxes payable.
Consistent with Iowa rate making practices for IESU and IPC, deferred tax
expense is not recorded for certain temporary differences (primarily related
to utility property, plant and equipment). As the deferred taxes become
payable (over periods exceeding 30 years for some generating plant
differences) they are recovered through rates. Accordingly, IESU and IPC have
recorded deferred tax liabilities and regulatory assets for certain temporary
differences, as identified in Note 1(c). In Wisconsin, the PSCW has allowed
rate recovery of deferred taxes on all temporary differences since August
1991. WP&L established a regulatory asset associated with those temporary
differences occurring prior to August 1991 that will be recovered in future
rates.
Alliant Energy files a consolidated federal income tax return. Under the
terms of an agreement between Alliant Energy and its subsidiaries, the
subsidiaries calculate their respective federal income tax provisions and make
payments to or receive payments from Alliant Energy as if they were separate
taxable entities.
(e) Common Shares Outstanding - Weighted average common shares outstanding
used to calculate basic and diluted earnings per share for 1999, 1998 and 1997
were as follows:
Weighted Average 1999 1998 1997
- -------------------------------------------------------------------- ------------- ------------- -------------
Common shares outstanding - basic earnings per share calculation 78,352,186 76,912,219 76,209,935
Effect of dilutive securities 42,961 16,412 2,138
Common shares - diluted earnings per share calculation 78,395,147 76,928,631 76,212,073
In 1999, 1,275,355 options to purchase shares of common stock, with an average
exercise price of $30.55, were excluded from the calculation of diluted
earnings per share as the exercise prices were greater than the average market
price.
(f) Temporary Cash Investments - Temporary cash investments are stated at
cost, which approximates market value, and are considered cash equivalents for
the Consolidated Statements of Cash Flows. These investments consist of
short-term liquid investments that have maturities of less than 90 days from
the date of acquisition.
(g) Depreciation of Utility Property, Plant and Equipment - IESU, WP&L and
IPC use a combination of remaining life and straight-line depreciation methods
as approved by their respective regulatory commissions. The remaining life of
DAEC, of which IESU is a co-owner, is based on the NRC license end-of-life of
2014. The remaining life of Kewaunee, of which WP&L is a co-owner, is based
on the PSCW approved revised end-of-life of 2002 (prior to May 1997 the
calculation was based on the NRC license end-of-life of 2013). Depreciation
67
expense related to the decommissioning of DAEC and Kewaunee is discussed in
Note 12(h). The average rates of depreciation for electric and gas properties
of IESU, WP&L and IPC, consistent with current rate making practices, were as
follows:
IESU WP&L IPC
------------------------ ------------------------ -----------------------
1999 1998 1997 1999 1998 1997 1999 1998 1997
------------------------ ------------------------ -----------------------
Electric 3.5% 3.5% 3.5% 3.6% 3.6% 3.6% 3.6% 3.6% 3.6%
Gas 3.5% 3.5% 3.5% 3.9% 3.8% 3.8% 3.6% 3.4% 3.4%
(h) Property, Plant and Equipment - Utility plant (other than acquisition
adjustments) is recorded at original cost, which includes overhead and
administrative costs and AFUDC. At December 31, 1999, IESU had $25.6 million
of acquisition adjustments, net of accumulated amortization, included in
utility plant ($6 million of such balance is currently being recovered in
IESU's rates). AFUDC, which represents the cost during the construction period
of funds used for construction purposes, is capitalized as a component of the
cost of utility plant. The amount of AFUDC applicable to debt funds and to
other (equity) funds, a non-cash item, is computed in accordance with the
prescribed FERC formula. These capitalized costs are recovered in rates as
the cost of the utility plant is depreciated. The aggregate gross rates used
were as follows:
1999 1998 1997
------------ ------------ ------------
IESU 7.9% 8.9% 6.7%
WP&L 5.4% 5.2% 6.2%
IPC 5.3% 7.0% 6.0%
Other property, plant and equipment is recorded at original cost. Upon
retirement or sale of other property and equipment, the cost and related
accumulated depreciation are removed from the accounts and any gain or loss is
included in "Miscellaneous, net" in the Consolidated Statements of Income.
Normal repairs, maintenance and minor items of utility plant and other
property, plant and equipment are expensed. Ordinary retirements of utility
plant, including removal costs less salvage value, are charged to accumulated
depreciation upon removal from utility plant accounts and no gain or loss is
recognized.
(i) Operating Revenues - Alliant Energy accrues revenues for services
rendered but unbilled at month-end in order to more properly match revenues
with expenses. In the third quarter of 1999, Alliant Energy recorded a $9
million increase in the estimate of utility services rendered but unbilled at
month-end. This change was a result of the implementation of a refined
estimation process compared with the unbilled revenues recorded at June 30,
1999 using the estimation process in effect at that time. In accordance with
an order from the PSCW, effective January 1, 1998, off-system gas sales for
WP&L are included in the Consolidated Statements of Income as a reduction of
the cost of gas sold rather than as gas revenues. Off-system gas sales at
WP&L were $12.8 million, $11.5 million and $11.1 million in 1999, 1998 and
1997, respectively.
(j) Utility Fuel Cost Recovery - IESU's and IPC's tariffs provide for
subsequent adjustments to its electric and natural gas rates for changes in
the cost of fuel and purchased energy and in the cost of natural gas purchased
for resale. Changes in the under/over collection of these costs are reflected
in "Electric and steam production fuels" and "Cost of utility gas sold" in the
Consolidated Statements of Income. The cumulative effects are reflected on
the Consolidated Balance Sheets as a current asset or current liability,
pending automatic reflection in future billings to customers. At IESU and
IPC, purchased capacity costs are not recovered from electric customers
through energy adjustment clauses. Recovery of these costs must be addressed
in base rates in a formal rate proceeding.
WP&L's retail electric rates are based in part on forecasted fuel and
purchased-power costs. Under PSCW rules, Wisconsin utilities can seek
emergency rate increases if the annual costs are more than 3% higher than the
estimated costs used to establish rates. WP&L has a gas performance incentive
which includes a sharing mechanism whereby 40% of all gains and losses
relative to current commodity prices, as well as other benchmarks, are
retained by WP&L rather than refunded to or recovered from customers.
68
(k) Nuclear Refueling Outage Costs - The IUB allows IESU to collect, as part
of its base revenues, funds to offset other operation and maintenance
expenditures incurred during refueling outages at DAEC. As these revenues are
collected, an equivalent amount is charged to other operation and maintenance
expenses with a corresponding credit to a reserve. During a refueling outage,
the reserve is reversed to offset the refueling outage expenditures.
Operating expenses incurred during refueling outages at Kewaunee are expensed
by WP&L as incurred.
(l) Nuclear Fuel - Nuclear fuel for DAEC is leased. Annual nuclear fuel
lease expenses include the cost of fuel, based on the quantity of heat
produced for the generation of electric energy, plus the lessor's interest
costs related to fuel in the reactor and administrative expenses. Nuclear
fuel for Kewaunee is recorded at its original cost and is amortized to expense
based upon the quantity of heat produced for the generation of electricity.
This accumulated amortization assumes spent nuclear fuel will have no residual
value. Estimated future disposal costs of such fuel are expensed based on
kilowatt-hours generated.
(m) Translation of Foreign Currency - Assets and liabilities of international
investments, where the local currency is the functional currency, have been
translated at year-end exchange rates and related income statement results
have been translated using average exchange rates prevailing during the year.
Adjustments resulting from translation have been recorded in other
comprehensive income.
(n) Derivative Financial Instruments - From time to time, Alliant Energy uses
derivative financial instruments to hedge exposures to fluctuations in
interest rates, certain commodity prices and volatility in a portion of
natural gas sales volumes due to weather. These instruments are used to
mitigate risks and are not to be used for speculative purposes. Under the
deferral method of accounting, gains and losses related to derivatives that
qualify as hedges are recognized in earnings when the underlying hedged item
or physical transaction is recognized in income.
Alliant Energy is exposed to losses related to financial instruments in the
event of counterparties' nonperformance. Alliant Energy has established
controls to determine and monitor the creditworthiness of counterparties in
order to mitigate its exposure to counterparty credit risk. Alliant Energy is
not aware of any counterparties that will fail to meet their obligations.
Refer to Note 11 for a further discussion of Alliant Energy's derivative
financial instruments.
(2) MERGER
On April 21, 1998, IES, WPLH and IPC completed a merger forming Alliant
Energy. The merger was accounted for as a pooling of interests and the
accompanying Consolidated Financial Statements, along with the related notes,
are presented as if the companies were combined as of the earliest period
presented.
In association with the merger, Alliant Energy eliminated 167 positions in
1998. As a result, Alliant Energy recorded $15 million of expenses during
1998 in "Other operation" expense related to the employee separation benefits
to be paid to the impacted employees. The bulk of the positions eliminated
were administrative in nature and resulted from no longer needing certain
duplicative positions given the consolidation of the three companies. The
departure dates for the impacted employees varied based on the need for their
services during the transition period as well as certain other factors. The
balance of the accrual at December 31, 1999 and 1998 was $1.0 million and $5.7
million, respectively. As of December 31, 1999, all of the terminated
employees had actually left the organization. As of December 31, 1998, 156 of
the terminated employees had actually left the organization. The balance
remaining in the accrued liability at December 31, 1999 related to payments to
certain terminated executives that were being paid out over a 18-36 month
period pursuant to the terms of their respective severance agreements. The
only significant adjustments made to the liability after the initial accrual
were to reflect the actual payments of the employee separation benefits.
In association with the merger, Alliant Energy entered into a three-year
consulting agreement, which expires in the second quarter of 2001, with Wayne
Stoppelmoor, the Chief Executive Officer of IPC prior to the consummation of
the merger. Under the terms of the consulting agreement, Mr. Stoppelmoor, who
also serves as Vice Chairman of Alliant Energy's Board of Directors, receives
annual fees of $324,500, $324,500 and $200,000 for his services during the
respective periods of the agreement.
69
(3) LEASES
IESU has a capital lease covering its 70% undivided interest in nuclear fuel
purchased for DAEC. Future purchases of fuel may also be added to the fuel
lease. This lease provides for annual one-year extensions and IESU intends to
continue exercising such extensions. Interest costs under the lease are based
on commercial paper costs incurred by the lessor. IESU is responsible for the
payment of taxes, maintenance, operating cost, risk of loss and insurance
relating to the leased fuel. The lessor has a $45 million credit agreement
with a bank supporting the nuclear fuel lease. The agreement continues on a
year-to-year basis, unless either party provides at least a three-year notice
of termination; no such notice of termination has been provided by either
party. Annual nuclear fuel lease expenses (included in "Electric and steam
production fuels" in the Consolidated Statements of Income) for 1999, 1998 and
1997 were $12.7 million, $14.2 million and $16.6 million, respectively.
Alliant Energy's operating lease rental expenses for 1999, 1998 and 1997 were
$24.6 million, $21.6 million and $20.3 million, respectively. Alliant
Energy's future minimum lease payments by year are as follows (in millions):
Capital Operating
Year Leases Leases
- ------------------------------------------ --------------- ----------------
2000 $15.6 $24.0
2001 10.6 20.1
2002 8.7 15.3
2003 4.3 12.9
2004 3.9 10.5
Thereafter 1.3 39.1
---------------
----------------
44.4 $121.9
================
Less: Amount representing interest 5.0
---------------
Present value of net minimum
capital lease payments $39.4
===============
(4) UTILITY ACCOUNTS RECEIVABLE
Utility customer accounts receivable, including unbilled revenues, arise
primarily from the sale of electricity and natural gas. At December 31, 1999,
Alliant Energy was serving a diversified base of residential, commercial and
industrial customers and did not have any significant concentrations of credit
risk.
Similar accounts receivable financing arrangements exist for two of Alliant
Energy's utility subsidiaries, IESU and WP&L. In both cases, the utility
subsidiaries sell up to a pre-determined maximum amount of accounts receivable
to a financial institution on a limited recourse basis. Accounts receivable
sold include receivables arising from sales to customers and to other public,
municipal and cooperative utilities, as well as from billings to the co-owners
of the jointly-owned electric generating plants operated by utility
subsidiaries of Alliant Energy. The amounts are discounted at the
then-prevailing market rate and additional administrative fees are payable
according to the activity levels undertaken. All billing and collection
functions remain the responsibility of the respective utilities. Specifics of
the two agreements include (dollars in millions):
IESU WP&L
----------- -----------
Year agreement expires 2000 2000
Maximum amount of receivables that can be sold $65 $150
Effective 1999 all-in cost 5.58% 5.58%
Average monthly sale of receivables - 1999 $55 $73
- 1998 $63 $83
Receivables sold at December 31, 1999 $59 $67
For additional information on the accounts receivable programs, refer to the
"Liquidity and Capital Resources - Financing and Capital Structure" section of
MD&A.
70
(5) RESOURCES SUMMARY FINANCIAL INFORMATION
Summary financial information for Resources was as follows (in millions):
December 31, 1999 December 31, 1998
--------------------- ---------------------
Current assets $132.4 $92.1
Non-current assets 1,716.2 777.1
Current liabilities 197.7 63.6
Non-current liabilities (excludes minority interest) 502.8 160.3
Minority interest (primarily real estate joint ventures) 7.2 6.2
Refer to the "Non-regulated Businesses" column of Note 14 for summary income
statement data of Resources. Alliant Energy has not presented separate
financial statements for Resources because it is a wholly-owned subsidiary of
Alliant Energy and because management has determined that such information is
not material to holders of senior notes of Resources. Alliant Energy has
fully and unconditionally guaranteed the payment of principal and interest on
the senior notes.
(6) INCOME TAXES
The components of federal and state income taxes for Alliant Energy for the
years ended December 31 were as follows (in millions):
1999 1998 1997
--------- --------- ---------
Current tax expense $142.7 $92.5 $99.6
Deferred tax expense (10.8) (22.2) (6.1)
Amortization of investment tax credits (5.5) (5.6) (5.6)
Affordable housing tax credits (5.9) (6.6) (6.2)
--------- --------- ---------
$120.5 $58.1 $81.7
========= ========= =========
The overall effective income tax rates shown below for the years ended
December 31 were computed by dividing total income tax expense by income
before income taxes and preferred dividend requirements of subsidiaries.
1999 1998 1997
------------- -------------- -------------
Statutory federal income tax rate 35.0% 35.0% 35.0%
State income taxes, net of federal benefits 6.4 8.0 6.4
Affordable housing tax credits (1.9) (4.1) (2.7)
Amortization of investment tax credits (1.7) (3.4) (2.4)
Adjustment of prior period taxes (1.7) (0.4) (2.2)
Merger expenses -- 2.4 0.5
Oil and gas production credits (1.0) (1.6) (0.6)
Property donation (0.3) (1.5) (1.1)
Effect of rate making on property related differences 2.2 1.8 1.1
Other items, net 0.2 (0.2) 1.1
------------- -------------- -------------
Overall effective income tax rate 37.2% 36.0% 35.1%
============= ============== =============
The accumulated deferred income taxes (assets) and liabilities as set forth
below on the Consolidated Balance Sheets at December 31 arise from the
following temporary differences (in millions):
1999 1998
--------- ---------
Property related $669.5 $677.7
McLeod investment 455.1 121.1
Other (106.1) (107.2)
--------- ---------
$1,018.5 $691.6
========= =========
71
Deferred tax liabilities are not recognized for temporary differences related
to investments in foreign subsidiaries and in unconsolidated foreign
affiliates that are essentially permanent in duration. As of December 31,
1999, Alliant Energy had not recorded a U.S. tax provision of approximately
$1.4 million relating to approximately $4.1 million of unremitted earnings
from two of its investments in China as these earnings are expected to be
reinvested permanently overseas in China.
(7) BENEFIT PLANS
(a) Pension Plans and Other Postretirement Benefits - Alliant Energy has
several non-contributory defined benefit pension plans that cover
substantially all of its employees who are subject to a collective bargaining
agreement. Plan benefits are generally based on years of service and
compensation during the employees' latter years of employment. Eligible
employees of Alliant Energy that are not subject to a collective bargaining
agreement are covered by the Alliant Energy Cash Balance Pension Plan, a
non-contributory defined benefit pension plan. During each year of service,
Alliant Energy credits each participant's account with a benefit credit equal
to 5% of base pay as well as a guaranteed minimum interest credit equal to
4%. The projected unit credit actuarial cost method was used to compute
pension cost and the accumulated and projected benefit obligations. Alliant
Energy's policy is to fund all of the pension plans at an amount that is at
least equal to the minimum funding requirements mandated by the Employee
Retirement Income Security Act of 1974, as amended, and that does not exceed
the maximum tax deductible amount for the year.
Alliant Energy also provides certain other postretirement benefits to
retirees, including medical benefits for retirees and their spouses (and
Medicare Part B reimbursement for certain retirees) and, in some cases,
retiree life insurance. IESU's and IPC's funding policy for other
postretirement benefits is generally to fund an amount up to the cost
calculated using SFAS 106, "Employers' Accounting for Postretirement Benefits
Other Than Pensions," while WP&L's funding policy is generally to fund tax
deductible amounts up to the incurred but unclaimed paid medical claim reserve
and tax deductible amounts (if any) to the retiree medical account within the
Cash Balance Pension Plan.
The weighted-average assumptions as of the measurement date of September 30
are as follows:
Qualified Pension Benefits Other Postretirement Benefits
-------------------------------------- -----------------------------------
1999 1998 1997 1999 1998 1997
------------ ------------- ---------- ---------- ---------- -----------
Discount rate 7.75% 6.75% 7.25% 7.75% 6.75% 7.25%
Expected return on plan assets 9% 9% 8-9% 9% 9% 8-9%
Rate of compensation increase 3.5-4.5% 3.5-4.5% 3.5-5.0% 3.5% 3.5% 3.5%
Medical cost trend on covered charges:
Initial trend range N/A N/A N/A 7% 8% 8%
Ultimate trend range N/A N/A N/A 5% 5-6% 5.0-6.5%
The components of Alliant Energy's qualified pension benefits and other postretirement benefits costs are as
follows (in millions):
Qualified Pension Benefits Other Postretirement Benefits
------------------------------------ ---------------------------------
1999 1998 1997 1999 1998 1997
---------- ---------- -------- -------- -------- ---------
Service cost $12.8 $13.8 $13.1 $5.5 $5.1 $4.7
Interest cost 35.6 35.4 32.2 10.4 9.7 9.8
Expected return on plan assets (46.2) (47.2) (39.0) (5.0) (3.7) (2.6)
Amortization of:
Transition obligation (asset) (2.4) (2.4) (2.4) 4.3 4.7 4.9
Prior service cost 2.5 2.8 2.5 (0.3) (0.3) (0.3)
Actuarial loss (gain) 0.2 (0.9) -- (0.8) (1.2) (0.2)
---------- ---------- -------- -------- -------- --------
Total $2.5 $1.5 $6.4 $14.1 $14.3 $16.3
========== ========== ======== ======== ======== =========
During 1998 and 1997, Alliant Energy recognized an additional $10.3 million
and $5.1 million, respectively, of costs in accordance with SFAS 88. The
charges were for severance and early retirement programs in the respective
years. In addition, during 1999, 1998 and 1997, Alliant Energy recognized
$0.5 million, $10.2 million and $1.7 million, respectively, of curtailment
charges relating to Alliant Energy's other postretirement benefits.
72
The assumed medical trend rates are critical assumptions in determining the
service and interest cost and accumulated postretirement benefit obligation
related to postretirement benefit costs. A one percent change in the medical
trend rates for 1999, holding all other assumptions constant, would have the
following effects (in millions):
1 Percent 1 Percent
Increase Decrease
--------------- ---------------
Effect on total of service and interest cost components $2.5 ($2.0)
Effect on postretirement benefit obligation $14.0 ($11.6)
A reconciliation of the funded status of Alliant Energy's plans to the amounts
recognized on Alliant Energy's Consolidated Balance Sheets at December 31 is
presented below (in millions):
Qualified Pension Benefits Other Postretirement Benefits
---------------------------- -------------------------------
1999 1998 1999 1998
----------- ------------ -------------- -------------
Change in benefit obligation:
Net benefit obligation at beginning of year $528.4 $474.2 $153.3 $146.4
Service cost 12.8 13.8 5.5 5.1
Interest cost 35.6 35.4 10.4 9.7
Plan participants' contributions -- -- 1.5 1.3
Plan amendments -- (2.5) (2.5) --
Actuarial loss (gain) (60.7) 24.8 (29.9) (3.6)
Curtailments -- (3.0) (0.3) 1.9
Special termination benefits -- 10.7 -- --
Gross benefits paid (35.1) (25.0) (10.2) (7.5)
----------- ------------ -------------- -------------
Net benefit obligation at end of year 481.0 528.4 127.8 153.3
----------- ------------ -------------- -------------
Change in plan assets:
Fair value of plan assets at beginning of year 506.3 529.1 55.1 50.7
Actual return on plan assets 54.7 2.2 8.2 2.5
Employer contributions -- -- 13.6 7.0
Plan participants' contributions -- -- 1.6 1.3
401(h) assets recognized -- -- -- 1.1
Gross benefits paid (35.1) (25.0) (10.2) (7.5)
----------- ------------ -------------- -------------
Fair value of plan assets at end of year 525.9 506.3 68.3 55.1
----------- ------------ -------------- -------------
Funded status at end of year 44.9 (22.1) (59.5) (98.2)
Unrecognized net actuarial loss (gain) (39.0) 30.3 (39.3) (7.5)
Unrecognized prior service cost 23.2 25.8 (1.5) (1.7)
Unrecognized net transition obligation (asset) (8.2) (10.6) 52.4 60.6
----------- ------------ -------------- -------------
Net amount recognized at end of year $20.9 $23.4 ($47.9) ($46.8)
=========== ============ ============== =============
Amounts recognized on the Consolidated
Balance Sheets consist of:
Prepaid benefit cost $39.1 $38.9 $0.6 $0.9
Accrued benefit cost (18.2) (15.5) (48.5) (47.7)
Additional minimum liability -- (7.7) -- --
Intangible asset -- 7.7 -- --
----------- ------------ -------------- -------------
Net amount recognized at measurement date 20.9 23.4 (47.9) (46.8)
----------- ------------ -------------- -------------
Contributions paid after 9/30 and prior to 12/31 -- -- 6.9 6.8
----------- ------------ -------------- -------------
Net amount recognized at 12/31 $20.9 $23.4 ($41.0) ($40.0)
=========== ============ ============== =============
73
The benefit obligation and fair value of plan assets for the postretirement
welfare plans with benefit obligations in excess of plan assets were $121.3
million and $58.7 million, respectively, as of September 30, 1999 and $146.5
million and $45.3 million, respectively, as of September 30, 1998. The
projected benefit obligation, accumulated benefit obligation and fair value of
plan assets for the pension plans with benefit obligations in excess of plan
assets were $231.4 million, $225.9 million and $219.8 million, respectively,
as of September 30, 1999 and $250.5 million, $241.1 million and $217.9
million, respectively, as of September 30, 1998.
Alliant Energy also sponsors several non-qualified pension plans which cover
certain current and former officers. At December 31, 1999 and 1998, the
funded balances of such plans totaled approximately $5 million. Alliant
Energy's pension benefit obligation under these plans was $28.0 million and
$25.8 million at December 31, 1999 and 1998, respectively. Alliant Energy's
pension expense under these plans was $2.5 million, $4.5 million, and $3.7
million in 1999, 1998 and 1997, respectively.
A significant number of Alliant Energy employees also participate in defined
contribution pension plans (401(k) plans). Alliant Energy's contributions to
the plans, which are based on the participants' level of contribution, were
$7.4 million, $7.7 million, and $5.5 million in 1999, 1998 and 1997,
respectively.
(b) Long-Term Equity Incentive Plan - Alliant Energy has a long-term equity
incentive plan which permits the grant of non-qualified stock options,
incentive stock options, restricted stock, performance shares and performance
units to key employees. As of December 31, 1999, non-qualified stock options,
restricted stock, performance shares and performance units had been granted to
key employees. The maximum number of shares of Alliant Energy common stock
that may be issued under the plan may not exceed 3.8 million (no awards may be
granted on or after January 22, 2004).
Options are granted at the fair market value of the shares on the date of
grant. The options vest over three years and expire no later than 10 years
after the grant date with the exception of participants that retire. Their
options become fully vested upon retirement and remain exercisable at any time
prior to their expiration date, or for three years after the effective date of
the retirement, whichever period is shorter. Participants' options that are
not vested become forfeited when the participant leaves Alliant Energy and
their vested options expire after three months. A summary of the stock option
activity for 1999, 1998 and 1997 is as follows:
1999 1998 1997
------------------------ ------------------------ ------------------------
Weighted Weighted Weighted
Average Average Average
Exercise Exercise Exercise
Shares Price Shares Price Shares Price
------------------------ ------------------------ ------------------------
Outstanding at beginning of year 751,084 $30.83 191,800 $28.98 114,150 $29.56
Options granted 824,564 29.88 636,451 31.32 77,650 28.12
Options exercised -- -- 28.59 -- --
(8,900)
Options forfeited (32,620) 30.55 30.49 -- --
(68,267)
------------------------ ------------------------ ------------------------
Outstanding at end of year 1,543,028 $30.32 751,084 $30.83 191,800 $28.98
======================== ======================== ========================
Exercisable at end of year 333,782 $30.80 38,250 $27.50 -- --
The range of exercise prices for the options outstanding at December 31, 1999
was $27.50 to $31.56.
The value of the options at the grant date using the Black-Scholes pricing
method is as follows:
1999 1998 1997
------------ ------------ ------------
Value of options based on Black-Scholes model $4.71 $4.93 $3.30
Volatility 20.2% 21% 15%
Risk free interest rate 5.78% 5.75% 6.43%
Expected life 10 years 10 years 10 years
Expected dividend yield 6.69% 7.00% 7.00%
74
Alliant Energy follows APB 25, "Accounting for Stock Issued to Employees," to
account for stock options. No compensation cost is recognized because the
option exercise price is equal to the market price of the underlying stock on
the date of grant. Had compensation cost for the plan been determined based
on the Black-Scholes value at the grant dates for awards as prescribed by SFAS
123 "Accounting for Stock-Based Compensation," pro forma net income and
earnings per share would have been:
1999 1998 1997
------- -------- --------
Pro forma net income (in millions) $192.7 $93.5 $144.3
Pro forma earnings per share (basic and diluted) $2.46 $1.22 $1.89
In 1999, 65,752 shares of restricted stock were awarded, all of which were
outstanding at December 31, 1999, and are restricted for a three-year period.
Any unvested shares of restricted stock become fully vested upon retirement.
Participants' restricted stock becomes forfeited when the participant leaves
Alliant Energy. Alliant Energy follows APB 25 to account for restricted
stock. Compensation cost, which is recognized over the three-year restriction
period, was $0.4 million in 1999. Prior to the merger, various restricted
stock awards were granted under the former IES Long-Term Incentive Plan. For
most of the awards, restrictions lapsed effective with the merger.
Compensation cost of $0.4 million, $1.3 million and $0.4 million was
recognized in 1999, 1998 and 1997, respectively.
The payout to key employees of Corporate Services for performance units/shares
is contingent upon achievement of specified levels of total return to
shareowners of Alliant Energy compared with an investor-owned utility peer
group over a three-year period (the payout is contingent upon achievement of
specified earnings growth for key employees of Resources). Performance
units/shares are paid out in cash or shares of Alliant Energy's common stock
and are modified by a performance multiplier, which ranges from 0 to 2.00
based on the three-year average performance criteria. Performance shares have
an intrinsic value equal to the market price of a share on the date of grant
and performance units represent accumulated dividends on the shares underlying
the non-qualified stock options based on the annual dividend rate at the grant
date. Pursuant to APB 25, Alliant Energy accrues the expenses for these plans
over the three-year period the services are performed. Alliant Energy
recognized $1.6 million, $0.2 million and $0.4 million of expense for these
plans in 1999, 1998 and 1997, respectively.
(8) COMMON, PREFERRED AND PREFERENCE STOCK
(a) Common Stock - During 1999, 1998 and 1997, Alliant Energy issued
1,353,971 shares; 890,035 shares and 687,962 shares of common stock under its
various stock plans, respectively. In addition, 260,039 shares were issued in
1998 in connection with the acquisition of oil and gas properties. At
December 31, 1999, Alliant Energy had a total of 7.0 million shares available
for issuance pursuant to its Shareowner Direct Plan, Long-Term Equity
Incentive Plan and 401(k) Savings Plan. Alliant Energy has declared a
quarterly dividend of 50 cents per share each quarter since the consummation
of the merger.
During 1998 and 1997, Alliant Energy reacquired 1,133 shares and 3,278 shares,
respectively, of its common stock on the open market. The shares were
reacquired by IES prior to the consummation of the merger and were
subsequently issued to various Alliant Energy directors and employees. At
December 31, 1999, no shares remained held as treasury stock.
Alliant Energy has a Shareowner Rights Plan whereby rights will be exercisable
only if a person or group acquires, or announces a tender offer to acquire,
15% or more of Alliant Energy's common stock. Each right will initially
entitle shareowners to buy one-half of one share of Alliant Energy's common
stock. The rights will only be exercisable in multiples of two at an initial
price of $95.00 per full share, subject to adjustment. If any shareowner
acquires 15% or more of the outstanding common stock of Alliant Energy, each
right (subject to limitations) will entitle its holder to purchase, at the
right's then current exercise price, a number of common shares of Alliant
Energy or of the acquirer having a market value at the time of twice the
right's per full share exercise price. The Board of Directors is also
authorized to reduce the 15% thresholds to not less than 10%.
75
Alliant Energy's utility subsidiaries each have common stock dividend
restrictions based on their respective bond indentures and articles of
incorporation. Each utility has restrictions on the payment of common stock
dividends that are commonly found with preferred stock. In addition, at IESU
and IPC their ability to pay common stock dividends is restricted based on
requirements associated with sinking funds. WP&L's common stock dividends are
restricted to the extent that such dividend would reduce the common stock
equity ratio to less than 25%. Also at WP&L, in rate order UR-110, the PSCW
ordered that it must approve the payment of dividends by WP&L to Alliant
Energy that are in excess of the level forecasted in the rate order ($58.3
million), if such dividends would reduce WP&L's average common equity ratio
below 52.00% of total capitalization. The dividends paid by WP&L to Alliant
Energy since the rate order was issued have not exceeded the level forecasted
in the rate order.
All non-employee directors are eligible to receive a 25% matching contribution
in Alliant Energy common stock for limited cash purchases, up to $10,000, of
Alliant Energy's common stock through Alliant Energy's Shareowner Direct
Plan. Matching contributions of $2,500 each were made to nine directors in
1999.
(b) Preferred and Preference Stock - In 1993, IPC issued 545,000 shares of
6.40%, $50 par value preferred stock with a final redemption date of May 1,
2022. Under the provisions of the mandatory sinking fund, beginning in 2003,
IPC is required to redeem annually $1.4 million of 6.40% preferred stock
(27,250 shares).
The carrying value of Alliant Energy's cumulative preferred stock at December
31, 1999 and 1998 was $114 million and $113 million, respectively. The fair
market value, based upon the market yield of similar securities and quoted
market prices, at December 31, 1999 and 1998 was $97 million and $109 million,
respectively.
(9) DEBT
(a) Short-Term Debt - Alliant Energy maintains committed bank lines of
credit, most of which are at the bank prime rates, to obtain short-term
borrowing flexibility, including pledging lines of credit as security for any
commercial paper outstanding. Amounts available under these committed lines
of credit totaled $250 million as of December 31, 1999. Commitment fees are
paid to maintain these lines and there are no conditions which restrict the
unused lines of credit. Resources also maintains a revolving credit agreement
with various banking institutions. The unborrowed portion of this agreement
is also used to support Resources' commercial paper program. The amount
available under this agreement as of December 31, 1999, was $150 million.
Resources is also party to a revolving 3-Year Credit Agreement with various
banking institutions. The agreement extends through October 2000, with
one-year extensions available upon agreement by the parties. Unused borrowing
availability under this agreement is also used to support Resources'
commercial paper program. A combined maximum of $450 million of borrowings
under this agreement and the commercial paper program may be outstanding at
any one time. Interest rates and maturities are set at the time of
borrowing. The rates are based upon quoted market prices and the maturities
are less than one year. At December 31, 1999, Resources had $139 million of
commercial paper outstanding and backed by its 3-Year Credit Agreement with
discount rates ranging from 5.90%-6.32%. Resources intends to continue
issuing commercial paper backed by this facility and no conditions existed at
December 31, 1999 that would prevent the issuance of commercial paper or
direct borrowings on its bank lines. As a result, Alliant Energy had been
classifying this debt as long-term. However, since this agreement expires in
October 2000, beginning in October 1999 this debt (including commercial paper
backed by this facility) is now being classified as short-term.
76
Information regarding short-term debt is as follows (dollars in millions):
1999 1998 1997
---------------- ---------------- ---------------
As of year end:
Commercial paper outstanding $374.7 $64.5 $114.5
Notes payable outstanding $50.0 $51.8 $42.0
Discount rates on commercial paper 5.60-6.50% 5.10-6.55% 5.82-5.90%
Interest rates on notes payable 6.30% 5.44-7.00% 5.00-5.90%
For the year ended:
Average amount of short-term debt
(based on daily outstanding balances) $185.9 $126.6 $211.0
Average interest rate on short-term debt 5.44% 5.55% 5.61%
(b) Long-Term Debt - IESU's Indentures and Deeds of Trust securing its First
Mortgage Bonds constitute direct first mortgage liens upon substantially all
tangible public utility property. IESU's Indenture and Deed of Trust securing
its Collateral Trust Bonds constitutes a second lien on substantially all
tangible public utility property while First Mortgage Bonds remain
outstanding. Substantially all of WP&L's and IPC's utility plant is secured
by their First Mortgage Bonds. WP&L also maintains an unsecured indenture
relating to the issuance of debt securities. In addition, Alliant Energy's
long-term debt includes unsecured debentures, notes payable and revenue bonds
related to its affordable housing properties.
Debt maturities (excluding periodic sinking fund requirements, which will not
require additional cash expenditures) for 2000 to 2004 are $54.8 million,
$84.4 million, $2.4 million, $7.5 million and $89.8 million, respectively.
Depending upon market conditions, it is currently anticipated that a majority
of the maturing debt will be refinanced with the issuance of long-term
securities.
The carrying value of Alliant Energy's long-term debt at December 31, 1999 and
1998 was $1,597 million and $1,664 million, respectively. The fair market
value, based upon the market yield of similar securities and quoted market
prices, at December 31, 1999 and 1998 was $1,561 million and $1,753 million,
respectively.
Refer to MD&A for a further discussion of Alliant Energy's debt.
(10) INVESTMENTS AND ESTIMATED FAIR VALUE OF FINANCIAL INSTRUMENTS
Information relating to various investments and financial instruments held by
Alliant Energy is as follows (in millions):
December 31, 1999 December 31, 1998
------------------------------------- -----------------------------------
Gross Gross Unrealized
Carrying Fair Unrealized Carrying Fair Gains/(Losses)
Value Value Gains/(Losses) Value Value
----------- -------- ---------------- ----------- ------- -----------------
Nuclear decommissioning trust funds:
Equity securities $112 $112 $80 $98 $98 $56
Debt securities 159 159 (4) 128 128 3
Total 271 271 76 226 226 59
Investment in McLeod 1,124 1,124 1,096 320 320 291
Investments in New Zealand/Australia 125 131 11 32 44 (0.1)
The fair market value of the New Zealand/Australia investments is generally
based on quoted market prices. The difference in the carrying value and fair
value relates to investments that are not marked to market under SFAS 115,
"Accounting for Certain Investments in Debt and Equity Securities." The
carrying amount of Alliant Energy's current assets and current liabilities
approximates fair value because of the short maturity of such financial
instruments. Since IESU, WP&L and IPC are subject to regulation, any gains or
losses related to the difference between the carrying amount and the fair
value of its financial instruments may not be realized by Alliant Energy's
shareowners.
77
Nuclear Decommissioning Trust Funds - As required by SFAS 115, IESU's and
WP&L's debt and equity security investments in the nuclear decommissioning
trust funds are classified as available for sale. The fair market value of
the nuclear decommissioning trust funds is as reported by the trustee,
adjusted for the tax effect of unrealized gains and losses. Net unrealized
holding gains were recorded as part of accumulated provision for
depreciation. The funds realized gains from the sales of securities of $6.6
million, $1.2 million and $0.2 million in 1999, 1998 and 1997, respectively
(cost of the investments based on specific identification were $111.7 million,
$71.9 million and $68.6 million, respectively).
Investment in McLeod - Alliant Energy held 19.1 million and 20.6 million of
shares of common stock (including 2.6 million unexercised vested options) in
McLeod, a telecommunications company, at December 31, 1999 and 1998,
respectively. The cost basis of the investment, net of the cost to exercise
the options, was $28 million and $29 million at December 31, 1999 and 1998,
respectively. McLeod declared a 2-for-1 stock split which was effective in
July 1999 (the December 1998 shares have been adjusted for the split).
Pursuant to the provisions of SFAS 115, Alliant Energy's investment in McLeod
is considered an available-for-sale security thus the carrying value of the
investment is adjusted to the estimated fair value each quarter based on the
closing price at the end of the quarter. The adjustments do not impact
earnings as the unrealized gains or losses, net of taxes, are recorded
directly to the common equity section of the Consolidated Balance Sheets and
are a component of "Accumulated other comprehensive income." In addition, any
such gains or losses are reflected in current earnings only at the time they
are realized through a sale. Alliant Energy sold approximately 7% (1.4
million shares, as adjusted for the stock split) of its investment in McLeod
in 1999, resulting in pre-tax gains of $40.3 million (proceeds of $40.9
million less a cost basis of $0.6 million as computed under the
first-in-first-out (FIFO) method).
Alliant Energy entered into an agreement in November 1998, as amended, with
McLeod whereby Alliant Energy's ability to sell the McLeod stock is subject to
various restrictions. The agreement provides that until December 31, 2001,
Alliant Energy and its affiliates generally may not sell or otherwise dispose
of shares of McLeod stock beneficially owned by Alliant Energy and its
affiliates, other than to a subsidiary of Alliant Energy, without the prior
written consent of the Board of Directors of McLeod. However, the amended
agreement provides that the Board of Directors of McLeod may permit Alliant
Energy and its affiliates to sell a specified number of shares of McLeod stock
per quarter during specified time periods. In addition, if Alliant Energy and
its affiliates are not provided the opportunity to sell, on an annual basis,
an aggregate number of shares of McLeod stock equal to 15% of the shares of
McLeod stock owned by Alliant Energy and its affiliates as of December 31,
1998, then Alliant Energy may terminate the amended November 1998 agreement.
Investments in Foreign Entities - Alliant Energy has investments in foreign
entities on its Consolidated Balance Sheets that included investments in
several New Zealand and Australian utility entities, investments in several
generation facilities in China and an investment in secured debentures of a
development project in Mexico. The New Zealand and Australian investments are
accounted for under the cost method and the China investments are accounted
for under the equity method. The geographic concentration of these
investments at December 31 was as follows (in millions):
1999 1998
---------- ---------
New Zealand/Australia $125 $32
China 62 36
Mexico 10 --
Other 1 1
---------- ---------
$198 $69
========== =========
Refer to Note 11 for a discussion of Alliant Energy's derivative financial
instruments.
(11) DERIVATIVE FINANCIAL INSTRUMENTS
Information relating to derivative financial instruments utilized by Alliant
Energy is as follows:
(a) Interest Rate Swaps and Forward Contracts - In November 1999, Resources
terminated its two interest rate swap agreements, each with notional amounts
78
of $100 million of debt. The agreements converted variable rate debt into
fixed rate debt and Resources received an insignificant settlement payment
upon termination which was recorded as an offset to interest expense. On
November 1, 1999, Resources entered into an interest rate forward contract
with a notional amount of $250 million related to the anticipated issuance of
$250 million of senior notes. The senior notes were priced on November 4,
1999, and the forward contract was settled, which resulted in a cash payment
of $2.5 million by Resources. Because the fair value of the change in the
forward contract was highly correlated to the fair value of the change in the
senior notes, the $2.5 million is being deferred as an adjustment to the
carrying value of the notes and amortized into interest expense over the life
of the senior notes, which mature in 2009.
At December 31, 1999, WP&L had two interest rate swap agreements outstanding
(both expiring in January 2000), with an aggregate notional amount of $30
million. The agreements converted variable rate debt into fixed rate debt.
If WP&L had terminated the agreements at December 31, 1999, WP&L would have
made an insignificant payment. Settlements on these swaps occurring during
the year were recorded as a component of interest expense.
(b) Utility Gas Commodities Instruments - WP&L uses gas commodity swaps to
reduce the impact of price fluctuations on gas purchased and injected into
storage during the summer months and withdrawn and sold at current market
prices during the winter months. The notional amount of gas commodity swaps
outstanding as of December 31, 1999 and 1998 was 1.9 million and 5.8 million
dekatherms, respectively. Unrealized gains/losses are deferred and accounted
for as hedges of the fair value of the gas in storage as the indexed price
WP&L pays is highly correlated to the market price that WP&L will receive from
customers under the current rate making structure. If WP&L had terminated all
of the agreements existing at December 31, 1999 and 1998, WP&L would have
realized an estimated gain of $0.1 million and $0.8 million, respectively,
based on current NYMEX gas futures contracts adjusted for the proper basis
differential. Settlements of these swaps are recorded as an adjustment to the
cost of gas sold in the period that coincides with the withdrawal and sale of
the hedged gas in storage.
(c) Oil and Gas Commodities Instruments - Whiting is exposed to commodity
price risk in the pricing of its oil and gas production. Alliant Energy
entered into swap transactions in the third quarter of 1999 to hedge the
ultimate sales price for approximately two-thirds of Whiting's anticipated gas
production from November 1, 1999 through December 31, 2000. At December 31,
1999, the notional amount of these swaps was 13.4 million dekatherms and the
estimated fair value was approximately $1.9 million. The fair value was
determined based on the difference between the fixed price of the swaps and
NYMEX futures prices, adjusted for the necessary basis differential. In
December 1999, Alliant Energy entered into a crude oil swap to fix Whiting's
ultimate sales price for 650 barrels per day from December 1, 1999 to December
31, 2000. At December 31, 1999, the estimated fair value of these swaps was
approximately ($0.3) million, as determined by the difference between the
fixed prices of the swaps and NYMEX futures prices for the appropriate
delivery locations. Alliant Energy also used commodity derivative instruments
to hedge a portion of the anticipated sales of Whiting's gas production during
1999. The notional amounts of these derivative instruments was 11,530,000
dekatherms, none of which were outstanding at December 31, 1999. The net
settlements of such instruments resulted in Alliant Energy recognizing a
pre-tax loss of $5.2 million in 1999. All of Whiting's gas and crude oil
swaps are treated as hedges of the anticipated sales of Whiting's production
as the notional amounts and fixed prices of these swaps are highly correlated
to Whiting's volumes of production and the ultimate sales prices of such
production. Settlements related to all of Whiting's swaps are recognized as
income in the periods in which the swap is settled, which coincides with the
sale of the hedged oil and gas production.
(d) Weather Derivatives - WP&L uses weather derivatives to reduce the impact
of weather volatility on its natural gas sales volumes. In September 1998,
WP&L entered into a non-exchange traded "weather collar" with a contract
period commencing on November 1, 1998 and ending on March 31, 1999. The
maximum amount to be paid or received under the collar was $5,000,000. WP&L
recognized a gain in "Miscellaneous, net" on this collar of $2.5 million in
the first quarter of 1999 upon termination of the collar. In August 1999,
WP&L entered into a non-exchange traded "weather collar" with a contract
period commencing on November 1, 1999 and ending on March 31, 2000. The
maximum payment amount is $5,000,000. Pursuant to the requirements of
EITF-99-2, WP&L is accounting for this instrument using the intrinsic value
method and recognized an unrealized gain in "Miscellaneous, net" of $2.4
million in the fourth quarter of 1999.
79
(e) Nuclear Decommissioning Trust Fund Investments - WP&L entered into an
equity collar that uses written options to mitigate the effect of significant
market fluctuations on its common stock investments in its nuclear
decommissioning trust funds. The program is designed to protect the
portfolio's value while allowing the funds to earn a total return modestly in
excess of long-term expectations over the two-year hedge period, which expires
September 2000. The notional amount of the options was $78 million and $52
million at December 31, 1999 and 1998, respectively. The options are reported
at fair market value each reporting period. These fair value changes do not
impact net income as they are recorded as equally offsetting changes in the
investment in nuclear decommissioning trust funds and accumulated
depreciation. The option liability fair value exceeded the premium received
by $17.8 million and $8.9 million at December 31, 1999 and December 31, 1998,
respectively, as reported by the trustee.
(12) COMMITMENTS AND CONTINGENCIES
(a) Construction and Acquisition Program - Plans for Alliant Energy's
construction and acquisition program can be found elsewhere in this report in
the "Liquidity and Capital Resources - Capital Requirements" section of MD&A.
(b) Purchased-Power, Coal and Natural Gas Contracts - Alliant Energy has
entered into purchased-power capacity and coal contracts and its minimum
commitments are as follows (dollars in millions, MWHs and tons in thousands):
Coal
Purchased-Power (including
transportation)
------------------- ----------------------
Dollars MWHs Dollars Tons
-------- --------- --------- -----------
2000 $108.2 1,571 $63.2 16,227
2001 69.6 925 44.5 11,434
2002 47.0 280 19.6 5,991
2003 36.5 280 14.2 4,993
2004 25.2 219 11.7 3,878
Alliant Energy is in the process of negotiating several new coal contracts.
In addition, it expects to supplement its coal contracts with spot market
purchases to fulfill its future fossil fuel needs. Alliant Energy also has
various natural gas supply, transportation and storage contracts outstanding.
The minimum dekatherm commitments, in millions, for 2000-2004 are 185.6,
150.8, 133.2, 110.3 and 9.8, respectively. The minimum dollar commitments for
2000-2004, in millions, are $94.0, $70.3, $47.7, $40.0 and $3.2,
respectively. The gas supply commitments are all index-based. Alliant Energy
expects to supplement its natural gas supply with spot market purchases as
needed.
(c) Information Technology Services - Alliant Energy has an agreement,
expiring in 2004, with EDS for information technology services. Alliant
Energy's anticipated operating and capital expenditures under the agreement for
2000 are estimated to total approximately $16 million. Future costs under the
agreement are variable and are dependent upon Alliant Energy's level of usage
of technological services from EDS.
(d) Financial Guarantees and Commitments - Alliant Energy has financial
guarantees, which were generally issued to support third-party borrowing
arrangements and similar transactions, amounting to $17 million and $18
million outstanding at December 31, 1999 and 1998, respectively. Such
guarantees are not reflected in the consolidated financial statements.
Management believes that the likelihood of Alliant Energy having to make any
material cash payments under these agreements is remote.
In addition, as part of Alliant Energy's electricity trading joint venture
with Cargill, both Alliant Energy and Cargill have made guarantees to certain
counterparties regarding the performance of contracts entered into by the
joint venture. Revocable guarantees of approximately $95 million and $50
million have been issued, of which approximately $20 million and $5 million
were outstanding at December 31, 1999 and 1998, respectively. Under the terms
of the joint venture agreement, any payments required under the guarantees
would be shared by Alliant Energy and Cargill on a 50/50 basis to the extent
the joint venture is not able to reimburse the guarantor for payments made
under the guarantee.
80
As of December 31, 1999 and 1998, Resources had extended commitments to
provide $6.1 million and $19 million, respectively, in nonrecourse, permanent
financing to developers which were secured by affordable housing properties.
Alliant Energy anticipates other lenders will ultimately finance these
properties.
(e) Nuclear Insurance Programs - Public liability for nuclear accidents is
governed by the Price Anderson Act of 1988, which sets a statutory limit of
$9.5 billion for liability to the public for a single nuclear power plant
incident and requires nuclear power plant operators to provide financial
protection for this amount. As required, IESU provides this financial
protection for a nuclear incident at DAEC through a combination of liability
insurance ($200 million) and industry-wide retrospective payment plans ($9.3
billion). Under the industry-wide plan, each operating licensed nuclear
reactor in the U.S. is subject to an assessment in the event of a nuclear
incident at any nuclear plant in the U.S. The owners of DAEC could be
assessed a maximum of $88.1 million per nuclear incident, with a maximum of
$10 million per incident per year (of which IESU's 70% ownership portion would
be approximately $61.7 million and $7 million, respectively) if losses
relating to the incident exceeded $200 million. These limits are subject to
adjustments for changes in the number of participants and inflation in future
years. On a similar note, WP&L, as a 41% owner of Kewaunee, is subject to an
overall assessment of approximately $36.1 million per incident, not to exceed
$4.1 million payable in any given year.
IESU and WP&L are members of NEIL, which provides $1.9 billion of insurance
coverage for IESU and $1.8 billion for WP&L on certain property losses for
property damage, decontamination and premature decommissioning. The proceeds
from such insurance, however, must first be used for reactor stabilization and
site decontamination before they can be used for plant repair and premature
decommissioning. NEIL also provides separate coverage for additional expense
incurred during certain outages. Owners of nuclear generating stations
insured through NEIL are subject to retroactive premium adjustments if losses
exceed accumulated reserve funds. NEIL's accumulated reserve funds are
currently sufficient to more than cover its exposure in the event of a single
incident under the primary and excess property damage or additional expense
coverages. However, IESU could be assessed annually a maximum of $1.9 million
for NEIL primary property, $2.8 million for NEIL excess property and $0.5
million for NEIL additional expenses if losses exceed the accumulated reserve
funds. WP&L could be assessed annually a maximum of $1.1 million for NEIL
primary property, $1.6 million for NEIL excess property and $0.4 million for
NEIL additional expense coverage. IESU and WP&L are not aware of any losses
that they believe are likely to result in an assessment.
In the unlikely event of a catastrophic loss at Kewaunee or DAEC, the amount
of insurance available may not be adequate to cover property damage,
decontamination and premature decommissioning. Uninsured losses, to the
extent not recovered through rates, would be borne by Alliant Energy and could
have a material adverse effect on Alliant Energy's financial condition and
results of operations.
(f) Environmental Liabilities - Alliant Energy had recorded the following
environmental liabilities, and regulatory assets associated with certain of
these liabilities, as of December 31 (in millions):
1999 1998
---------------------------------------------- ----------------------------------------------
Environmental
liabilities IESU WP&L IPC Resources Total IESU WP&L IPC Resources Total
------- --------- -------- ------------ ------- ------- --------- ------- ------------ -------
MGP sites $24.5 $7.3 $16.2 -- $48.0 $26.6 $7.7 $17.5 -- $51.8
NEPA 7.0 4.1 -- -- 11.1 7.8 4.6 -- -- 12.4
Oil and gas
properties -- -- -- $13.0 13.0 -- -- -- $13.0 13.0
Other 0.3 0.1 0.5 0.1 1.0 0.4 -- 0.6 0.2 1.2
------- --------- -------- ------------ ------- ------- --------- ------- ------------ -------
$31.8 $11.5 $16.7 $13.1 $73.1 $34.8 $12.3 $18.1 $13.2 $78.4
======= ========= ======== ============ ======= ======= ========= ======= ============ =======
1999 1998
----------------------------------- -----------------------------------
Regulatory assets IESU WP&L IPC Total IESU WP&L IPC Total
------- ---------- ------- -------- ------- ---------- -------- -------
MGP sites $24.5 $14.2 $15.7 $54.4 $26.6 $14.1 $17.5 $58.2
NEPA 7.7 4.9 -- 12.6 8.4 5.4 -- 13.8
Other 0.2 -- -- 0.2 0.2 -- -- 0.2
------- ---------- ------- -------- ------- ---------- -------- -------
$32.4 $19.1 $15.7 $67.2 $35.2 $19.5 $17.5 $72.2
======= ========== ======= ======== ======= ========== ======== =======
Alliant Energy's significant environmental liabilities are discussed further
below.
81
Manufactured Gas Plant Sites - IESU, WP&L and IPC have current or previous
- ----------------------------
ownership interests in 34, 14 and 9 sites, respectively, previously associated
with the production of gas for which they may be liable for investigation,
remediation and monitoring costs relating to the sites. The companies are
working pursuant to the requirements of various federal and state agencies to
investigate, mitigate, prevent and remediate, where necessary, the
environmental impacts to property, including natural resources, at and around
the sites in order to protect public health and the environment. The
companies each believe that they have completed the remediation at various
sites, although they are still in the process of obtaining final approval from
the applicable environmental agencies for some of these sites.
Each company records environmental liabilities based upon periodic studies,
most recently updated in the third quarter of 1999, related to the MGP sites.
Such amounts are based on the best current estimate of the remaining amount to
be incurred for investigation, remediation and monitoring costs for those
sites where the investigation process has been or is substantially completed,
and the minimum of the estimated cost range for those sites where the
investigation is in its earlier stages. It is possible that future cost
estimates will be greater than current estimates as the investigation process
proceeds and as additional facts become known. The amounts recognized as
liabilities are reduced for expenditures made and are adjusted as further
information develops or circumstances change. Costs of future expenditures
for environmental remediation obligations are not discounted to their fair
value.
Management currently estimates the range of remaining costs to be incurred for
the investigation, remediation and monitoring of all Alliant Energy sites to
be approximately $33 million to $61 million. IESU, WP&L and IPC currently
estimate their share of the remaining costs to be incurred to be approximately
$16 million to $33 million, $6 million to $8 million, and $11 million to $20
million, respectively.
Under the current rate making treatment approved by the PSCW, the MGP
expenditures of WP&L, net of any insurance proceeds, are deferred and
collected from gas customers over a five-year period after new rates are
implemented. The MPUC also allows the deferral of MGP-related costs
applicable to the Minnesota sites and IPC has been successful in obtaining
approval to recover such costs in rates in Minnesota. The IUB has permitted
utilities to recover prudently incurred costs. As a result, regulatory assets
have been recorded by each company which reflect the probable future rate
recovery, where applicable. Considering the current rate treatment, and
assuming no material change therein, IESU, WP&L and IPC believe that the
clean-up costs incurred for these MGP sites will not have a material adverse
effect on their respective financial conditions or results of operations.
Settlement has been reached with all of IESU's and WP&L's insurance carriers
regarding reimbursement for its MGP-related costs and all issues have been
resolved. IPC has settled with all but one of its insurance carriers. The
following insurance recoveries were available as of December 31 (in millions):
1999 1998
--------- --------
IESU $18.5 $18.5
IPC 5.3 4.8
WP&L 2.1 2.1
--------- --------
$25.9 $25.4
========= ========
Pursuant to their applicable rate making treatment, IESU and IPC have recorded
their recoveries in "Other long-term liabilities and deferred credits" and
WP&L has recorded its recoveries as an offset against its regulatory assets.
National Energy Policy Act of 1992 - NEPA requires owners of nuclear power
- -----------------------------------
plants to pay a special assessment into a "Uranium Enrichment Decontamination
and Decommissioning Fund." The assessment is based upon prior nuclear fuel
purchases. IESU is recovering the costs associated with this assessment
through its electric fuel adjustment clauses over the period the costs are
assessed. Alliant Energy continues to pursue relief from this assessment
through litigation.
Oil and Gas Properties Dismantlement and Abandonment Costs - Whiting is
- ----------------------------------------------------------
responsible for certain dismantlement and abandonment costs related to various
82
off-shore oil and gas platforms (and related on-shore plants and equipment),
the most significant of which is located off the coast of California. Whiting
estimates the total costs for these properties to be approximately $13 million
and the most significant expenditures are not expected to be incurred until
2004. In accordance with applicable accounting requirements, Whiting has
accrued these costs.
(g) Spent Nuclear Fuel - Nuclear Waste Policy Act of 1982 assigned
responsibility to the DOE to establish a facility for the ultimate disposition
of high level waste and spent nuclear fuel and authorized the DOE to enter
into contracts with parties for the disposal of such material beginning in
January 1998. IESU and WP&L entered into such contracts and have made the
agreed payments to the Nuclear Waste Fund held by the U.S. Treasury. The
companies were subsequently notified by the DOE that it was not able to begin
acceptance of spent nuclear fuel by the January 31, 1998 deadline.
Furthermore, the DOE has experienced significant delays in its efforts and
material acceptance is now expected to occur no earlier than 2010 with the
possibility of further delay being likely. Alliant Energy has participated in
several litigation proceedings against the DOE on this issue and the
respective courts have affirmed the DOE's responsibility for spent nuclear
fuel acceptance. Alliant Energy is evaluating its options for recovery of
damages due to the DOE's delay in accepting spent nuclear fuel.
The Nuclear Waste Policy Act of 1982 assigns responsibility for interim
storage of spent nuclear fuel to generators of such spent nuclear fuel, such
as IESU and WP&L. In accordance with this responsibility, IESU and WP&L have
been storing spent nuclear fuel on site at DAEC and Kewaunee, respectively,
since plant operations began. IESU will have to increase its spent fuel
storage capacity at DAEC to store all of the spent fuel that will be produced
before the current license expires in 2014. To provide assurance that both
the operating and post-shutdown storage needs are satisfied, construction of a
dry cask storage facility is being planned. With minor modifications planned
for 2001, Kewaunee would have sufficient fuel storage capacity to store all of
the fuel it will generate through the end of the NRC license life in 2013. No
decisions have been made concerning post-shutdown storage needs. Legislation
is being considered on the federal level that would, among other provisions,
expand the DOE's permanent spent nuclear fuel storage to include interim
storage for spent nuclear fuel as early as 2003. This legislation has been
passed in the U.S. Senate and submitted in the U.S. House. The prospects for
the legislation being approved by the U.S. Senate and the President, and
subsequent successful implementation by the DOE, are uncertain at this time.
(h) Decommissioning of DAEC and Kewaunee - Pursuant to the most recent
electric rate case order, the IUB and PSCW allow IESU and WP&L to recover $6
million and $16 million annually for their share of the cost to decommission
DAEC and Kewaunee, respectively. Decommissioning expense is included in
"Depreciation and amortization" in the Consolidated Statements of Income and
the cumulative amount is included in "Accumulated depreciation" on the
Consolidated Balance Sheets to the extent recovered through rates.
Additional information relating to the decommissioning of DAEC and Kewaunee
included in the most recent electric rate orders (dollars in millions):
DAEC Kewaunee
------------------------- ----------------------
Assumptions relating to current rate recovery figures:
Alliant Energy's share of estimated decommissioning cost $252.8 $200.8
Year dollars in 1993 1999
Method to develop estimate NRC minimum formula Site-specific study
Annual inflation rate 4.91% 5.83%
Decommissioning method Prompt dismantling Prompt dismantling
and removal and removal
Year decommissioning to commence 2014 2013
After-tax return on external investments:
Qualified 7.34% 5.62%
Non-qualified 5.98% 6.97%
External trust fund balance at December 31, 1999 $105.1 $166.2
Internal reserve at December 31, 1999 $21.7 --
After-tax earnings (losses) on external trust funds in 1999 $4.8 ($4.3)
83
The rate recovery figures for DAEC only included an inflation estimate through
1997. Both IESU and WP&L are funding all rate recoveries for decommissioning
into external trust funds and funding on a tax-qualified basis to the extent
possible. All of the rate recovery assumptions are subject to change in
future regulatory proceedings. In accordance with their respective regulatory
requirements, IESU and WP&L record the earnings on the external trust funds as
interest income with a corresponding entry to interest expense at IESU and to
depreciation expense at WP&L. The earnings accumulate in the external trust
fund balances and in accumulated depreciation on utility plant.
IESU's 70% share of the estimated cost to decommission DAEC based on the most
recent site-specific study completed in 1998 is $334.2 million, in 1998
dollars. This study includes the costs to terminate DAEC's NRC license and to
return the site to a greenfield condition. IESU's 70% share of the estimated
cost to decommission DAEC based on the most recent NRC minimum formula, using
the direct disposal method, is $351.2 million in 1998 dollars. The NRC
minimum formula is intended to apply only to the cost of terminating DAEC's
NRC license. The additional decommissioning expense funding requirements
which should result from these updated studies are not reflected in IESU's
rates.
(i) Legal Proceedings - Alliant Energy is involved in legal and
administrative proceedings before various courts and agencies with respect to
matters arising in the ordinary course of business. Although unable to
predict the outcome of these matters, Alliant Energy believes that appropriate
reserves have been established and final disposition of these actions will not
have a material adverse effect on its financial condition or results of
operations.
(13) JOINTLY-OWNED ELECTRIC UTILITY PLANT
Under joint ownership agreements with other Iowa and Wisconsin utilities,
IESU, WP&L and IPC have undivided ownership interests in jointly-owned
electric generating stations and related transmission facilities. Each of the
respective owners is responsible for the financing of its portion of the
construction costs. Kilowatt-hour generation and operating expenses are
divided on the same basis as ownership with each owner reflecting its
respective costs in its Consolidated Statements of Income. Information
relative to IESU's, WP&L's and IPC's ownership interest in these facilities at
December 31, 1999 is as follows (dollars in millions):
1999 1998
-------------------------------- -----------------------------
Plant Accumulated Accumulated
Name-plate Provision Plant Provision
Ownership In-service MW Plant in for in for
Interest % Date Capacity Service Depreciation CWIP Service Depreciation CWIP
- ------------------- ----------- -------- ----------- -- --------- ------------- -------- -------- ------------- -------
IESU
Coal:
Ottumwa Unit 1 48.0 1981 716 $195.3 $107.8 $0.5 $193.1 $102.7 $0.8
Neal Unit 3 28.0 1975 515 59.2 32.1 -- 59.0 32.4 0.1
Nuclear:
DAEC 70.0 1974 520 515.8 264.4 8.6 507.1 247.2 1.4
--------- ------------- -------- -------- ------------- -------
Total IESU $770.3 $404.3 $9.1 $759.2 $382.3 $2.3
--------- ------------- -------- -------- ------------- -------
WP&L
Coal:
Columbia Energy 1975 &
Center 46.2 1978 1,023 $163.2 $97.8 $2.6 $161.5 $93.8 $1.4
Edgewater Unit 4 68.2 1969 330 52.7 32.0 0.7 52.4 30.8 0.4
Edgewater Unit 5 75.0 1985 380 229.3 92.2 0.6 229.0 85.9 0.2
Nuclear:
Kewaunee 41.0 1974 535 135.0 100.7 13.6 132.2 93.7 6.4
--------- ------------- ------- --------- ------------ -------
Total WP&L $580.2 $322.7 $17.5 $575.1 $304.2 $8.4
--------- ------------- ------- --------- ------------ -------
IPC
Coal:
Neal Unit 4 21.5 1979 640 $83.5 $51.1 $-- $82.1 $48.4 $1.5
Louisa Unit 1 4.0 1983 738 24.7 12.5 -- 24.7 11.7 --
--------- ------------- ------- --------- ------------ -------
Total IPC $108.2 $63.6 $-- $106.8 $60.1 $1.5
--------- ------------- ------- --------- ------------ -------
Total Alliant Energy $1,458.7 $790.6 $26.6 $1,441.1 $746.6 $12.2
========= ============= ======= ========= ============ =======
84
(14) SEGMENTS OF BUSINESS
Alliant Energy's principal business segments are:
o Regulated domestic utilities - consists of Alliant Energy's three
regulated utility operating companies (IESU, WP&L and IPC) serving
customers in Iowa, Wisconsin, Minnesota and Illinois. The regulated
domestic utility business is broken down into three segments which are: a)
electric operations; b) gas operations; and c) other, which includes the
water and steam businesses and the unallocated portions of the utility
business.
o Non-regulated businesses - represents the operations of Resources and
its subsidiaries. This includes domestic and international energy products
and services businesses; industrial services, which includes environmental,
engineering and transportation services; investments in affordable housing
initiatives; and investments in various other strategic initiatives.
o Other - includes the operations of Alliant Energy's parent company and
Corporate Services, as well as any reconciling/eliminating entries.
Intersegment revenues were not material to Alliant Energy's operations and
there was no single customer whose revenues exceeded 10% or more of Alliant
Energy's consolidated revenues. Refer to Note 10 for a breakdown of Alliant
Energy's international investments by country.
Certain financial information relating to Alliant Energy's significant
business segments and products and services is presented below:
Regulated Domestic Utilities Non-regulated Alliant Energy
----------------------------------------------
Electric Gas Other Total Businesses Other Consolidated
- ----------------------------------------------------------------------------------------------------------------------------
(in millions)
1999
Operating revenue $1,548.9 $ 314.3 $32.1 $1,895.3 $305.0 ($2.3) $2,198.0
Depreciation and
amortization expense 219.3 25.2 2.9 247.4 31.7 -- 279.1
Operating income (loss) 345.1 27.4 5.3 377.8 (1.3) -- 376.5
Interest expense, net of AFUDC 100.7 100.7 24.8 3.4 128.9
Preferred and preference
dividends 6.7 6.7 -- -- 6.7
Net (income) loss from equity
method subsidiaries (0.3) (0.3) (2.9) 0.2 (3.0)
Gains on sales of McLeod stock -- -- (40.3) -- (40.3)
Miscellaneous, net (other than
equity income/loss) (5.4) (5.4) (27.6) 0.1 (32.9)
Income tax expense (benefit) 115.0 115.0 6.9 (1.4) 120.5
Net income (loss) 161.1 161.1 37.8 (2.3) 196.6
Total assets 3,321.8 477.6 385.2 4,184.6 1,848.6 42.5 6,075.7
Investments in equity method
subsidiaries 5.7 5.7 74.0 -- 79.7
Construction and acquisition
expenditures 246.9 35.5 3.3 285.7 192.1 0.8 478.6
- ----------------------------------------------------------------------------------------------------------------------------
85
Regulated Domestic Utilities Non-regulated Alliant Energy
------------------------------------------------
Electric Gas Other Total Businesses Other Consolidated
- ----------------------------------------------------------------------------------------------------------------------------
(in millions)
1998
Operating revenues $1,567.5 $295.6 $31.2 $1,894.3 $238.7 ($2.1) $2,130.9
Depreciation and
amortization expense 219.4 23.7 2.6 245.7 33.8 -- 279.5
Operating income (loss) 271.5 16.0 5.6 293.1 (8.6) (1.2) 283.3
Interest expense, net of AFUDC 97.0 97.0 23.3 2.3 122.6
Preferred and preference
dividends 6.7 6.7 -- -- 6.7
Net (income) loss from equity
method subsidiaries (0.9) (0.9) 2.2 -- 1.3
Miscellaneous, net (other than
equity income/loss) 3.5 3.5 (8.0) 2.4 (2.1)
Income tax expense (benefit) 77.2 77.2 (17.2) (1.9) 58.1
Net income (loss) 109.6 109.6 (8.9) (4.0) 96.7
Total assets 3,268.5 477.0 386.0 4,131.5 869.2 (41.4) 4,959.3
Investments in equity method
subsidiaries 5.2 5.2 49.4 -- 54.6
Construction and acquisition
expenditures 233.7 33.2 2.3 269.2 102.9 -- 372.1
- ----------------------------------------------------------------------------------------------------------------------------
Regulated Domestic Utilities Non-regulated Alliant Energy
------------------------------------------------
Electric Gas Other Total Businesses Other Consolidated
- ----------------------------------------------------------------------------------------------------------------------------
(in millions)
1997
- ----
Operating revenues $1,515.7 $393.9 $30.9 $1,940.5 $362.0 ($1.9) $2,300.6
Depreciation and
amortization expense 201.7 21.6 2.4 225.7 34.0 -- 259.7
Operating income (loss) 316.9 29.3 2.2 348.4 (6.8) (5.2) 336.4
Interest expense, net of AFUDC 95.7 95.7 23.2 (1.6) 117.3
Preferred and preference
dividends 6.7 6.7 -- -- 6.7
Net (income) loss from equity
method subsidiaries -- -- 0.8 -- 0.8
Miscellaneous, net (other than
equity income/loss) (8.2) (8.2) (8.3) 1.8 (14.7)
Income tax expense (benefit) 101.7 101.7 (18.6) (1.4) 81.7
Net income (loss) 152.5 152.5 (4.0) (3.9) 144.6
Total assets 3,262.3 471.5 343.2 4,077.0 838.5 8.1 4,923.6
Investments in equity method
subsidiaries 5.7 5.7 39.2 -- 44.9
Construction and acquisition
expenditures 217.0 34.0 5.7 256.7 71.3 -- 328.0
- ----------------------------------------------------------------------------------------------------------------------------
86
Products and Services
Revenues
-----------------------------------------------------------------------------------------------------------------
Regulated Domestic Utilities Non-regulated Businesses
------------------------------------ ---------------------------------------------------------------------------
Total
Industrial Oil and Gas Non-regulated
Year Electric Gas Other Services Production Transportation Other Businesses
- -------------------------------------------- ---------------------------------------------------------------------------
(in millions)
1999 $1,548.9 $314.3 $32.1 $196.0 $62.6 $21.6 $24.8 $305.0
1998 1,567.5 295.6 31.2 127.2 64.6 22.0 24.9 238.7
1997 1,515.7 393.9 30.9 245.4 68.9 21.3 26.4 362.0
(15) SELECTED CONSOLIDATED QUARTERLY FINANCIAL DATA
Quarter Ended
------------------------------------------------------------------------
March 31 June 30 September 30 December 31
----------------- ---------------- ------------------ -----------------
(in millions, except per share data)
1999
Operating revenues $546.9 $486.1 $598.3 $566.7
Operating income 93.0 60.2 130.8 92.5
Net income * 41.7 38.6 71.5 44.8
Earnings per average common
share (basic and diluted) * 0.54 0.49 0.91 0.57
1998
Operating revenues $556.3 $491.0 $555.3 $528.3
Operating income 73.9 32.6 122.2 54.6
Net income (loss) ** 28.9 (9.1) 51.7 25.2
Earnings per average common
share (basic and diluted) ** 0.38 (0.12) 0.67 0.33
* In the second and fourth quarters of 1999, Alliant Energy realized pre-tax
gains on the sales of McLeod stock of approximately $34 million and $6 million,
respectively.
** Net income for 1998 was impacted by the recording of approximately $10
million, $35 million, $6 million and $3 million of pre-tax merger-related
expenses in the first, second, third and fourth quarters, respectively.
(16) SUBSEQUENT EVENTS
In January 2000, Resources acquired a non-controlling interest in four
Brazilian electric utilities serving more than 820,000 customers for a total
investment of approximately $347 million.
On January 25, 2000, Resources committed to a private placement of
exchangeable senior notes in the original aggregate principal amount of $402.5
million, due in 2030, with a closing date of February 1, 2000. The
exchangeable senior notes have an interest rate of 7.25% through February 15,
2003 and 2.5% thereafter. The exchangeable senior notes are exchangeable for
cash based upon the higher of the amount borrowed or the value of McLeod Class
A Common Stock. Alliant Energy has agreed to fully and unconditionally
guarantee the payment of principal and interest on the exchangeable senior
notes.
Refer to the "Liquidity and Capital Resources - Future Considerations" section
of MD&A for additional details.
87
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Shareowners of IES Utilities Inc.:
We have audited the accompanying consolidated balance sheets and
statements of capitalization of IES Utilities Inc. (an Iowa
corporation) and subsidiaries as of December 31, 1999 and 1998, and
the related consolidated statements of income, retained earnings
and cash flows for each of the three years in the period ended
December 31, 1999. These financial statements and the supplemental
schedule referred to below are the responsibility of the Company's
management. Our responsibility is to express an opinion on these
financial statements and supplemental schedule based on our audits.
We conducted our audits in accordance with generally accepted
auditing standards. Those standards require that we plan and
perform the audit to obtain reasonable assurance about whether the
financial statements are free of material misstatement. An audit
includes examining, on a test basis, evidence supporting the
amounts and disclosures in the financial statements. An audit also
includes assessing the accounting principles used and significant
estimates made by management, as well as evaluating the overall
financial statement presentation. We believe that our audits
provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present
fairly, in all material respects, the financial position of IES
Utilities Inc. and subsidiaries as of December 31, 1999 and 1998,
and the results of their operations and their cash flows for each
of the three years in the period ended December 31, 1999, in
conformity with generally accepted accounting principles.
Our audit was made for the purpose of forming an opinion on the basic
financial statements taken as a whole. The schedule listed in Item
14(a)(2) is presented for purposes of complying with the Securities and
Exchange Commission's rules and is not part of the basic financial
statements. This schedule has been subjected to the auditing procedures
applied in the audit of the basic financial statements and, in our
opinion, fairly states in all material respects the financial data
required to be set forth therein in relation to the basic financial
statements taken as a whole.
/s/ ARTHUR ANDERSEN LLP
ARTHUR ANDERSEN LLP
Milwaukee, Wisconsin
January 28, 2000
88
IES UTILITIES INC.
CONSOLIDATED STATEMENTS OF INCOME
Year Ended December 31,
1999 1998 1997
- --------------------------------------------------------------------------------------------------------
(in thousands)
Operating revenues:
Electric utility $627,950 $639,423 $604,270
Gas utility 145,825 141,279 183,517
Steam and other 26,921 26,228 26,191
---------------- ---------------- ----------------
800,696 806,930 813,978
---------------- ---------------- ----------------
- --------------------------------------------------------------------------------------------------------
Operating expenses:
Electric and steam production fuels 95,247 113,181 108,344
Purchased power 82,402 71,637 74,098
Cost of gas sold 88,308 84,642 126,631
Other operation 174,417 187,932 161,418
Maintenance 48,504 52,040 53,833
Depreciation and amortization 101,053 93,965 89,754
Taxes other than income taxes 49,266 48,537 46,130
---------------- ---------------- ----------------
639,197 651,934 660,208
---------------- ---------------- ----------------
- --------------------------------------------------------------------------------------------------------
Operating income 161,499 154,996 153,770
---------------- ---------------- ----------------
- --------------------------------------------------------------------------------------------------------
Interest expense and other:
Interest expense 51,852 52,354 52,791
Allowance for funds used during construction (2,366) (3,351) (2,309)
Miscellaneous, net (3,818) 2,589 2,279
---------------- ---------------- ----------------
45,668 51,592 52,761
---------------- ---------------- ----------------
- --------------------------------------------------------------------------------------------------------
Income before income taxes 115,831 103,404 101,009
---------------- ---------------- ----------------
- --------------------------------------------------------------------------------------------------------
Income taxes 49,385 41,494 42,216
---------------- ---------------- ----------------
- --------------------------------------------------------------------------------------------------------
Net income 66,446 61,910 58,793
---------------- ---------------- ----------------
- --------------------------------------------------------------------------------------------------------
Preferred dividend requirements 914 914 914
---------------- ---------------- ----------------
- --------------------------------------------------------------------------------------------------------
Earnings available for common stock $65,532 $60,996 $57,879
================ ================ ================
- --------------------------------------------------------------------------------------------------------
IES UTILITIES INC.
CONSOLIDATED STATEMENTS OF RETAINED EARNINGS
Year Ended December 31,
1999 1998 1997
- --------------------------------------------------------------------------------------------------------
(in thousands)
Balance at beginning of year $275,372 $233,216 $231,337
Net income 66,446 61,910 58,793
Cash dividends declared on common stock (87,951) (18,840) (56,000)
Cash dividends declared on preferred stock (914) (914) (914)
---------------- ---------------- ----------------
Balance at end of year $252,953 $275,372 $233,216
================ ================ ================
- --------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
89
IES UTILITIES INC.
CONSOLIDATED BALANCE SHEETS
December 31,
ASSETS 1999 1998
- --------------------------------------------------------------------------------------------------------------
(in thousands)
Property, plant and equipment:
Utility -
Plant in service -
Electric $2,196,895 $2,140,322
Gas 207,769 198,488
Steam 59,929 55,797
Common 147,845 106,940
----------------- -----------------
2,612,438 2,501,547
Less - Accumulated depreciation 1,311,996 1,209,204
----------------- -----------------
1,300,442 1,292,343
Construction work in progress 37,572 48,991
Leased nuclear fuel, net of amortization 39,284 25,644
----------------- -----------------
1,377,298 1,366,978
Other property, plant and equipment, net of accumulated
depreciation and amortization of $2,094 and $1,948, respectively 5,481 5,623
----------------- -----------------
1,382,779 1,372,601
----------------- -----------------
- --------------------------------------------------------------------------------------------------------------
Current assets:
Cash and temporary cash investments 5,720 4,175
Temporary cash investments with associated companies - 53,729
Accounts receivable:
Customer, less allowance for doubtful
accounts of $824 and $1,058, respectively 14,130 16,703
Associated companies 5,696 2,662
Other, less allowance for doubtful accounts
of $817 and $357, respectively 12,864 10,346
Income tax refunds receivable 6,007 1,754
Production fuel, at average cost 12,312 11,863
Materials and supplies, at average cost 24,722 25,591
Gas stored underground, at average cost 11,462 12,284
Adjustment clause balances 11,099 -
Regulatory assets 18,569 23,487
Prepayments and other 2,921 2,431
----------------- -----------------
125,502 165,025
----------------- -----------------
- --------------------------------------------------------------------------------------------------------------
Investments:
Nuclear decommissioning trust funds 105,056 91,691
Other 6,119 6,019
----------------- -----------------
111,175 97,710
----------------- -----------------
- --------------------------------------------------------------------------------------------------------------
Other assets:
Regulatory assets 123,031 137,908
Deferred charges and other 13,321 15,734
----------------- -----------------
136,352 153,642
----------------- -----------------
- --------------------------------------------------------------------------------------------------------------
Total assets $1,755,808 $1,788,978
================= =================
- --------------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
90
IES UTILITIES INC.
CONSOLIDATED BALANCE SHEETS (CONTINUED)
December 31,
CAPITALIZATION AND LIABILITIES 1999 1998
- --------------------------------------------------------------------------------------------------------------------
(in thousands)
Capitalization (See Consolidated Statements of Capitalization):
Common stock $33,427 $33,427
Additional paid-in capital 279,042 279,042
Retained earnings 252,953 275,372
------------------ -----------------
Total common equity 565,422 587,841
Cumulative preferred stock, not mandatorily redeemable 18,320 18,320
Long-term debt (excluding current portion) 551,079 602,020
------------------ -----------------
1,134,821 1,208,181
------------------ -----------------
- --------------------------------------------------------------------------------------------------------------------
Current liabilities:
Current maturities and sinking funds 51,196 50,140
Capital lease obligations 13,307 11,965
Notes payable to associated companies 56,946 -
Accounts payable 41,273 43,953
Accounts payable to associated companies 17,438 22,487
Accrued payroll and vacations 7,816 6,365
Accrued interest 10,833 12,045
Accrued taxes 44,259 55,295
Accumulated refueling outage provision 1,455 6,605
Environmental liabilities 5,530 5,660
Other 8,817 17,617
------------------ -----------------
258,870 232,132
------------------ -----------------
- --------------------------------------------------------------------------------------------------------------------
Other long-term liabilities and deferred credits:
Accumulated deferred income taxes 225,961 224,510
Accumulated deferred investment tax credits 26,682 29,243
Environmental liabilities 26,292 29,195
Pension and other benefit obligations 27,734 25,655
Capital lease obligations 25,977 13,679
Other 29,471 26,383
------------------ -----------------
362,117 348,665
------------------ -----------------
- --------------------------------------------------------------------------------------------------------------------
Commitments and contingencies (Note 12)
- --------------------------------------------------------------------------------------------------------------------
Total capitalization and liabilities $1,755,808 $1,788,978
================== =================
- --------------------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
91
IES UTILITIES INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
Year Ended December 31,
1999 1998 1997
- ------------------------------------------------------------------------------------------------------------------------------
(in thousands)
Cash flows from operating activities:
Net income $66,446 $61,910 $58,793
Adjustments to reconcile net income to net cash
flows from operating activities:
Depreciation and amortization 101,053 93,965 89,754
Amortization of leased nuclear fuel 11,400 12,513 14,774
Amortization of deferred energy efficiency expenditures 16,000 18,707 10,987
Deferred taxes and investment tax credits (6,399) (17,921) (16,059)
Refueling outage provision (5,150) (4,001) 9,290
Impairment of regulatory assets - 8,969 -
Other 1,355 (346) 3,952
Other changes in assets and liabilities:
Accounts receivable (2,979) 9,690 (5,670)
Gas stored underground 822 4,908 (3,740)
Accounts payable (7,729) 3,158 (11,198)
Accrued taxes (11,036) (3,701) 18,043
Adjustment clause balances (14,530) 8,829 5,354
Benefit obligations and other 12,450 9,433 16,020
--------------- --------------- ---------------
Net cash flows from operating activities 161,703 206,113 190,300
--------------- --------------- ---------------
- ------------------------------------------------------------------------------------------------------------------------------
Cash flows used for financing activities:
Common stock dividends declared (87,951) (18,840) (56,000)
Dividends payable (4,840) 4,840 -
Preferred stock dividends (914) (914) (914)
Proceeds from issuance of long-term debt - 10,000 190,000
Reductions in long-term debt (50,140) (10,140) (63,140)
Net change in short-term borrowings 56,946 - (135,000)
Principal payments under capital lease obligations (12,887) (13,250) (12,964)
Other (20) (137) (871)
--------------- --------------- ---------------
Net cash flows used for financing activities (99,806) (28,441) (78,889)
--------------- --------------- ---------------
- ------------------------------------------------------------------------------------------------------------------------------
Cash flows used for investing activities:
Utility construction expenditures (107,342) (115,371) (108,966)
Deferred energy efficiency expenditures - - (8,450)
Nuclear decommissioning trust funds (6,008) (6,008) (6,008)
Other (731) 1,381 635
--------------- --------------- ---------------
Net cash flows used for investing activities (114,081) (119,998) (122,789)
--------------- --------------- ---------------
- ------------------------------------------------------------------------------------------------------------------------------
Net increase (decrease) in cash and temporary cash investments (52,184) 57,674 (11,378)
--------------- --------------- ---------------
- ------------------------------------------------------------------------------------------------------------------------------
Cash and temporary cash investments at beginning of period 57,904 230 11,608
--------------- --------------- ---------------
- ------------------------------------------------------------------------------------------------------------------------------
Cash and temporary cash investments at end of period $5,720 $57,904 $230
=============== =============== ===============
- ------------------------------------------------------------------------------------------------------------------------------
Supplemental cash flow information:
Cash paid during the period for:
Interest $47,307 $50,177 $46,377
=============== =============== ===============
Income taxes $70,779 $64,738 $41,422
=============== =============== ===============
Noncash investing and financing activities-
Capital lease obligations incurred $25,040 $1,426 $16,781
=============== =============== ===============
- ------------------------------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
92
IES UTILITIES INC.
CONSOLIDATED STATEMENTS OF CAPITALIZATION
December 31,
1999 1998
- ----------------------------------------------------------------------------------------------------------------------------
(in thousands, except share amounts)
Common equity:
Common stock - $2.50 par value - authorized 24,000,000 shares;
13,370,788 shares outstanding $33,427 $33,427
Additional paid-in capital 279,042 279,042
Retained earnings 252,953 275,372
------------------ ------------------
565,422 587,841
------------------ ------------------
- ----------------------------------------------------------------------------------------------------------------------------
Cumulative preferred stock:
Cumulative, par value $50 per share, not mandatorily redeemable
- authorized 466,406 shares; 366,406 shares outstanding:
6.10% series, 100,000 shares outstanding 5,000 5,000
4.80% series, 146,406 shares outstanding 7,320 7,320
4.30% series, 120,000 shares outstanding 6,000 6,000
------------------ ------------------
18,320 18,320
------------------ ------------------
- ----------------------------------------------------------------------------------------------------------------------------
Long-term debt:
Collateral Trust Bonds:
7.65% series, due 2000 50,000 50,000
7.25% series, due 2006 60,000 60,000
6-7/8% series, due 2007 55,000 55,000
6% series, due 2008 50,000 50,000
7% series, due 2023 50,000 50,000
5.5% series, due 2023 19,400 19,400
------------------ ------------------
284,400 284,400
First Mortgage Bonds:
Series Y, 8-5/8%, due 2001 60,000 60,000
Series Z, 7.6%, retired in 1999 - 50,000
9-1/8% series, due 2001 21,000 21,000
7-1/4% series, due 2007 30,000 30,000
------------------ ------------------
111,000 161,000
Pollution control obligations:
5.75%, due serially 2000 to 2003 2,996 3,136
Variable rate (5.45% at December 31, 1999), due 2000 to 2010 11,100 11,100
Variable/fixed rate series 1998 (4.25% through 2003), due 2023 10,000 10,000
------------------ ------------------
24,096 24,236
Subordinated Deferrable Interest Debentures, 7-7/8%, due 2025 50,000 50,000
Senior Debentures, 6-5/8%, due 2009 135,000 135,000
------------------ ------------------
604,496 654,636
------------------ ------------------
Less:
Current maturities (51,196) (50,140)
Unamortized debt premium and (discount), net (2,221) (2,476)
------------------ ------------------
551,079 602,020
------------------ ------------------
- ----------------------------------------------------------------------------------------------------------------------------
Total capitalization $1,134,821 $1,208,181
================== ==================
- ----------------------------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
93
IES UTILITIES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Except as modified below, the Alliant Energy Notes to Consolidated Financial
Statements are incorporated by reference insofar as they relate to IESU.
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
(a) General - The Consolidated Financial Statements include the accounts of
IESU and its consolidated subsidiaries. In the fourth quarter of 1999,
IESU's subsidiaries were merged into IESU. IESU is a subsidiary of Alliant
Energy and is engaged principally in the generation, transmission,
distribution and sale of electric energy; the purchase, distribution,
transportation and sale of natural gas; and steam services. All of IESU's
retail customers are located in Iowa.
(i) Operating Revenues - IESU accrues revenues for services rendered but
unbilled at month-end in order to more properly match revenues with
expenses. In the third quarter of 1999, IESU recorded a $5 million increase
in the estimate of utility services rendered but unbilled at month-end. This
change was a result of the implementation of a refined estimation process
compared with the unbilled revenues recorded at June 30, 1999 using the
estimation process in effect at that time.
(3) LEASES
IESU's operating lease rental expenses for 1999, 1998 and 1997 were $8.9
million, $9.0 million and $8.3 million, respectively. IESU's future minimum
lease payments by year are as follows (in millions):
Capital Operating
Year Leases Leases
- ----------------------------------------- --------------- ------------------
2000 $15.6 $8.8
2001 10.5 7.1
2002 8.7 5.7
2003 4.3 5.2
2004 3.9 4.7
Thereafter 1.3 10.2
--------------- ------------------
44.3 $41.7
==================
Less: Amount representing interest 5.0
---------------
Present value of net minimum
capital lease payments $39.3
===============
(6) INCOME TAXES
The components of federal and state income taxes for IESU for the years ended
December 31 were as follows (in millions):
1999 1998 1997
---------------- -------------- ---------------
Current tax expense $55.8 $59.4 $58.3
Deferred tax expense (3.8) (15.3) (13.5)
Amortization of investment tax credits (2.6) (2.6) (2.6)
---------------- -------------- ---------------
$49.4 $41.5 $42.2
================ ============== ===============
The overall effective income tax rates shown below for the years ended December
31 were computed by dividing total income tax expense by income before income
taxes.
1999 1998 1997
------------- ------------- ------------
Statutory federal income tax rate 35.0% 35.0% 35.0%
State income taxes, net of federal benefits 7.0 6.6 7.0
Effect of rate making on property related differences 5.1 1.5 3.5
Amortization of investment tax credits (2.2) (2.5) (2.6)
Adjustment of prior period taxes (2.7) (1.4) (1.4)
Other items, net 0.4 0.9 0.3
------------- ------------- ------------
Overall effective income tax rate 42.6% 40.1% 41.8%
============= ============= ============
94
The accumulated deferred income taxes (assets) and liabilities as set forth
below on the Consolidated Balance Sheets at December 31 arise from the
following temporary differences (in millions):
1999 1998
----------- -----------
Property related $276.2 $275.7
Investment tax credit related (18.9) (20.8)
Other (31.3) (30.4)
----------- -----------
$226.0 $224.5
=========== ===========
(7) BENEFIT PLANS
(a) Pension Plans and Other Postretirement Benefits - IESU has a
non-contributory defined benefit pension plan that covers substantially all
of its employees who are subject to a collective bargaining agreement. Plan
benefits are generally based on years of service and compensation during the
employees' latter years of employment. Effective in 1998, eligible employees
of IESU that are not subject to a collective bargaining agreement are covered
by the Alliant Energy Cash Balance Pension Plan, a non-contributory defined
benefit pension plan. The projected unit credit actuarial cost method was
used to compute pension cost and the accumulated and projected benefit
obligations. IESU's policy is to fund the pension plan at an amount that is
at least equal to the minimum funding requirements mandated by ERISA and that
does not exceed the maximum tax deductible amount for the year.
IESU also provides certain other postretirement benefits to retirees,
including medical benefits for retirees and their spouses and, in some cases,
retiree life insurance. IESU's funding policy for other postretirement
benefits is generally to fund an amount up to the cost calculated using SFAS
106, "Employers' Accounting for Postretirement Benefits Other Than
Pensions."
The weighted-average assumptions as of the measurement date of September 30
are as follows:
Qualified Pension Benefits Other Postretirement Benefits
------------------------------------ ---------------------------------------
1999 1998 1997 1999 1998 1997
----------- ---------- ---------- ----------- ----------- ---------------
Discount rate 7.75% 6.75% 7.25% 7.75% 6.75% 7.25%
Expected return on plan assets 9% 9% 9% 9% 9% 9%
Rate of compensation increase 3.5% 3.5% 4.75% N/A N/A N/A
Medical cost trend on covered charges:
Initial trend range N/A N/A N/A 7% 8% 8%
Ultimate trend range N/A N/A N/A 5% 6% 6.5%
95
The components of IESU's qualified pension benefits and other postretirement
benefits costs are as follows (in millions):
Qualified Pension Benefits Other Postretirement Benefits
------------------------------------- ----------------------------------
1999 1998 1997 1999 1998 1997
--------- ----------- --------- -------- --------- ---------
Service cost $2.6 $2.9 $5.4 $1.5 $1.5 $1.5
Interest cost 7.6 8.0 14.1 4.4 4.2 3.5
Expected return on plan assets (10.3) (11.3) (15.1) (2.0) (1.1) (0.7)
Amortization of:
Transition obligation (asset) (0.2) (0.2) (0.3) 1.8 1.9 1.9
Prior service cost 0.9 0.9 1.8 -- -- --
Actuarial gain -- (0.4) -- -- -- --
--------- ----------- --------- -------- --------- ---------
Total $0.6 ($0.1) $5.9 $5.7 $6.5 $6.2
========= =========== ========= ======== ========= =========
During 1997, IESU recognized an additional $3.8 million of costs in
accordance with SFAS 88 for severance and early retirement programs. In
addition, during 1998, IESU recognized $1.2 million of curtailment charges
relating to IESU's other postretirement benefits.
The pension benefit cost shown above (and in the following tables) for 1999
and 1998 represents only the pension benefit cost for bargaining unit
employees of IESU covered under the bargaining unit pension plan that is
sponsored by IESU. The pension benefit cost for IESU's non-bargaining
employees who are now participants in other Alliant Energy plans was $0.9
million and $2.7 million for 1999 and 1998, respectively, including a special
charge of $1.9 million in 1998 for severance and early retirement window
programs. In addition, Corporate Services provides services to IESU. The
allocated pension benefit costs associated with these services was $1.2
million and $0.5 million for 1999 and 1998, respectively. The other
postretirement benefit cost shown above for each period (and in the following
tables) represents the other postretirement benefit cost for all IESU
employees. The allocated other postretirement benefit cost associated with
Corporate Services for IESU was $0.4 million and $0.2 million for 1999 and
1998, respectively.
The assumed medical trend rates are critical assumptions in determining the
service and interest cost and accumulated postretirement benefit obligation
related to postretirement benefit costs. A one percent change in the medical
trend rates for 1999, holding all other assumptions constant, would have the
following effects (in millions):
1 Percent 1 Percent
Increase Decrease
---------- ----------
Effect on total of service and interest cost components $1.3 ($1.0)
Effect on postretirement benefit obligation $8.4 ($6.8)
96
A reconciliation of the funded status of IESU's plans to the amounts
recognized on IESU's Consolidated Balance Sheets at December 31 is presented
below (in millions):
Qualified Pension Benefits Other Postretirement Benefits
----------------------------- -------------------------------
1999 1998 1999 1998
------------ ------------ ------------- -------------
Change in benefit obligation:
Net benefit obligation at beginning of year $113.1 $206.1 $65.2 $50.8
Transfer of obligation (to)/from other
Alliant Energy plans -- (99.1) -- 2.3
Service cost 2.6 2.9 1.5 1.5
Interest cost 7.6 8.0 4.4 4.2
Plan participants' contributions -- -- 0.4 0.4
Plan amendments -- -- (1.0) --
Actuarial loss (gain) (14.3) 2.2 (20.1) 8.2
Curtailments -- -- -- 0.4
Gross benefits paid (6.7) (7.0) (3.6) (2.6)
------------ ------------ ------------- -------------
Net benefit obligation at end of year 102.3 113.1 46.8 65.2
------------ ------------ ------------- -------------
Change in plan assets:
Fair value of plan assets at beginning of year 118.7 225.7 21.7 19.9
Transfer of assets to other Alliant Energy plans -- (97.5) -- --
Actual return on plan assets 14.1 (2.5) 5.6 0.1
Employer contributions -- -- 6.2 2.7
Plan participants' contributions -- -- 0.4 0.4
401(h) assets recognized -- -- -- 1.2
Gross benefits paid (6.7) (7.0) (3.6) (2.6)
------------ ------------ ------------- -------------
Fair value of plan assets at end of year 126.1 118.7 30.3 21.7
------------ ------------ ------------- -------------
Funded status at end of year 23.8 5.6 (16.5) (43.5)
Unrecognized net actuarial loss (gain) (25.4) (7.3) (18.6) 5.7
Unrecognized prior service cost 8.9 9.8 (0.3) (0.3)
Unrecognized net transition obligation (asset) (1.4) (1.6) 23.6 25.9
------------ ------------ ------------- -------------
Net amount recognized at end of year $5.9 $6.5 ($11.8) ($12.2)
============ ============ ============= =============
Amounts recognized on the Consolidated
Balance Sheets consist of:
Prepaid benefit cost $5.9 $6.5 $-- $--
Accrued benefit cost -- -- (11.8) (12.2)
------------ ------------ ------------- -------------
Net amount recognized at measurement date 5.9 6.5 (11.8) (12.2)
------------ ------------ ------------- -------------
Contributions paid after 9/30 and prior to 12/31 -- -- 3.4 3.6
------------ ------------ ------------- -------------
Net amount recognized at 12/31 $5.9 $6.5 ($8.4) ($8.6)
============ ============ ============= =============
Alliant Energy sponsors several non-qualified pension plans which cover
certain current and former officers. The pension expense allocated to IESU
for these plans was $0.8 million, $1.4 million and $2.3 million in 1999, 1998
and 1997, respectively.
IESU employees also participate in defined contribution pension plans (401(k)
plans) covering substantially all employees. IESU's contributions to the
plans, which are based on the participants' level of contribution, were $2.0
million, $2.8 million and $1.2 million in 1999, 1998 and 1997, respectively.
97
(8) COMMON, PREFERRED AND PREFERENCE STOCK
(b) Preferred and Preference Stock - The carrying value of IESU's
cumulative preferred stock at December 31, 1999 and 1998 was $18 million.
The fair market value, based upon the market yield of similar securities and
quoted market prices, at December 31, 1999 and 1998 was $12 million and $15
million, respectively.
(9) DEBT
(a) Short-Term Debt - IESU participates in a utility money pool with WP&L
and IPC that is funded, as needed, through the issuance of commercial paper
by Alliant Energy. Interest expense and other fees are allocated based on
borrowing amounts. Information regarding short-term debt is as follows
(dollars in millions):
1999 1998 1997
--------------- --------------- ---------------
As of year end:
Money pool borrowings $56.9 $-- $--
Interest rate on money pool borrowings 5.84% N/A N/A
For the year ended:
Average amount of short-term debt
(based on daily outstanding balances) $24.6 $-- $88.4
Average interest rate on short-term debt 5.24% N/A 5.58%
(b) Long-Term Debt - Debt maturities (excluding periodic sinking fund
requirements, which will not require additional cash expenditures) for 2000
to 2004 are $51.2 million, $81.5 million, $0.6 million, $4.1 million and $0,
respectively. Depending upon market conditions, it is currently anticipated
that a majority of the maturing debt will be refinanced with the issuance of
long-term securities.
The carrying value of IESU's long-term debt at December 31, 1999 and 1998 was
$602 million and $652 million, respectively. The fair market value, based
upon the market yield of similar securities and quoted market prices, at
December 31, 1999 and 1998 was $573 million and $687 million, respectively.
(10) ESTIMATED FAIR VALUE OF FINANCIAL INSTRUMENTS
Information relating to other financial instruments held by IESU is as
follows (in millions):
December 31, 1999 December 31, 1998
------------------------------------- --------------------------------
Gross Gross
Carrying Fair Unrealized Carrying Fair Unrealized
Value Value Gains/(Losses) Value Value Gains
----------- -------- ---------------- ---------- -------- ------------
Nuclear decommissioning trust funds:
Equity securities $47 $47 $35 $45 $45 $29
Debt securities 58 58 (1) 47 47 2
----------- -------- ---------------- ---------- -------- ------------
Total $105 $105 $34 $92 $92 $31
=========== ======== ================ ========== ======== ============
The carrying amount of IESU's current assets and current liabilities
approximates fair value because of the short maturity of such financial
instruments. The nuclear decommissioning trust funds realized gains from the
sales of securities of $2.5 million, $0.4 million and $0.1 million in 1999,
1998 and 1997, respectively (cost of the investments based on specific
identification were $25.5 million, $14.3 million and $14.6 million,
respectively). Since IESU is subject to regulation, any gains or losses
related to the difference between the carrying amount and the fair value of
its financial instruments may not be realized by IESU's parent.
98
(12) COMMITMENTS AND CONTINGENCIES
(b) Purchased-Power, Coal and Natural Gas Contracts - Corporate Services has
entered into purchased-power capacity contracts as agent for IESU, WP&L and
IPC. Based on the System Coordination and Operating Agreement, Alliant
Energy annually allocates purchased-power contracts to the individual
utilities. Such process considers factors such as resource mix, load growth
and resource availability and as a result of that process, IESU was not
allocated any of the purchased-power contracts for 2000 to 2004. IESU has
entered into a contract for the purchase of $9.3 million of capacity in 2000
from IPC. See Note 17 for additional information. In addition, Corporate
Services has entered into various coal contracts as agent for IESU, WP&L and
IPC. Contract quantities are allocated to specific plants at the individual
utilities based on various factors including projected heat input
requirements, combustion compatibility and efficiency. However, in 2000 and
2001, system-wide contracts of $24.6 million (6.5 million tons) and $12.5
million (3.6 million tons), respectively, have not yet been allocated to the
individual utilities due to the need for additional analysis of combustion
compatibility and efficiency. The minimum commitments directly assigned to
IESU are as follows (dollars in millions, tons in thousands):
Coal
(including
transportation)
-----------------------
Dollars Tons
---------- -----------
2000 $12.8 2,300
2001 10.4 1,556
2002 3.7 619
2003 3.3 520
2004 3.2 475
Corporate Services is in the process of negotiating several new coal
contracts. In addition, it expects to supplement its coal contracts with
spot market purchases to fulfill its future fossil fuel needs. IESU also has
various natural gas supply, transportation and storage contracts
outstanding. The minimum dekatherm commitments, in millions, for 2000-2004
are 93.8, 79.3, 72.1, 60.8 and 2.4, respectively. The minimum dollar
commitments for 2000-2004, in millions, are $51.4, $39.0, $27.4, $23.5 and
$1.3, respectively. The gas supply commitments are all index-based. IESU
expects to supplement its natural gas supply with spot market purchases as
needed.
(c) Information Technology Services - Alliant Energy has an agreement,
expiring in 2004, with EDS for information technology services. IESU's
anticipated operating and capital expenditures under the agreement for 2000
are estimated to total approximately $13 million. Future costs under the
agreement are variable and are dependent upon IESU's level of usage of
technological services from EDS.
(d) Financial Guarantees and Commitments - IESU has financial guarantees,
which were generally issued to support third-party borrowing arrangements and
similar transactions, amounting to $17 million and $18 million outstanding at
December 31, 1999 and 1998, respectively. Such guarantees are not reflected
in the consolidated financial statements. Management believes that the
likelihood of IESU having to make any material cash payments under these
agreements is remote.
(14) SEGMENTS OF BUSINESS
IESU is a regulated domestic utility, serving customers in Iowa, with three
principal business segments: a) electric operations; b) gas operations; and
c) other, which includes steam operations and the unallocated portions of the
utility business. Intersegment revenues were not material to IESU's
operations and there was no single customer whose revenues exceeded 10% or
more of IESU's consolidated revenues.
99
Certain financial information relating to IESU's significant business
segments is presented below:
Electric Gas Other Total
- ------------------------------------------------------------------------------------------------------------
(in millions)
1999
Operating revenue $628.0 $145.8 $26.9 $800.7
Depreciation and amortization expense 91.0 8.2 1.9 101.1
Operating income 149.6 8.4 3.5 161.5
Interest expense, net of AFUDC 49.5 49.5
Net income from equity method subsidiaries -- --
Miscellaneous, net (other than equity income/loss) (3.8) (3.8)
Income tax expense 49.4 49.4
Net income 66.4 66.4
Preferred and preference dividends 0.9 0.9
Earnings available for common stock 65.5 65.5
Total assets 1,449.2 201.1 105.5 1,755.8
Investments in equity method subsidiaries -- --
Construction and acquisition expenditures 92.7 13.8 0.8 107.3
- ------------------------------------------------------------------------------------------------------------
1998
Operating revenue $639.4 $141.3 $26.2 $806.9
Depreciation and amortization expense 84.7 7.6 1.7 94.0
Operating income 143.4 7.6 4.0 155.0
Interest expense, net of AFUDC 49.0 49.0
Net income from equity method subsidiaries -- --
Miscellaneous, net (other than equity income/loss) 2.6 2.6
Income tax expense 41.5 41.5
Net income 61.9 61.9
Preferred and preference dividends 0.9 0.9
Earnings available for common stock 61.0 61.0
Total assets 1,440.8 201.2 147.0 1,789.0
Investments in equity method subsidiaries -- --
Construction and acquisition expenditures 100.5 14.1 0.8 115.4
- ------------------------------------------------------------------------------------------------------------
1997
Operating revenue $604.3 $183.5 $26.2 $814.0
Depreciation and amortization expense 81.2 7.0 1.6 89.8
Operating income 138.1 13.0 2.7 153.8
Interest expense, net of AFUDC 50.5 50.5
Net loss from equity method subsidiaries 0.4 0.4
Miscellaneous, net (other than equity income/loss) 1.9 1.9
Income tax expense 42.2 42.2
Net income 58.8 58.8
Preferred and preference dividends 0.9 0.9
Earnings available for common stock 57.9 57.9
Total assets 1,441.9 211.7 115.3 1,768.9
Investments in equity method subsidiaries -- --
Construction and acquisition expenditures 89.4 15.3 4.3 109.0
- ------------------------------------------------------------------------------------------------------------
100
(15) SELECTED CONSOLIDATED QUARTERLY FINANCIAL DATA
Quarter Ended
------------------------------------------------------------------------
March 31 June 30 September 30 December 31
----------------- --------------- ----------------- ------------------
(in millions)
1999
Operating revenues $209.3 $170.8 $228.3 $192.3
Operating income 36.2 24.1 72.1 29.1
Net income 14.4 7.0 35.5 9.5
Earnings available for common stock 14.2 6.8 35.3 9.2
1998 *
Operating revenues $208.3 $174.7 $222.2 $201.7
Operating income 34.3 21.8 69.9 29.0
Net income 11.7 3.0 30.6 16.6
Earnings available for common stock 11.4 2.8 30.4 16.4
* Earnings in 1998 were impacted by the recording of approximately $2
million, $10 million, $3 million and $2 million of pre-tax merger-related
expenses in the first, second, third and fourth quarters, respectively.
(17) RELATED PARTY ISSUES
In association with the merger, IESU, WP&L and IPC entered into a System
Coordination and Operating Agreement which became effective with the merger.
The agreement, which has been approved by FERC, provides a contractual basis
for coordinated planning, construction, operation and maintenance of the
interconnected electric generation and transmission systems of the three
utility companies. In addition, the agreement allows the interconnected
system to be operated as a single entity with off-system capacity sales and
purchases made to market excess system capability or to meet system
capability deficiencies. Such sales and purchases are allocated among the
three utility companies based on procedures included in the agreement. The
sales amounts allocated to IESU were $18.1 million and $18.0 million for 1999
and 1998, respectively. The purchases allocated to IESU were $71.3 million
and $56.0 million for 1999 and 1998, respectively. The procedures were
approved by both FERC and all state regulatory bodies having jurisdiction
over these sales. Under the agreement, IESU, WP&L and IPC are fully
reimbursed for any generation expense incurred to support the sale to an
affiliate or to a non-affiliate. Any margins on sales to non-affiliates are
distributed to the three utilities in proportion to each utility's share of
electric production at the time of sale.
Pursuant to a service agreement approved by the SEC under PUHCA, IESU
receives various administrative and general services from an affiliate,
Corporate Services. These services are billed to IESU at cost based on
payroll and other expenses incurred by Corporate Services for the benefit of
IESU. These costs totaled $93.9 million and $59.3 million for 1999 and 1998,
respectively, and consisted primarily of employee compensation, benefits and
fees associated with various professional services. Corporate Services began
operations in May 1998 upon the consummation of the merger.
At December 31, 1999 and 1998, IESU had an intercompany payable to Corporate
Services of $16.4 million and $20.9 million, respectively.
101
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Shareowners of Wisconsin Power and Light Company:
We have audited the accompanying consolidated balance sheets and
statements of capitalization of Wisconsin Power and Light Company
(a Wisconsin corporation) and subsidiaries as of December 31, 1999
and 1998, and the related consolidated statements of income,
retained earnings and cash flows for each of the three years in the
period ended December 31, 1999. These financial statements and the
supplemental schedule referred to below are the responsibility of
the Company's management. Our responsibility is to express an
opinion on these financial statements and supplemental schedule
based on our audits.
We conducted our audits in accordance with generally accepted
auditing standards. Those standards require that we plan and
perform the audit to obtain reasonable assurance about whether the
financial statements are free of material misstatement. An audit
includes examining, on a test basis, evidence supporting the
amounts and disclosures in the financial statements. An audit also
includes assessing the accounting principles used and significant
estimates made by management, as well as evaluating the overall
financial statement presentation. We believe that our audits
provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present
fairly, in all material respects, the financial position of
Wisconsin Power and Light Company and subsidiaries as of December
31, 1999 and 1998, and the results of their operations and their
cash flows for each of the three years in the period ended December
31, 1999, in conformity with generally accepted accounting
principles.
Our audit was made for the purpose of forming an opinion on the basic
financial statements taken as a whole. The schedule listed in Item
14(a)(2) is presented for purposes of complying with the Securities and
Exchange Commission's rules and is not part of the basic financial
statements. This schedule has been subjected to the auditing procedures
applied in the audit of the basic financial statements and, in our
opinion, fairly states in all material respects the financial data
required to be set forth therein in relation to the basic financial
statements taken as a whole.
/s/ ARTHUR ANDERSEN LLP
ARTHUR ANDERSEN LLP
Milwaukee, Wisconsin
January 28, 2000
102
WISCONSIN POWER AND LIGHT COMPANY
CONSOLIDATED STATEMENTS OF INCOME
Year Ended December 31,
1999 1998 1997
- ---------------------------------------------------------------------------------------------------------
(in thousands)
Operating revenues:
Electric utility $626,607 $614,704 $634,143
Gas utility 120,770 111,737 155,883
Water 5,128 5,007 4,691
---------------- ---------------- ----------------
752,505 731,448 794,717
---------------- ---------------- ----------------
- ---------------------------------------------------------------------------------------------------------
Operating expenses:
Electric production fuels 110,521 120,485 116,812
Purchased power 107,598 113,936 125,438
Cost of gas sold 64,073 61,409 99,267
Other operation 126,479 143,666 131,398
Maintenance 45,652 49,912 48,058
Depreciation and amortization 113,037 119,221 104,297
Taxes other than income taxes 30,240 30,169 30,338
---------------- ---------------- ----------------
597,600 638,798 655,608
---------------- ---------------- ----------------
- ---------------------------------------------------------------------------------------------------------
Operating income 154,905 92,650 139,109
---------------- ---------------- ----------------
- ---------------------------------------------------------------------------------------------------------
Interest expense and other:
Interest expense 40,992 36,584 32,607
Allowance for funds used during construction (4,511) (3,049) (2,775)
Miscellaneous, net 1,836 (1,129) (3,796)
---------------- ---------------- ----------------
38,317 32,406 26,036
---------------- ---------------- ---------------
- ---------------------------------------------------------------------------------------------------------
Income before income taxes 116,588 60,244 113,073
---------------- ---------------- ----------------
- ---------------------------------------------------------------------------------------------------------
Income taxes 45,758 24,670 41,839
---------------- ---------------- ----------------
- ---------------------------------------------------------------------------------------------------------
Net income 70,830 35,574 71,234
---------------- ---------------- ----------------
- ---------------------------------------------------------------------------------------------------------
Preferred dividend requirements 3,310 3,310 3,310
---------------- ---------------- ----------------
- ---------------------------------------------------------------------------------------------------------
Earnings available for common stock $67,520 $32,264 $67,924
================ ================ ================
- ---------------------------------------------------------------------------------------------------------
WISCONSIN POWER AND LIGHT COMPANY
CONSOLIDATED STATEMENTS OF RETAINED EARNINGS
Year Ended December 31,
1999 1998 1997
- ---------------------------------------------------------------------------------------------------------
(in thousands)
Balance at beginning of year $294,309 $320,386 $310,805
Net income 70,830 35,574 71,234
Cash dividends declared on common stock (58,353) (58,341) (58,343)
Cash dividends declared on preferred stock (3,310) (3,310) (3,310)
---------------- ---------------- ----------------
Balance at end of year $303,476 $294,309 $320,386
================ ================ ================
- ---------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
103
WISCONSIN POWER AND LIGHT COMPANY
CONSOLIDATED BALANCE SHEETS
December 31,
ASSETS 1999 1998
- ---------------------------------------------------------------------------------------------------------------
(in thousands)
Property, plant and equipment:
Utility -
Plant in service -
Electric $1,921,624 $1,839,545
Gas 258,132 244,518
Water 27,770 26,567
Common 218,607 219,268
----------------- ------------------
2,426,133 2,329,898
Less - Accumulated depreciation 1,266,366 1,168,830
----------------- ------------------
1,159,767 1,161,068
Construction work in progress 66,784 56,994
Nuclear fuel, net of amortization 15,079 18,671
----------------- ------------------
1,241,630 1,236,733
Other property, plant and equipment, net of accumulated
depreciation and amortization of $169 and $44, respectively 608 630
----------------- ------------------
1,242,238 1,237,363
----------------- ------------------
- ---------------------------------------------------------------------------------------------------------------
Current assets:
Cash and temporary cash investments 3,555 1,811
Accounts receivable:
Customer 22,061 13,372
Associated companies 5,067 3,019
Other 10,984 8,298
Production fuel, at average cost 20,663 20,105
Materials and supplies, at average cost 20,439 20,025
Gas stored underground, at average cost 8,624 10,738
Regulatory assets 3,707 3,707
Prepaid gross receipts tax 20,864 22,222
Other 5,568 6,987
----------------- ------------------
121,532 110,284
----------------- ------------------
- ---------------------------------------------------------------------------------------------------------------
Investments:
Nuclear decommissioning trust funds 166,202 134,112
Other 15,272 15,960
----------------- ------------------
181,474 150,072
----------------- ------------------
- ---------------------------------------------------------------------------------------------------------------
Other assets:
Regulatory assets 82,161 76,284
Deferred charges and other 138,730 111,147
----------------- ------------------
220,891 187,431
----------------- ------------------
- ---------------------------------------------------------------------------------------------------------------
Total assets $1,766,135 $1,685,150
================= ==================
- ---------------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
104
WISCONSIN POWER AND LIGHT COMPANY
CONSOLIDATED BALANCE SHEETS (CONTINUED)
December 31,
CAPITALIZATION AND LIABILITIES 1999 1998
- --------------------------------------------------------------------------------------------------------------------
(in thousands)
Capitalization (See Consolidated Statements of Capitalization):
Common stock $66,183 $66,183
Additional paid-in capital 229,438 199,438
Retained earnings 303,476 294,309
------------------ -----------------
Total common equity 599,097 559,930
------------------ -----------------
Cumulative preferred stock, not mandatorily redeemable 59,963 59,963
Long-term debt (excluding current portion) 414,673 414,579
------------------ -----------------
1,073,733 1,034,472
------------------ -----------------
- --------------------------------------------------------------------------------------------------------------------
Current liabilities:
Current maturities 1,875 -
Variable rate demand bonds 55,100 56,975
Notes payable - 50,000
Notes payable to associated companies 125,749 26,799
Accounts payable 88,245 84,754
Accounts payable to associated companies 25,306 20,315
Accrued payroll and vacations 7,499 5,276
Accrued interest 6,903 6,863
Other 15,881 14,600
------------------ -----------------
326,558 265,582
------------------ -----------------
- --------------------------------------------------------------------------------------------------------------------
Other long-term liabilities and deferred credits:
Accumulated deferred income taxes 235,838 245,489
Accumulated deferred investment tax credits 31,311 33,170
Customer advances 34,643 34,367
Environmental liabilities 10,861 11,683
Other 53,191 60,387
------------------ -----------------
365,844 385,096
------------------ -----------------
- --------------------------------------------------------------------------------------------------------------------
Commitments and contingencies (Note 12)
- --------------------------------------------------------------------------------------------------------------------
Total capitalization and liabilities $1,766,135 $1,685,150
================== =================
- --------------------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
105
WISCONSIN POWER AND LIGHT COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
Year Ended December 31,
1999 1998 1997
- -----------------------------------------------------------------------------------------------------------------------------
(in thousands)
Cash flows from operating activities:
Net income $70,830 $35,574 $71,234
Adjustments to reconcile net income to net cash
flows from operating activities:
Depreciation and amortization 113,037 119,221 104,297
Amortization of nuclear fuel 6,094 5,356 3,534
Deferred taxes and investment tax credits (12,618) (7,529) 3,065
Other 2,432 (2,089) (1,323)
Other changes in assets and liabilities:
Accounts receivable (13,423) 12,845 (3,314)
Accounts payable 8,482 19,452 (7,102)
Benefit obligations and other (11,854) (5,509) (20,460)
---------------- --------------- ----------------
Net cash flows from operating activities 162,980 177,321 149,931
---------------- --------------- ----------------
- -----------------------------------------------------------------------------------------------------------------------------
Cash flows from (used for) financing activities:
Common stock dividends (58,353) (58,341) (58,343)
Preferred stock dividends (3,310) (3,310) (3,310)
Proceeds from issuance of long-term debt - 60,000 105,000
Reductions in long-term debt - (8,899) (55,000)
Net change in short-term borrowings 48,950 (4,201) 11,500
Capital contribution from parent 30,000 - -
Other - (1,966) (2,601)
---------------- --------------- ----------------
Net cash flows from (used for) financing activities 17,287 (16,717) (2,754)
---------------- --------------- ----------------
- -----------------------------------------------------------------------------------------------------------------------------
Cash flows used for investing activities:
Utility construction expenditures (131,915) (117,143) (119,232)
Nuclear decommissioning trust funds (16,092) (14,297) (11,427)
Shared savings program (31,085) (24,355) (17,610)
Other 569 (5,490) (583)
---------------- --------------- ----------------
Net cash flows used for investing activities (178,523) (161,285) (148,852)
---------------- --------------- ----------------
- -----------------------------------------------------------------------------------------------------------------------------
Net increase (decrease) in cash and temporary cash investments 1,744 (681) (1,675)
---------------- --------------- ----------------
- -----------------------------------------------------------------------------------------------------------------------------
Cash and temporary cash investments at beginning of period 1,811 2,492 4,167
---------------- --------------- ----------------
- -----------------------------------------------------------------------------------------------------------------------------
Cash and temporary cash investments at end of period $3,555 $1,811 $2,492
================ =============== ================
- -----------------------------------------------------------------------------------------------------------------------------
Supplemental cash flow information:
Cash paid during the period for:
Interest $38,330 $33,368 $32,955
================ =============== ================
Income taxes $47,164 $31,951 $37,407
================ =============== ================
- -----------------------------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
106
WISCONSIN POWER AND LIGHT COMPANY
CONSOLIDATED STATEMENTS OF CAPITALIZATION
December 31,
1999 1998
- ----------------------------------------------------------------------------------------------------------------------------
(in thousands, except share amounts)
Common equity:
Common stock - $5.00 par value - authorized 18,000,000 shares;
13,236,601 shares outstanding $66,183 $66,183
Additional paid-in capital 229,438 199,438
Retained earnings 303,476 294,309
------------------ ------------------
599,097 559,930
------------------ ------------------
- ----------------------------------------------------------------------------------------------------------------------------
Cumulative preferred stock:
Cumulative, without par value, not mandatorily redeemable - authorized
3,750,000 shares, maximum aggregate stated value $150,000,000:
$100 stated value - 4.50% series, 99,970 shares outstanding 9,997 9,997
$100 stated value - 4.80% series, 74,912 shares outstanding 7,491 7,491
$100 stated value - 4.96% series, 64,979 shares outstanding 6,498 6,498
$100 stated value - 4.40% series, 29,957 shares outstanding 2,996 2,996
$100 stated value - 4.76% series, 29,947 shares outstanding 2,995 2,995
$100 stated value - 6.20% series, 150,000 shares outstanding 15,000 15,000
$25 stated value - 6.50% series, 599,460 shares outstanding 14,986 14,986
------------------ ------------------
59,963 59,963
------------------ ------------------
- ----------------------------------------------------------------------------------------------------------------------------
Long-term debt:
First Mortgage Bonds:
1984 Series A, variable rate (5.00% at December 31, 1999), due 2014 8,500 8,500
1988 Series A, variable rate (5.60% at December 31, 1999), due 2015 14,600 14,600
1990 Series V, 9.3%, due 2025 27,000 27,000
1991 Series A, variable rate (4.75% at December 31, 1999), due 2015 16,000 16,000
1991 Series B, variable rate (4.75% at December 31, 1999), due 2005 16,000 16,000
1991 Series C, variable rate (4.75% at December 31, 1999), due 2000 1,000 1,000
1991 Series D, variable rate (4.75% at December 31, 1999), due 2000 875 875
1992 Series W, 8.6%, due 2027 90,000 90,000
1992 Series X, 7.75%, due 2004 62,000 62,000
1992 Series Y, 7.6%, due 2005 72,000 72,000
------------------ ------------------
307,975 307,975
Debentures, 7%, due 2007 105,000 105,000
Debentures, 5.7%, due 2008 60,000 60,000
------------------ ------------------
472,975 472,975
------------------ ------------------
Less:
Current maturities (1,875) -
Variable rate demand bonds (55,100) (56,975)
Unamortized debt premium and (discount), net (1,327) (1,421)
------------------ ------------------
414,673 414,579
------------------ ------------------
- ----------------------------------------------------------------------------------------------------------------------------
Total capitalization $1,073,733 $1,034,472
================== ==================
- ----------------------------------------------------------------------------------------------------------------------------
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
107
WISCONSIN POWER AND LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Except as modified below, the Alliant Energy Notes to Consolidated Financial
Statements are incorporated by reference insofar as they relate to WP&L.
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
(a) General - The Consolidated Financial Statements include the accounts of
WP&L and its consolidated subsidiaries. WP&L is a subsidiary of Alliant
Energy and is engaged principally in the generation, transmission,
distribution and sale of electric energy; the purchase, distribution,
transportation and sale of natural gas; and water services. Nearly all of
WP&L's retail customers are located in south and central Wisconsin. WP&L's
principal consolidated subsidiary is South Beloit.
(3) LEASES
WP&L's operating lease rental expenses for 1999, 1998 and 1997 were $7.7
million, $6.4 million and $5.5 million, respectively. WP&L's future minimum
lease payments by year are as follows (in millions):
Operating
Year Leases
- ---------------- -------------
2000 $8.0
2001 7.6
2002 6.2
2003 4.9
2004 4.5
Thereafter 25.3
-------------
$56.5
=============
(6) INCOME TAXES
The components of federal and state income taxes for WP&L for the years ended
December 31 were as follows (in millions):
1999 1998 1997
------------ ---------- ----------
Current tax expense $58.4 $32.2 $38.8
Deferred tax expense (10.7) (5.6) 4.9
Amortization of investment
tax credits (1.9) (1.9) (1.9)
------------ ---------- ----------
$45.8 $24.7 $41.8
============ ========== ==========
The overall effective income tax rates shown below for the years ended
December 31 were computed by dividing total income tax expense by income
before income taxes.
1999 1998 1997
-------------- -------------- -------------
Statutory federal income tax rate 35.0% 35.0% 35.0%
State income taxes, net of federal benefits 6.3 7.8 5.7
Amortization of investment tax credits (1.6) (3.1) (1.7)
Adjustment of prior period taxes (0.3) -- (2.1)
Merger expenses -- 2.5 0.3
Amortization of excess deferred taxes (1.3) (2.5) (1.3)
Other items, net 1.1 1.3 1.1
-------------- -------------- -------------
Overall effective income tax rate 39.2% 41.0% 37.0%
============== ============== =============
108
The accumulated deferred income taxes (assets) and liabilities as set forth
below on the Consolidated Balance Sheets at December 31 arise from the
following temporary differences (in millions):
1999 1998
----------- -----------
Property related $271.9 $282.7
Investment tax credit related (21.0) (22.2)
Other (15.1) (15.0)
----------- -----------
$235.8 $245.5
=========== ===========
(7) BENEFIT PLANS
(a) Pension Plans and Other Postretirement Benefits - WP&L has a
non-contributory, defined benefit pension plan that covers substantially all
of its employees who are subject to a collective bargaining agreement. Plan
benefits are generally based on years of service and levels of compensation.
Effective in 1998, eligible employees of WP&L that are not subject to a
collective bargaining agreement are covered by the Alliant Energy Cash
Balance Pension Plan, a non-contributory defined benefit pension plan. The
projected unit credit actuarial cost method was used to compute pension cost
and the accumulated and projected benefit obligations. WP&L's policy is to
fund the pension plan at an amount that is at least equal to the minimum
funding requirements mandated by ERISA, and that does not exceed the maximum
tax deductible amount for the year.
WP&L also provides certain other postretirement benefits to retirees,
including medical benefits for retirees and their spouses and, in some cases,
retiree life insurance. WP&L's funding policy is generally to fund tax
deductible amounts up to the incurred but unclaimed paid medical claim
reserve and tax deductible amounts (if any) to the retiree medical account
within the Cash Balance Pension Plan.
The weighted-average assumptions as of the measurement date of September 30
are as follows:
Qualified Pension Benefits Other Postretirement Benefits
------------------------------------- ----------------------------------------
1999 1998 1997 1999 1998 1997
------------ ----------- ------------ ---------- ------------ ---------------
Discount rate 7.75% 6.75% 7.25% 7.75% 6.75% 7.25%
Expected return on plan assets 9% 9% 9% 9% 9% 9%
Rate of compensation increase 3.5% 3.5% 3.5-4.5% 3.5% 3.5% 3.5%
Medical cost trend on covered charges:
Initial trend range N/A N/A N/A 7% 8% 8%
Ultimate trend range N/A N/A N/A 5% 5% 5%
109
The components of WP&L's qualified pension benefits and other postretirement
benefits costs are as follows (in millions):
Qualified Pension Benefits Other Postretirement Benefits
------------------------------------- ----------------------------------
1999 1998 1997 1999 1998 1997
---------- ----------- --------- -------- -------- ---------
Service cost $3.8 $3.2 $4.8 $1.6 $1.7 $1.8
Interest cost 8.9 8.5 13.9 2.7 2.6 3.3
Expected return on plan assets (12.9) (12.8) (19.2) (1.5) (1.5) (1.1)
Amortization of:
Transition obligation (asset) (2.1) (2.1) (2.4) 1.2 1.3 1.5
Prior service cost 0.4 0.5 0.4 -- -- --
Actuarial loss (gain) 0.2 -- -- (0.9) (1.1) (0.3)
---------- ----------- --------- -------- -------- ---------
Total ($1.7) ($2.7) ($2.5) $3.1 $3.0 $5.2
========== =========== ========= ======== ======== =========
During 1998 and 1997, WP&L recognized an additional $0.6 million and $1.3
million, respectively, of costs in accordance with SFAS 88. The charges were
for severance and early retirement programs in the respective years. In
addition, during 1998 and 1997, WP&L recognized $3.6 million and $1.7
million, respectively, of curtailment charges relating to WP&L's other
postretirement benefits.
The pension benefit cost shown above (and in the following tables) for 1999
and 1998 represents only the pension benefit cost for bargaining unit
employees of WP&L covered under the bargaining unit pension plan that is
sponsored by WP&L. The pension benefit cost for WP&L's non-bargaining
employees who are now participants in other Alliant Energy plans was ($1.8)
million and $3.0 million for 1999 and 1998, respectively, including a special
charge of $3.6 million in 1998 for severance and early retirement window
programs. In addition, Corporate Services provides services to WP&L. The
allocated pension benefit costs associated with these services was $1.2
million and $0.6 million for 1999 and 1998, respectively. The other
postretirement benefit cost shown above for each period (and in the following
tables) represents the other postretirement benefit cost for all WP&L
employees. The allocated other postretirement benefit cost associated with
Corporate Services for WP&L was $0.4 million and $0.2 million for 1999 and
1998, respectively.
The assumed medical trend rates are critical assumptions in determining the
service and interest cost and accumulated postretirement benefit obligation
related to postretirement benefit costs. A one percent change in the medical
trend rates for 1999, holding all other assumptions constant, would have the
following effects (in millions):
1 Percent 1 Percent
Increase Decrease
-------------- ---------------
Effect on total of service and interest cost components $0.3 ($0.3)
Effect on postretirement benefit obligation $1.5 ($1.5)
110
A reconciliation of the funded status of WP&L's plans to the amounts
recognized on WP&L's Consolidated Balance Sheets at December 31 is presented
below (in millions):
Qualified Pension Benefits Other Postretirement Benefits
---------------------------- ------------------------------
1999 1998 1999 1998
------------ ------------ ------------- -----------
Change in benefit obligation:
Net benefit obligation at beginning of year $132.3 $205.1 $40.3 $47.1
Transfer of obligations to other Alliant Energy
plans -- (91.9) -- --
Service cost 3.8 3.2 1.6 1.7
Interest cost 8.9 8.5 2.7 2.6
Plan participants' contributions -- -- 1.2 0.8
Actuarial loss (gain) (20.8) 12.2 0.8 (9.7)
Curtailments -- -- -- 0.7
Special termination benefits -- 0.6 -- --
Gross benefits paid (7.0) (5.4) (4.2) (2.9)
------------ ------------ ------------- -----------
Net benefit obligation at end of year 117.2 132.3 42.4 40.3
------------ ------------ ------------- -----------
Change in plan assets:
Fair value of plan assets at beginning of year 137.5 244.4 15.1 16.1
Transfer of assets to other Alliant Energy plans -- (100.2) -- --
Actual return on plan assets 17.1 (1.3) 1.8 1.1
Employer contributions -- -- 4.0 --
Plan participants' contributions -- -- 1.2 0.8
Gross benefits paid (7.0) (5.4) (4.2) (2.9)
------------ ------------ ------------- -----------
Fair value of plan assets at end of year 147.6 137.5 17.9 15.1
------------ ------------ ------------- -----------
Funded status at end of year 30.4 5.2 (24.5) (25.2)
Unrecognized net actuarial loss (gain) 0.8 26.0 (14.5) (17.0)
Unrecognized prior service cost 4.7 5.1 (0.2) (0.2)
Unrecognized net transition obligation (asset) (5.8) (7.9) 14.9 17.2
------------ ------------ ------------- -----------
Net amount recognized at end of year $30.1 $28.4 ($24.3) ($25.2)
============ ============ ============= ===========
Amounts recognized on the Consolidated
Balance Sheets consist of:
Prepaid benefit cost $30.1 $28.4 $0.6 $0.4
Accrued benefit cost -- -- (24.9) (25.6)
------------ ------------ ------------- -----------
Net amount recognized at measurement date 30.1 28.4 (24.3) (25.2)
------------ ------------ ------------- -----------
Contributions paid after 9/30 and prior to 12/31 -- -- 1.0 2.1
------------ ------------ ------------- -----------
Net amount recognized at 12/31 $30.1 $28.4 ($23.3) ($23.1)
============ ============ ============= ===========
Alliant Energy sponsors several non-qualified pension plans which cover
certain current and former officers. The pension expense allocated to WP&L
for these plans was $0.8 million, $0.8 million and $0.5 million in 1999, 1998
and 1997, respectively.
WP&L employees also participate in defined contribution pension plans (401(k)
plans) covering substantially all employees. WP&L's contributions to the
plans, which are based on the participants' level of contribution, were $2.0
million, $2.4 million and $2.8 million in 1999, 1998 and 1997, respectively.
111
The benefit obligation and fair value of plan assets for the postretirement
welfare plans with benefit obligations in excess of plan assets were $36.5
million and $8.4 million as of September 30, 1999 and $33.4 million and $6.2
million, respectively, as of September 30, 1998.
(8) COMMON, PREFERRED AND PREFERENCE STOCK
(b) Preferred and Preference Stock - The carrying value of WP&L's
cumulative preferred stock at December 31, 1999 and 1998 was $60 million.
The fair market value, based upon the market yield of similar securities and
quoted market prices, at December 31, 1999 and 1998 was $49 million and $55
million, respectively.
(9) DEBT
(a) Short-Term Debt - WP&L participates in a utility money pool with IESU
and IPC that is funded, as needed, through the issuance of commercial paper
by Alliant Energy. Interest expense and other fees are allocated based on
borrowing amounts. The PSCW has restricted WP&L from lending money to
non-utility affiliates and non-Wisconsin utilities. As a result, WP&L is
prohibited from lending money to the utility money pool but is able to borrow
money from the utility money pool. Information regarding short-term debt is
as follows (dollars in millions):
1999 1998 1997
-------------- -------------- --------------
As of year end:
Commercial paper outstanding $-- $-- $81.0
Notes payable outstanding $-- $50.0 $--
Money pool borrowings $125.7 $26.8 $--
Discount rates on commercial paper N/A N/A 5.82-5.90%
Interest rate on notes payable N/A 5.44% N/A
Interest rate on money pool borrowings 5.84% 5.17% N/A
For the year ended:
Average amount of short-term debt
(based on daily outstanding balances) $77.1 $48.4 $49.2
Average interest rate on short-term debt 5.22% 5.55% 5.64%
(b) Long-Term Debt - Debt maturities (excluding periodic sinking fund
requirements, which will not require additional cash expenditures) for 2000
to 2004 are $1.9 million, $0, $0, $0 and $62.0 million, respectively.
The carrying value of WP&L's long-term debt at December 31, 1999 and 1998 was
$472 million. The fair market value, based upon the market yield of similar
securities and quoted market prices, at December 31, 1999 and 1998 was $469
million and $513 million, respectively.
(10) ESTIMATED FAIR VALUE OF FINANCIAL INSTRUMENTS
Information relating to other financial instruments held by WP&L is as
follows (in millions):
December 31, 1999 December 31, 1998
------------------------------------- --------------------------------
Gross Gross
Carrying Fair Unrealized Carrying Fair Unrealized
Value Value Gains/(Losses) Value Value Gains
----------- -------- ---------------- ---------- -------- ------------
Nuclear decommissioning trust funds:
Equity securities $65 $65 $45 $53 $53 $27
Debt securities 101 101 (3) 81 81 1
----------- -------- ---------------- ---------- -------- ------------
Total $166 $166 $42 $134 $134 $28
=========== ======== ================ ========== ======== ============
The carrying amount of WP&L's current assets and current liabilities
approximates fair value because of the short maturity of such financial
instruments. The nuclear decommissioning trust funds realized gains from the
sales of securities of $4.1 million, $0.8 million and $0.1 million in 1999,
1998 and 1997, respectively (cost of the investments based on specific
identification were $86.2 million, $57.6 million and $54.0 million,
112
respectively). Since WP&L is subject to regulation, any gains or losses
related to the difference between the carrying amount and the fair value of
its financial instruments may not be realized by WP&L's parent.
(12) COMMITMENTS AND CONTINGENCIES
(b) Purchased-Power, Coal and Natural Gas Contracts - Corporate Services has
entered into purchased-power capacity contracts as agent for WP&L, IESU and
IPC. Based on the System Coordination and Operating Agreement, Alliant
Energy annually allocates purchased-power contracts to the individual
utilities. Such process considers factors such as resource mix, load growth
and resource availability. See Note 17 for additional information. In
addition, Corporate Services has entered into various coal contracts as agent
for WP&L, IESU and IPC. Contract quantities are allocated to specific plants
at the individual utilities based on various factors including projected heat
input requirements, combustion compatibility and efficiency. However, in
2000 and 2001, system-wide contracts of $24.6 million (6.5 million tons) and
$12.5 million (3.6 million tons), respectively, have not yet been allocated
to the individual utilities due to the need for additional analysis of
combustion compatibility and efficiency. The minimum commitments directly
assigned to WP&L are as follows (dollars in millions, tons in thousands):
Coal
Purchased-Power (including
transportation)
------------------- ----------------------
Dollars MWHs Dollars Tons
--------- -------- ---------- ----------
2000 $79.8 1,509 $16.8 5,269
2001 59.2 864 14.0 4,557
2002 43.9 219 9.8 3,707
2003 33.4 219 5.4 2,957
2004 25.2 219 5.4 2,957
Corporate Services is in the process of negotiating several new coal
contracts. In addition, it expects to supplement its coal contracts with
spot market purchases to fulfill its future fossil fuel needs. WP&L also has
various natural gas supply, transportation and storage contracts
outstanding. The minimum dekatherm commitments, in millions, for 2000-2004
are 60.0, 44.9, 42.6, 34.6 and 7.4, respectively. The minimum dollar
commitments for 2000-2004, in millions, are $27.9, $18.5, $14.6, $12.0 and
$1.9, respectively. The gas supply commitments are all index-based. WP&L
expects to supplement its natural gas supply with spot market purchases as
needed.
(c) Information Technology Services - Alliant Energy has an agreement,
expiring in 2004, with EDS for information technology services. WP&L's
anticipated operating and capital expenditures under the agreement for 2000
are estimated to total approximately $2 million. Future costs under the
agreement are variable and are dependent upon WP&L's level of usage of
technological services from EDS.
(14) SEGMENTS OF BUSINESS
WP&L is a regulated domestic utility, serving customers in Wisconsin and
Illinois, with three principal business segments: a) electric operations; b)
gas operations; and c) other, which includes water operations and the
unallocated portions of the utility business. Intersegment revenues were not
material to WP&L's operations and there was no single customer whose revenues
exceeded 10% or more of WP&L's consolidated revenues.
113
Certain financial information relating to WP&L's significant business
segments is presented below:
Electric Gas Other Total
- ------------------------------------------------------------------------------------------------------------
(in millions)
1999
Operating revenue $626.6 $120.8 $5.1 $752.5
Depreciation and amortization expense 97.5 14.5 1.0 113.0
Operating income 139.3 13.8 1.8 154.9
Interest expense, net of AFUDC 36.5 36.5
Net income from equity method subsidiaries (0.7) (0.7)
Miscellaneous, net (other than equity income/loss) 2.5 2.5
Income tax expense 45.8 45.8
Net income 70.8 70.8
Preferred and preference dividends 3.3 3.3
Earnings available for common stock 67.5 67.5
Total assets 1,310.5 200.3 255.3 1,766.1
Investments in equity method subsidiaries 5.2 5.2
Construction and acquisition expenditures 111.2 18.2 2.5 131.9
- ------------------------------------------------------------------------------------------------------------
1998
Operating revenue $614.7 $111.7 $5.0 $731.4
Depreciation and amortization expense 104.7 13.6 0.9 119.2
Operating income 87.4 3.6 1.7 92.7
Interest expense, net of AFUDC 33.5 33.5
Net income from equity method subsidiaries (0.8) (0.8)
Miscellaneous, net (other than equity income/loss) (0.3) (0.3)
Income tax expense 24.7 24.7
Net income 35.6 35.6
Preferred and preference dividends 3.3 3.3
Earnings available for common stock 32.3 32.3
Total assets 1,276.4 195.9 212.9 1,685.2
Investments in equity method subsidiaries 5.2 5.2
Construction and acquisition expenditures 99.6 16.0 1.5 117.1
- ------------------------------------------------------------------------------------------------------------
1997
Operating revenue $634.1 $155.9 $4.7 $794.7
Depreciation and amortization expense 91.2 12.3 0.8 104.3
Operating income (loss) 125.9 13.7 (0.5) 139.1
Interest expense, net of AFUDC 29.8 29.8
Net income from equity method subsidiaries (0.4) (0.4)
Miscellaneous, net (other than equity income/loss) (3.3) (3.3)
Income tax expense 41.8 41.8
Net income 71.2 71.2
Preferred and preference dividends 3.3 3.3
Earnings available for common stock 67.9 67.9
Total assets 1,270.9 193.6 200.1 1,664.6
Investments in equity method subsidiaries 5.7 5.7
Construction and acquisition expenditures 101.3 16.1 1.8 119.2
- ------------------------------------------------------------------------------------------------------------
114
(15) SELECTED CONSOLIDATED QUARTERLY FINANCIAL DATA
Quarter Ended
------------------------------------------------------------------------
March 31 June 30 September 30 December 31
----------------- --------------- ----------------- ------------------
(in millions)
1999
Operating revenues $203.0 $167.1 $186.8 $195.6
Operating income 46.4 21.9 32.5 54.1
Net income 26.3 6.9 14.2 23.4
Earnings available for common stock 25.4 6.1 13.4 22.6
1998 *
Operating revenues $202.8 $172.5 $176.1 $180.0
Operating income 33.7 10.8 29.7 18.5
Net income (loss) 17.6 (1.2) 12.7 6.5
Earnings available for common stock 16.8 (2.1) 11.9 5.7
*Earnings for 1998 were impacted by the recording of approximately $3
million, $11 million, $2 million and $1 million of pre-tax merger-related
expenses in the first, second, third and fourth quarters, respectively.
(17) RELATED PARTY ISSUES
In association with the merger, IESU, WP&L and IPC entered into a System
Coordination and Operating Agreement which became effective with the merger.
The agreement, which has been approved by FERC, provides a contractual basis
for coordinated planning, construction, operation and maintenance of the
interconnected electric generation and transmission systems of the three
utility companies. In addition, the agreement allows the interconnected
system to be operated as a single entity with off-system capacity sales and
purchases made to market excess system capability or to meet system
capability deficiencies. Such sales and purchases are allocated among the
three utility companies based on procedures included in the agreement. The
sales amounts allocated to WP&L were $23.8 million and $23.6 million for 1999
and 1998, respectively. The purchases allocated to WP&L were $101.0 million
and $70.0 million for 1999 and 1998, respectively. The procedures were
approved by both the FERC and all state regulatory bodies having jurisdiction
over these sales. Under the agreement, IESU, WP&L and IPC are fully
reimbursed for any generation expense incurred to support a sale to an
affiliate or to a non-affiliate. Any margins on sales to non-affiliates are
distributed to the three utilities in proportion to each utility's share of
electric production at the time of the sale.
Pursuant to a service agreement approved by the SEC under PUHCA, WP&L
received various administrative and general services from an affiliate,
Corporate Services. These services are billed to WP&L at cost based on
payroll and other expenses incurred by Corporate Services for the benefit of
WP&L. These costs totaled $96.5 million and $53.9 million for 1999 and 1998,
respectively, and consisted primarily of employee compensation, benefits and
fees associated with various professional services. Corporate Services began
operations in May 1998 upon the consummation of the merger.
At December 31, 1999 and 1998, WP&L had an intercompany payable to Corporate
Services of $24.7 million and $20.0 million, respectively.
115
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
None.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANTS
ALLIANT ENERGY
The information required by Item 10 relating to directors and nominees
for election of directors at the 2000 Annual Meeting of Shareowners is
incorporated herein by reference to the relevant information under the
caption "Election of Directors" in Alliant Energy's Proxy Statement for
the 2000 Annual Meeting of Shareowners (the 2000 Alliant Energy Proxy
Statement), which has been filed with the SEC within 120 days after the
end of Alliant Energy's fiscal year. The executive officers of Alliant
Energy as of the date of this filing are as follows (figures following
the names represent the officer's age as of December 31, 1999):
Executive Officers of Alliant Energy
Erroll B. Davis, Jr., 55, has served as President and Chief Executive
- ---------------------
Officer (CEO) since 1990 and has been a board member since 1988.
William D. Harvey, 50, was elected Executive Vice President-Generation
- -----------------
effective April 1998. Prior thereto, he served as Senior Vice President
since 1993 at WP&L.
James E. Hoffman, 46, was elected Executive Vice President-Business
- -----------------
Development effective April 1998. Prior thereto, he served as Executive
Vice President since 1996 at IES and Executive Vice President-Customer
Service & Energy Delivery from 1995 to 1997 at IESU.
Eliot G. Protsch, 46, was elected Executive Vice President-Energy
- -----------------
Delivery effective April 1998. Prior thereto, he served as Senior Vice
President since 1993 at WP&L.
Barbara J. Swan, 48, was elected Executive Vice President and General
- ---------------
Counsel effective October 1998. She previously served as Vice
President-General Counsel from 1994 to 1998 at WP&L.
Thomas M. Walker, 52, was elected Executive Vice President and Chief
- -----------------
Financial Officer (CFO) effective April 1998. Prior thereto, he served
as Executive Vice President and CFO since 1996 at IES and IESU. Prior to
joining Alliant Energy, he was Executive Vice President-Chief Financial
and Administrative Officer and member of the Board of Directors from 1990
to 1995 at Information Resources, Inc.
Pamela J. Wegner, 52, was elected Executive Vice President-Corporate
- ----------------
Services effective October 1998. She previously served as Vice
President-Information Services and Administration from 1994 to 1998 at
WP&L.
Daniel A. Doyle, 41, was elected Vice President-Chief Accounting and
- ---------------
Financial Planning Officer effective January 2000. He previously served
as Vice President-Manufacturing and Energy Portfolio Services since
October 1998 at WP&L and IESU and Vice President-Fossil Plants since
April 1998 at WP&L. He has also served as Vice President-Power
Production from 1996 to 1998 and Vice President-Finance, Controller and
Treasurer from 1994 to 1996 at WP&L.
John E. Ebright, 56, was elected Vice President-Special Projects
- ---------------
effective January 2000. He previously served as Vice
President-Controller since April 1998 at Alliant Energy, IESU and WP&L
and as Controller and Chief Accounting Officer from 1996 to 1998 at IES
and IESU. Prior to joining Alliant Energy, he was Vice President and
Controller from 1987 to 1996 at MidCon Corp., a subsidiary of Occidental
Petroleum Corporation.
116
Edward M. Gleason, 59, has served as Vice President-Treasurer and
- -----------------
Corporate Secretary since 1993.
Susan J. Kosmo, 53, was elected Assistant Controller effective April
- --------------
1998. She previously served as Assistant Controller since 1995 at WP&L.
John E. Kratchmer, 37, was elected Assistant Controller effective April
- -----------------
1998. He previously served as Manager of Financial Reporting and
Property since 1996 and Manager of Financial Reporting from 1994 to 1996
at IES.
Linda J. Wentzel, 51, was elected Assistant Corporate Secretary effective
- -----------------
May 1998. She previously served as Executive Administrative Assistant
since 1995 at Alliant Energy.
Enrique Bacalao, 50, was elected Assistant Treasurer effective November
- ---------------
1998. Prior to joining Alliant Energy, he was Vice President, Corporate
Banking from 1995 to 1998 at the Chicago Branch of The Industrial Bank of
Japan, Limited.
NOTE: None of the executive officers listed above is related to any
member of the Board of Directors or nominee for director or any other
executive officer.
Mr. Davis has an employment agreement with Alliant Energy pursuant to
which his term of office is established. All other executive officers
have no definite terms of office and serve at the pleasure of the Board
of Directors.
IESU
IESU's directors are identical to Alliant Energy, but are elected by
consent action. The information required by Item 10 relating to
directors and nominees for election of directors at the 2000 Annual
Meeting of Shareowners is incorporated herein by reference to the
relevant information included under the caption "Election of Directors"
in the 2000 Alliant Energy Proxy Statement, which has been filed with the
SEC within 120 days after the end of IESU's fiscal year. The executive
officers of IESU as of the date of this filing are as follows (figures
following the names represent the officer's age as of December 31,
1999):
Executive Officers of IESU
Erroll B. Davis, Jr., 55, was elected CEO effective April 1998. Mr.
- --------------------
Davis is also an officer of Alliant Energy and WP&L.
Eliot G. Protsch, 46, was elected President effective April 1998. Mr.
- ----------------
Protsch is also an officer of Alliant Energy and WP&L.
William D. Harvey, 50, was elected Executive Vice President-Generation
- -----------------
effective October 1998. Mr. Harvey is also an officer of Alliant Energy
and WP&L.
Barbara J. Swan, 48, was elected Executive Vice President and General
- ---------------
Counsel effective October 1998. Ms. Swan is also an officer of Alliant
Energy and WP&L.
Thomas M. Walker, 52, was elected Executive Vice President and CFO in
- -----------------
1996. Mr. Walker is also an officer of Alliant Energy and WP&L.
Pamela J. Wegner, 52, was elected Executive Vice President-Corporate
- -----------------
Services effective October 1998. Ms. Wegner is also an officer of
Alliant Energy and WP&L.
Dale R. Sharp, 59, was elected Senior Vice President-Transmission
- ------------------
effective September 1999. He previously served as Senior Vice
President-Engineering and Standards since October 1998 at IESU and WP&L.
He has also served as Vice President-Engineering from 1996 to 1998 and
Vice President-Power Production from 1995 to 1996 at IPC. Mr. Sharp is
also an officer of WP&L.
Daniel A. Doyle, 41, was elected Vice President-Chief Accounting and
- -------------------
Financial Planning Officer effective January 2000. He previously served
as Vice President-Manufacturing and Energy Portfolio Services since
October 1998. Mr. Doyle is also an officer of Alliant Energy and WP&L.
117
Edward M. Gleason, 59, was elected Vice President-Treasurer and Corporate
- -----------------
Secretary effective April 1998. Mr. Gleason is also an officer of
Alliant Energy and WP&L.
Dundeana K. Langer, 41, was elected Vice President-Customer Services and
- ------------------
Operations effective September 1999. She previously served as Vice
President-Customer Operations since April 1998 at IESU and Vice
President-Customer Services since October 1998 at WP&L. She has also
served as Assistant Vice President-Field Operations from 1997 to 1998,
General Manager-Operations & Director Process Redesign Implementation
from 1996 to 1997 and Team Leader-Energy Delivery Process Redesign Team
from 1995 to 1996 at IESU. Ms. Langer is also an officer of WP&L.
Daniel L. Mineck, 51, was elected Vice President-Performance Engineering
- ----------------
and Environmental effective October 1998. He previously served as
Assistant Vice President-Corporate Engineering since 1996 and Assistant
Vice President-Nuclear from 1995 to 1996. Mr. Mineck is also an officer
of WP&L.
David L. Wilson, 53, was elected Vice President-Nuclear effective
- ---------------
September 1999. He previously served as Assistant Vice President-Nuclear
since 1997, Facility Leader from 1996 to 1997 and Plant Manager from 1995
to 1996. Mr. Wilson is also an officer of WP&L.
Kim K. Zuhlke, 46, was elected Vice President-Engineering, Sales and
- --------------
Marketing effective September 1999. He previously served as Vice
President-Customer Operations since October 1998. Mr. Zuhlke is also an
officer of WP&L.
Daniel L. Siegfried, 40, was elected Assistant Corporate Secretary
- -------------------
effective April 1998. He also serves as Senior Attorney for Alliant
Energy. Previously he served as Senior Environmental Counsel from 1992
to 1998 at IES.
Linda J. Wentzel, 51, was elected Assistant Corporate Secretary effective
- -----------------
May 1998. Ms. Wentzel is also an officer of Alliant Energy and WP&L.
Enrique Bacalao, 50, was elected Assistant Treasurer effective November
- ---------------
1998. Prior to joining IESU, he was Vice President, Corporate Banking
from 1995 to 1998 at the Chicago Branch of The Industrial Bank of Japan,
Limited. Mr. Bacalao is also an officer of Alliant Energy and WP&L.
Steven F. Price, 47, was elected Assistant Treasurer effective April
- ----------------
1998. Mr. Price is also an officer of WP&L.
Robert A. Rusch, 37, was elected Assistant Treasurer effective April
- ---------------
1998. Mr. Rusch is also an officer of WP&L.
NOTE: None of the executive officers listed above is related to any
member of the Board of Directors or nominee for director or any other
executive officer.
Mr. Davis has an employment agreement with Alliant Energy pursuant to
which his term of office is established. All other executive officers
have no definite terms of office and serve at the pleasure of the Board
of Directors.
WP&L
The information required by Item 10 relating to directors and nominees
for election of directors at the 2000 Annual Meeting of Shareowners is
incorporated herein by reference to the relevant information under the
caption "Election of Directors" in WP&L's Proxy Statement for the 2000
Annual Meeting of Shareowners (the 2000 WP&L Proxy Statement), which will
be filed with the SEC within 120 days after the end of WP&L's fiscal
year. The executive officers of WP&L as of the date of this filing are
as follows (figures following the names represent the officer's age as of
December 31, 1999):
118
Executive Officers of WP&L
Erroll B. Davis, Jr., 55, was elected CEO effective April 1998. He
- --------------------
previously served as President and CEO of WP&L since 1988 and has been a
board member of WP&L since 1984. Mr. Davis is also an officer of Alliant
Energy and IESU.
William D. Harvey, 50, was elected President effective April 1998. He
- ------------------
previously served as Senior Vice President since 1993 at WP&L. Mr.
Harvey is also an officer of Alliant Energy and IESU.
Eliot G. Protsch, 46, was elected Executive Vice President-Energy
- ----------------
Delivery effective October 1998. He previously served as Senior Vice
President from 1993 to 1998 at WP&L. Mr. Protsch is also an officer of
Alliant Energy and IESU.
Barbara J. Swan, 48, was elected Executive Vice President and General
- ----------------
Counsel effective October 1998. She previously served as Vice
President-General Counsel from 1994 to 1998 at WP&L. Ms. Swan is also an
officer of Alliant Energy and IESU.
Thomas M. Walker, 52, was elected Executive Vice President and CFO
- ----------------
effective October 1998. Mr. Walker is also an officer of Alliant Energy
and IESU.
Pamela J. Wegner, 52, was elected Executive Vice President-Corporate
- ----------------
Services effective October 1998. She previously served as Vice
President-Information Services and Administration from 1994 to 1998 at
WP&L. Ms. Wegner is also an officer of Alliant Energy and IESU.
Dale R. Sharp, 59, was elected Senior Vice President-Transmission
- --------------
effective September 1999. He previously served as Senior Vice
President-Engineering and Standards since October 1998 at WP&L and IESU.
He has also served as Vice President-Engineering from 1996 to 1998 and
Vice President-Power Production from 1995 to 1996 at IPC. Mr. Sharp is
also an officer of IESU.
Daniel A. Doyle, 41, was elected Vice President-Chief Accounting and
- ---------------
Financial Planning Officer effective January 2000. He previously served
as Vice President-Manufacturing and Energy Portfolio Services since
October 1998 at WP&L and IESU and Vice President-Fossil Plants since
April 1998 at WP&L. He has also served as Vice President-Power
Production from 1996 to 1998 and Vice President-Finance, Controller and
Treasurer from 1994 to 1996 at WP&L. Mr. Doyle is also an officer of
Alliant Energy and IESU.
Edward M. Gleason, 59, was elected Vice President-Treasurer and Corporate
- -----------------
Secretary effective April 1998. He previously served as Controller,
Treasurer, and Corporate Secretary of WP&L since 1996 and Corporate
Secretary of WP&L from 1993 to 1996. Mr. Gleason is also an officer of
Alliant Energy and IESU.
Dundeana K. Langer, 41, was elected Vice President-Customer Services and
- ------------------
Operations effective September 1999. She previously served as Vice
President-Customer Services since October 1998. Ms. Langer is also an
officer of IESU.
Daniel L. Mineck, 51, was elected Vice President-Performance Engineering
- ----------------
and Environmental effective April 1998. Mr. Mineck is also an officer of
IESU.
David L. Wilson, 53, was elected Vice President-Nuclear effective
- ----------------
September 1999. He previously served as Assistant Vice President-Nuclear
since April 1998. Mr. Wilson is also an officer of IESU.
Kim K. Zuhlke, 46, was elected Vice President-Engineering, Sales &
- -------------
Marketing effective September 1999. He previously served as Vice
President-Customer Operations since April 1998 at WP&L and since October
1998 at IESU and as Vice President-Customer Services and Sales from 1993
to 1998 at WP&L. Mr. Zuhlke is also an officer of IESU.
119
Linda J. Wentzel, 51, was elected Assistant Corporate Secretary effective
- -----------------
May 1998. She previously served as Executive Administrative Assistant
since 1995 at Alliant Energy. Ms. Wentzel is also an officer of Alliant
Energy and IESU.
Enrique Bacalao, 50, was elected Assistant Treasurer effective November
- ----------------
1998. Prior to joining WP&L, he was Vice President, Corporate Banking
from 1995 to 1998 at the Chicago Branch of The Industrial Bank of Japan,
Limited. Mr. Bacalao is also an officer of Alliant Energy and IESU.
Steven F. Price, 47, was elected Assistant Treasurer effective April
- ---------------
1998. He previously served as Assistant Corporate Secretary since 1992
at Alliant Energy and WP&L and as Assistant Treasurer since 1992 at
Alliant Energy. Mr. Price is also an officer of IESU.
Robert A. Rusch, 37, was elected Assistant Treasurer effective April
- ---------------
1998. He previously served as Assistant Treasurer since 1995 at WP&L.
Mr. Rusch is also an officer of IESU.
NOTE: None of the executive officers listed above is related to any
member of the Board of Directors or nominee for director or any other
executive officer.
Mr. Davis has an employment agreement with Alliant Energy pursuant to
which his term of office is established. All other executive officers
have no definite terms of office and serve at the pleasure of the Board
of Directors.
ITEM 11. EXECUTIVE COMPENSATION
ALLIANT ENERGY
The information required by Item 11 is incorporated herein by reference
to the relevant information in the 2000 Alliant Energy Proxy Statement,
which has been filed with the SEC within 120 days after the end of
Alliant Energy's fiscal year.
IESU
The CEO and the four other most highly compensated executive officers for
IESU are the same as for WP&L. Therefore, the information required by
Item 11 is incorporated herein by reference to the relevant information
in the 2000 WP&L Proxy Statement, which will be filed with the SEC within
120 days after the end of IESU's fiscal year.
WP&L
The information required by Item 11 is incorporated herein by reference
to the relevant information in the 2000 WP&L Proxy Statement, which will
be filed with the SEC within 120 days after the end of WP&L's fiscal
year.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
ALLIANT ENERGY
The information required by Item 12 is incorporated herein by reference
to the relevant information under the caption "Ownership of Voting
Securities" in the 2000 Alliant Energy Proxy Statement, which has been
filed with the SEC within 120 days after the end of Alliant Energy's
fiscal year.
IESU
To IESU's knowledge, no shareowner beneficially owned five percent or
more of IESU's 4.80% Cumulative Preferred Stock as of December 31, 1999.
None of the directors or executive officers of IESU own any shares of
IESU's 4.80% Cumulative Preferred Stock.
WP&L
The information required by Item 12 is incorporated herein by reference
to the relevant information under the caption "Ownership of Voting
Securities" in the 2000 WP&L Proxy Statement, which will be filed with
the SEC within 120 days after the end of WP&L's fiscal year.
120
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
ALLIANT ENERGY
The information required by Item 13 is incorporated herein by reference to the
relevant information under the caption "Certain Agreements and Transactions" in
the 2000 Alliant Energy Proxy Statement, which has been filed with the SEC
within 120 days after the end of Alliant Energy's fiscal year.
IESU
The information required by Item 13 is incorporated herein by reference to the
relevant information under the caption "Certain Agreements and Transactions" in
the 2000 Alliant Energy Proxy Statement, which has been filed with the SEC
within 120 days after the end of IESU's fiscal year.
WP&L
The information required by Item 13 is incorporated herein by reference to the
relevant information under the caption "Certain Agreements and Transactions" in
the 2000 WP&L Proxy Statement, which will be filed with the SEC within 120 days
after the end of WP&L's fiscal year.
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
(a) (1) Consolidated Financial Statements
---------------------------------
Refer to Index to Financial Statements at Item 8. "Financial
Statements and Supplementary Data."
(a) (2) Financial Statement Schedules
------------------------------
Report of Independent Public Accountants on Schedules
Schedule II. Valuation and Qualifying Accounts and Reserves
NOTE: All other schedules are omitted because they are not applicable
or not required, or because that required information is shown either
in the consolidated financial statements or in the notes thereto.
(a) (3) Exhibits Required by Securities and Exchange Commission Regulation S-K
----------------------------------------------------------------------
The following Exhibits are filed herewith or incorporated herein by
reference. Documents indicated by an asterisk (*) are incorporated
herein by reference.
2.1* Agreement and Plan of Merger, dated as of November 10, 1995, by
and among WPLH, IES, IPC and AMW Acquisition, Inc.
(incorporated by reference to Exhibit 2.1 to Alliant Energy's
Current Report on Form 8-K, dated November 10, 1995)
2.2* Amendment No. 1 to Agreement and Plan of Merger and Stock
Option Agreements, dated May 22, 1996, by and among WPLH, IES,
IPC, a Delaware corporation, AMW Acquisition, Inc., WPLH
Acquisition Co. and IPC, a Wisconsin corporation (incorporated
by reference to Exhibit 2.1 to Alliant Energy's Current Report
on Form 8-K, dated May 22, 1996)
2.3* Amendment No. 2 to Agreement and Plan of Merger, dated August
16, 1996, by and among WPLH, IES, IPC, a Delaware corporation,
WPLH Acquisition Co. and IPC, a Wisconsin corporation
(incorporated by reference to Exhibit 2.1 to Alliant Energy's
Current Report on Form 8-K, dated August 15, 1996)
3.1* Restated Articles of Incorporation of Alliant Energy, as
amended (incorporated by reference to Exhibit 3.2 to Alliant
Energy's Form 10-Q for the quarter ended June 30, 1999)
3.2 Bylaws of Alliant Energy, as amended, effective as of March
15,2000
3.3* Restated Articles of Incorporation of WP&L, as amended
(incorporated by reference to Exhibit 3.1 to WP&L's Form 10-Q
for the quarter ended June 30, 1994)
121
3.4 Bylaws of WP&L, as amended, effective as of March 15, 2000
3.5* Amended and Restated Articles of Incorporation of IESU
(incorporated by reference to Exhibit 3.5 to IESU's Form 10-Q
for the quarter ended June 30, 1998)
3.6 Bylaws of IESU, as amended, effective as of March 15, 2000
4.1* Indenture of Mortgage or Deed of Trust dated August 1, 1941,
between WP&L and First Wisconsin Trust Company (n/k/a Firstar
Bank, N.A.) and George B. Luhman, as Trustees, filed as
Exhibit 7(a) in File No. 2-6409, and the indentures supplemental
thereto dated, respectively, January 1, 1948, September 1,
1948, June 1, 1950, April 1, 1951, April 1, 1952, September 1,
1953, October 1, 1954, March 1, 1959, May 1, 1962, August 1,
1968, June 1, 1969, October 1, 1970, July 1, 1971, April 1,
1974, December 1, 1975, May 1, 1976, May 15, 1978, August 1,
1980, January 15, 1981, August 1, 1984, January 15, 1986,
June 1, 1986, August 1, 1988, December 1, 1990, September 1,
1991, October 1, 1991, March 1, 1992, May 1, 1992, June 1, 1992
and July 1, 1992 (Second Amended Exhibit 7(b) in File
No. 2-7361; Amended Exhibit 7(c) in File No. 2-7628; Amended
Exhibit 7.02 in File No. 2-8462; Amended Exhibit 7.02 in File
No. 2-8882; Second Amendment Exhibit 4.03 in File No. 2-9526;
Amended Exhibit 4.03 in File No. 2-10406; Amended Exhibit 2.02
in File No. 2-11130; Amended Exhibit 2.02 in File No. 2-14816;
Amended Exhibit 2.02 in File No. 2-20372; Amended Exhibit 2.02
in File No. 2-29738; Amended Exhibit 2.02 in File No. 2-32947;
Amended Exhibit 2.02 in File No. 2-38304; Amended Exhibit 2.02
in File No. 2-40802; Amended Exhibit 2.02 in File No. 2-50308;
Exhibit 2.01(a) in File No. 2-57775; Amended Exhibit 2.02 in
File No. 2-56036; Amended Exhibit 2.02 in File No. 2-61439;
Exhibit 4.02 in File No. 2-70534; Amended Exhibit 4.03 in File
No. 2-70534; Exhibit 4.02 in File No. 33-2579; Amended
Exhibit 4.03 in File No. 33-2579; Amended Exhibit 4.02 in File
No. 33-4961; Exhibit 4.24 in File No. 33-45726, Exhibit 4.25 in
File No. 33-45726, Exhibit 4.26 in File No. 33-45726,
Exhibit 4.27 in File No.33-45726, Exhibit 4.1 to WP&L's Form 8-K
dated March 9, 1992, Exhibit 4.1 to WP&L's Form 8-K dated May
12, 1992, Exhibit 4.1 to WP&L's Form 8-K dated June 29, 1992
and Exhibit 4.1 to WP&L's Form 8-K dated July 20, 1992)
4.2* Rights Agreement, dated January 20, 1999, between Alliant
Energy and Firstar Bank Milwaukee, N.A. (incorporated by
reference to Exhibit 4.1 to Alliant Energy's Registration
Statement on Form 8-A, dated January 20, 1999)
4.3* Indenture, dated as of June 20, 1997, between WP&L and Firstar
Trust Company (n/k/a Firstar Bank, N.A.), as Trustee, relating
to debt securities (incorporated by reference to Exhibit 4.33
to Amendment No. 2 to WP&L's Registration Statement on Form S-3
(Registration No. 33-60917))
4.4* Officers' Certificate, dated as of June 25, 1997, creating
WP&L's 7% debentures due June 15, 2007 (incorporated by
reference to Exhibit 4 to WP&L's Current Report on Form 8-K,
dated June 25, 1997)
4.5* Officers' Certificate, dated as of October 27, 1998, creating
WP&L's 5.70% debentures due October 15, 2008 (incorporated by
reference to Exhibit 4 to WP&L's Current Report on Form 8-K,
dated October 27, 1998)
4.6* Officers' Certificate, dated as of March 1, 2000, creating
WP&L's 7-5/8% debentures due March 1, 2010 (incorporated by
reference to Exhibit 4 to WP&L's Current Report on Form 8-K,
dated March 1, 2000)
122
4.7* Indenture of Mortgage and Deed of Trust, dated as of
September 1, 1993, between IESU (formerly Iowa Electric Light
and Power Company (IE)) and The First National Bank of Chicago,
as Trustee (Mortgage) (incorporated by reference to
Exhibit 4(c) to IESU's Form 10-Q for the quarter ended
September 30, 1993), and the indentures supplemental thereto
dated, respectively, October 1, 1993, November 1, 1993, March
1, 1995, September 1, 1996 and April 1, 1997 (Exhibit 4(d) in
IESU's Form 10-Q dated November 12, 1993, Exhibit 4(e) in
IESU's Form 10-Q dated November 12, 1993, Exhibit 4(b) in IESU's
Form 10-Q dated May 12, 1995, Exhibit 4(c)(i) in IESU's Form
8-K dated September 19, 1996 and Exhibit 4(a) in IESU's Form
10-Q dated May 14, 1997)
4.8* Indenture of Mortgage and Deed of Trust, dated as of August 1,
1940, between IESU (formerly IE) and The First National Bank of
Chicago, Trustee (1940 Indenture) (incorporated by reference to
Exhibit 2(a) to IESU's Registration Statement, File No.
2-25347), and the indentures supplemental thereto dated,
respectively, March 1, 1941, July 15, 1942, August 2, 1943,
August 10, 1944, November 10, 1944, August 8, 1945, July 1,
1946, July 1, 1947, December 15, 1948, November 1, 1949,
November 10, 1950, October 1, 1951, March 1, 1952, November 5,
1952, February 1, 1953, May 1, 1953, November 3, 1953, November
8, 1954, January 1, 1955, November 1, 1955, November 9, 1956,
November 6, 1957, November 4, 1958, November 3, 1959, November
1, 1960, January 1, 1961, November 7, 1961, November 6, 1962,
November 5, 1963, November 4, 1964, November 2, 1965, September
1, 1966, November 30, 1966, November 7, 1967, November 5, 1968,
November 1, 1969, December 1, 1970, November 2, 1971, May 1,
1972, November 7, 1972, November 7, 1973, September 10, 1974,
November 5, 1975, July 1, 1976, November 1, 1976, December 1,
1977, November 1, 1978, December 1, 1979, November 1, 1981,
December 1, 1980, December 1, 1982, December 1, 1983, December
1, 1984, March 1, 1985, March 1, 1988, October 1, 1988, May 1,
1991, March 1, 1992, October 1, 1993, November 1, 1993, March
1, 1995, September 1, 1996 and April 1, 1997 (Exhibit 2(a) in
File No. 2-25347, Exhibit 2(a) in File No. 2-25347, Exhibit
2(a) in File No. 2-25347, Exhibit 2(a) in File No. 2-25347,
Exhibit 2(a) in File No. 2-25347, Exhibit 2(a) in File No.
2-25347, Exhibit 2(a) in File No. 2-25347, Exhibit 2(a) in File
No. 2-25347, Exhibit 2(a) in File No. 2-25347, Exhibit 2(a) in
File No. 2-25347, Exhibit 2(a) in File No. 2-25347, Exhibit
2(a) in File No. 2-25347, Exhibit 2(a) in File No. 2-25347,
Exhibit 2(a) in File No. 2-25347, Exhibit 2(a) in File No.
2-25347, Exhibit 2(a) in File No. 2-25347, Exhibit 2(a) in File
No. 2-25347, Exhibit 2(a) in File No. 2-25347, Exhibit 2(a) in
File No. 2-25347, Exhibit 2(a) in File No. 2-25347, Exhibit
2(a) in File No. 2-25347, Exhibit 2(a) in File No. 2-25347,
Exhibit 2(a) in File No. 2-25347, Exhibit 2(a) in File No.
2-25347, Exhibit 2(a) in File No. 2-25347, Exhibit 2(a) in File
No. 2-25347, Exhibit 2(a) in File No. 2-25347, Exhibit 2(a) in
File No. 2-25347, Exhibit 2(a) in File No. 2-25347, Exhibit
2(a) in File No. 2-25347, Exhibit 2(a) in File No. 2-25347,
Exhibit 4.10 in IESU's Form 10-K for the year 1966, Exhibit
4.10 in IESU's Form 10-K for the year 1966, Exhibit 4.10 in
IESU's Form 10-K for the year 1967, Exhibit 4.10 in IESU's Form
10-K for the year 1968, Exhibit 4.10 in IESU's Form 10-K for
the year 1969, Exhibit 1 in IESU's Form 8-K dated December
1970, Exhibit 2(g) in File No. 2-43131, Exhibit 1 in IESU's
Form 8-K dated May 1972, Exhibit 2(i) in File No. 2-56078,
Exhibit 2(j) in File No. 2-56078, Exhibit 2(k) in File No.
2-56078, Exhibit 2(l) in File No. 2-56078, Exhibit 1 in IESU's
Form 8-K dated July 1976, Exhibit 1 in IESU's Form 8-K dated
December 1976, Exhibit 2(o) in File No. 2-60040, Exhibit 1 in
IESU's Form 10-Q dated June 30, 1979, Exhibit 2(q) in Form S-16
in File No. 2-65996, Exhibit 2 in IESU's Form 10-Q dated March
31, 1982, Exhibit 4(s) in IESU's Form 10-K for the year 1981,
Exhibit 4(t) in IESU's Form 10-K for the year 1982, Exhibit
4(u) in IESU's Form 10-K for the year 1983, Exhibit 4(v) in
IESU's Form 10-K for the year 1984, Exhibit 4(w) in IESU's Form
10-K for the year 1984, Exhibit 4(b) in IESU's Form 10-Q dated
May 12, 1988, Exhibit 4(c) in IESU's Form 10-Q dated November
10, 1988, Exhibit 4(d) in IESU's Form 10-Q dated August 13,
1991, Exhibit 4(c) in IESU's Form 10-K for the year 1991,
Exhibit 4(a) in IESU's Form 10-Q dated November 12, 1993,
Exhibit 4(b) in IESU's Form 10-Q dated November 12, 1993,
Exhibit 4(a) in IESU's Form 10-Q dated May 12, 1995, Exhibit
4(f) in IESU's Form 8-K dated September 19, 1996 and Exhibit
4(b) in IESU's Form 10-Q dated May 14, 1997)
4.9* Indenture or Deed of Trust dated as of February 1, 1923,
between IESU (successor to Iowa Southern Utilities Company (IS)
as result of merger of IS and IE) and The Northern Trust
Company (The First National Bank of Chicago, successor) and
Harold H. Rockwell (Richard D. Manella, successor), as Trustees
123
(1923 Indenture) (incorporated by reference to Exhibit B-1 to
File No. 2-1719), and the indentures supplemental thereto
dated, respectively, May 1, 1940, May 2, 1940, October 1, 1945,
October 2, 1945, January 1, 1948, September 1, 1950, February
1, 1953, October 2, 1953, August 1, 1957, September 1, 1962,
June 1, 1967, February 1, 1973, February 1, 1975, July 1, 1975,
September 2, 1975, March 10, 1976, February 1, 1977, January 1,
1978, March 1, 1979, March 1, 1980, May 31, 1986, July 1, 1991,
September 1, 1992 and December 1, 1994 (Exhibit B-1-k in File
No. 2-4921, Exhibit B-1-l in File No. 2-4921, Exhibit 7(m) in
File No. 2-8053, Exhibit 7(n) in File No. 2-8053, Exhibit 7(o)
in File No. 2-8053, Exhibit 4(e) in File No. 33-3995, Exhibit
4(b) in File No. 2-10543, Exhibit 4(q) in File No. 2-10543,
Exhibit 2(b) in File No. 2-13496, Exhibit 2(b) in File No.
2-20667, Exhibit 2(b) in File No. 2-26478, Exhibit 2(b) in File
No. 2-46530, Exhibit 2(aa) in File No. 2-53860, Exhibit 2(bb)
in File No. 2-54285, Exhibit 2(bb) in File No. 2-57510, Exhibit
2(cc) in File No. 2-57510, Exhibit 2(ee) in File No. 2-60276,
Exhibit 2 in File No. 0-849, Exhibit 2 in File No. 0-849,
Exhibit 2 in File No. 0-849, Exhibit 4(g) in File No. 33-3995,
Exhibit 4(h) in File No. 0-849, Exhibit 4(m) in File No. 0-849
and Exhibit 4(f) in File No. 0-4117-1)
4.10* Indenture (For Unsecured Subordinated Debt Securities), dated
as of December 1, 1995, between IESU and The First National
Bank of Chicago, as Trustee (Subordinated Indenture)
(incorporated by reference to Exhibit 4(i) to IESU's Amendment
No. 1 to Registration Statement, File No. 33-62259)
4.11* Indenture (For Senior Unsecured Debt Securities), dated as of
August 1, 1997, between IESU and The First National Bank of
Chicago, as Trustee (incorporated by reference to Exhibit 4(j)
to IESU's Registration Statement, File No. 333-32097)
4.12* The Original through the Nineteenth Supplemental Indentures
of IPC to The Chase Manhattan Bank and Carl E. Buckley and C.
J. Heinzelmann, as Trustees, dated January 1, 1948 securing
First Mortgage Bonds (incorporated by reference to Exhibits
4(b) through 4(t) to IPC's Registration Statement No. 33-59352
dated March 11, 1993)
4.13* Twentieth Supplemental Indenture of IPC to The Chase
Manhattan Bank and C. J. Heinzelmann, as Trustees, dated May
15, 1993 (incorporated by reference to Exhibit 4(u) to IPC's
Registration Statement No. 33-59352 dated March 11, 1993)
4.14* Indenture, relating to Resources' debt securities, dated as
of November 4, 1999, among Resources, Alliant Energy, as
Guarantor, and Firstar Bank, N.A., as Trustee, (incorporated by
reference to Exhibit 4.1 to Resources' and Alliant Energy's
Registration Statement on Form S-4 (Registration No.
333-92859), and the indentures supplemental thereto dated,
respectively, November 4, 1999 and February 1, 2000 (Exhibit
4.2 in File No. 33-92859 and Exhibit 99.4 in Alliant Energy's
Form 8-K dated February 1, 2000)
4.15* Registration Rights Agreement, related to Resources' 7-3/8%
senior notes due 2009, dated as of November 9, 1999, among
Resources, Alliant Energy, Merrill Lynch, Pierce, Fenner &
Smith Incorporated, Morgan Stanley & Co. Incorporated, Salomon
Smith Barney Inc., ABN AMRO Incorporated and Barclays Capital
Inc. (incorporated by reference to Exhibit 4.5 to Resources'
and Alliant Energy's Registration Statement on Form S-4
(Registration No. 333-92859))
4.16* Registration Rights Agreement, related to Resources'
exchangeable senior notes due 2030, dated as of February 1,
2000, among Resources, Alliant Energy and Merrill Lynch,
Pierce, Fenner & Smith Incorporated (incorporated by reference
to Exhibit 99.5 to Alliant Energy's Current Report on Form 8-K
dated February 1, 2000)
4.17* Purchase Agreement, relating to Resources' 7-3/8% senior
notes due 2009, dated as of November 4, 1999, among Resources,
Alliant Energy, Merrill Lynch, Pierce, Fenner & Smith
Incorporated, Morgan Stanley & Co. Incorporated, Salomon Smith
Barney Inc., ABN AMRO Incorporated and Barclays Capital Inc.
(incorporated by reference to Exhibit 4.4 to Resources' and
Alliant Energy's Registration Statement on Form S-4
(Registration No. 333-92859))
4.18* Purchase Agreement, relating to Resources' exchangeable
senior notes due 2030, dated as of January 26, 1999, among
Resources, Alliant Energy and Merrill Lynch, Pierce, Fenner &
Smith Incorporated (incorporated by reference to Exhibit 99.2
to Alliant Energy's Current Report on Form 8-K dated February
1, 2000)
124
10.1* Service Agreement by and among WP&L, South Beloit, IESU, IPC,
and Corporate Services (incorporated by reference to Exhibit
10.1 to Alliant Energy's Form 10-Q for the quarter ended June
30, 1998)
10.2* Service Agreement by and among Resources, IPC Development
Company, Inc. and Corporate Services (incorporated by reference
to Exhibit 10.2 to Alliant Energy's Form 10-Q for the quarter
ended June 30, 1998)
10.3* System Coordination and Operating Agreement dated April 11,
1997, among IESU, IPC, WP&L and Corporate Services
(incorporated by reference to Exhibit 10.3 to Alliant Energy's
Form 10-Q for the quarter ended June 30, 1998)
10.4* Joint Power Supply Agreement among WPSC, WP&L, and MG&E,
dated February 2, 1967 (incorporated by reference to Exhibit
4.09 of WPSC in File No. 2-27308)
10.5* Joint Power Supply Agreement among WPSC, WP&L, and MG&E,
dated July 26, 1973 (incorporated by reference to Exhibit 5.04A
of WPSC in File No. 2-48781)
10.6* Basic Generating Agreement, Unit 4, Edgewater Generating
Station, dated June 5, 1967, between WP&L and WPSC
(incorporated by reference to Exhibit 4.10 of WPSC in File No.
2-27308)
10.7* Agreement for Construction and Operation of Edgewater 5
Generating Unit, dated February 24, 1983, between WP&L, WEPCO
and WPSC (incorporated by reference to Exhibit 10C-1 to WPSC's
Form 10-K for the year 1983 (File No. 1-3016))
10.7a* Amendment No. 1 to Agreement for Construction and Operation
of Edgewater 5 Generating Unit, dated December 1, 1988
(incorporated by reference to Exhibit 10C-2 to WPSC's Form 10-K
for the year 1988 (File No. 1-3016))
10.8* Revised Agreement for Construction and Operation of Columbia
Generating Plant among WPSC, WP&L, and MG&E, dated July 26,
1973 (incorporated by reference to Exhibit 5.07 of WPSC in File
No. 2-48781)
10.9* Operating and Transmission Agreement between CIPCO and IESU
(incorporated by reference to Exhibit 10(q) to IESU's Form 10-K
for the year 1990)
10.10* DAEC Ownership Participation Agreement dated June 1, 1970
between CIPCO, Corn Belt Power Cooperative and IESU
(incorporated by reference to Exhibit 5(kk) to IESU's
Registration Statement, File No. 2-38674)
10.11* DAEC Operating Agreement dated June 1, 1970 between CIPCO, Corn
Belt Power Cooperative and IESU (incorporated by reference to
Exhibit 5(ll) to IESU's Registration Statement, File No.
2-38674)
10.12* DAEC Agreement for Transmission, Transformation, Switching, and
Related Facilities dated June 1, 1970 between CIPCO, Corn Belt
Power Cooperative and IESU (incorporated by reference to
Exhibit 5(mm) to IESU's Registration Statement, File No.
2-38674)
10.13* Basic Generating Agreement dated April 16, 1975 between Iowa
Public Service Company, Iowa Power and Light Company,
Iowa-Illinois Gas and Electric Company and IESU for the joint
ownership of Ottumwa Generating Station-Unit 1 (OGS-1)
(incorporated by reference to Exhibit 1 to IESU's Form 10-K for
the year 1977)
10.13a*Addendum Agreement to the Basic Generating Agreement for OGS-1
dated December 7, 1977 between Iowa Public Service Company,
Iowa-Illinois Gas and Electric Company, Iowa Power and Light
Company and IESU for the purchase of 15% ownership in OGS-1
(incorporated by reference to Exhibit 3 to IESU's Form 10-K for
the year 1977)
125
10.14* Second Amended and Restated Credit Agreement dated as of
September 17, 1987 between Arnold Fuel, Inc. and the First
National Bank of Chicago and the Amended and Restated Consent
and Agreement dated as of September 17, 1987 by IESU
(incorporated by reference to Exhibit 10(j) to IESU's Form 10-K
for the year 1987)
10.15 Second Amended and Restated November 1998 Stockholders'
Agreement entered into as of December 17, 1999, by and among
McLeod, Alliant Energy, Investments and certain other principal
stockholders of McLeod
10.16 Second Amended and Restated January 1999 Stockholders'
Agreement entered into as of December 17, 1999, by and among
McLeod, Alliant Energy, Investments and certain other principal
stockholders of McLeod
10.17#*Alliant Energy LTEIP, as amended (incorporated by reference
to Exhibit 10.1 to Alliant Energy's Form 10-Q for the quarter
ended June 30, 1999)
10.18#*Alliant Energy 1998 Officer Incentive Compensation Plan
(incorporated by reference to Exhibit 10.16 to Alliant Energy's
Form 10-Q for the quarter ended June 30, 1998)
10.19#*Restricted Stock Agreement pursuant to the Alliant Energy LTEIP
(incorporated by reference to Exhibit 10.1 to Alliant Energy's
Form 10-Q for the quarter ended March 31, 1999)
10.20#*Corporate Services Key Employee Deferred Compensation Plan
(incorporated by reference to Exhibit 10.18 to Alliant Energy's
Form 10-Q for the quarter ended June 30, 1998)
10.21#*Key Employee Deferred Compensation Plan (incorporated by
reference to Exhibit 10(n) to IES's Form 10-K for the year 1987)
10.21a#* Amendments to Key Employee Deferred Compensation Agreement
for Key Employees (incorporated by reference to Exhibit 10(v)
to IES's Form 10-Q for the quarter ended March 31, 1990)
10.22#*Alliant Energy Deferred Compensation Plan for Directors
(incorporated by reference to Exhibit I-6 to Alliant Energy's
Post-Effective Amendment No. 1 to Form U-1, File No. 70-8891)
10.23#*IES Grantor Trust for Director Retirement Plan (incorporated
by reference to Exhibit 10(c) to IES's Form 10-Q for the
quarter ended September 30, 1997)
10.24#* IES Grantor Trust for Deferred Compensation Agreements
(incorporated by reference to Exhibit 10(d) to IES's Form 10-Q
for the quarter ended September 30, 1997)
10.25#* IES Grantor Trust for Supplemental Retirement Agreements
(incorporated by reference to Exhibit 10(e) to IES's Form 10-Q
for the quarter ended September 30, 1997)
10.26#* IESU Grantor Trust for Deferred Compensation Agreements
(incorporated by reference to Exhibit 10(f) to IES's Form 10-Q
for the quarter ended September 30, 1997)
10.27#* IESU Grantor Trust for Supplemental Retirement Agreements
(incorporated by reference to Exhibit 10(g) to IES's Form 10-Q
for the quarter ended September 30, 1997)
126
10.28#* IPC Irrevocable Trust Agreement dated April 30, 1990
(incorporated by reference to Exhibit 99.f to IPC's Form 10-K
for the year 1993)
10.29#* IPC Irrevocable Trust Agreement dated December 1997
(incorporated by reference to Exhibit 99.7 to IPC's Form 10-K
for the year 1997)
10.30#* Form of Supplemental Retirement Agreement (incorporated by
reference to Exhibit 10.15 to Alliant Energy's Form 10-Q for
the quarter ended June 30, 1998)
10.31#* Supplemental Retirement Plan (incorporated by reference to
Exhibit 10(l) to IES's Form 10-K for the year 1987)
10.32#* Executive Change of Control Severance Agreement - Vice
Presidents (incorporated by reference to Exhibit 10(b) to IES's
Form 10-Q for the quarter ended September 30, 1996)
10.33#*Key Executive Employment and Severance Agreement, dated March
29, 1999, by and between Alliant Energy and Erroll B. Davis,
Jr. (incorporated by reference to Exhibit 10.2 to Alliant
Energy's Form 10-Q for the quarter ended March 31, 1999)
10.34#*Key Executive Employment and Severance Agreement, dated March
29, 1999, by and between Alliant Energy and each of J.E.
Hoffman, W.D. Harvey, E.G. Protsch, P.J. Wegner, T.M. Walker
and B.J. Swan (incorporated by reference to Exhibit 10.3 to
Alliant Energy's Form 10-Q for the quarter ended March 31, 1999)
10.35#*Key Executive Employment and Severance Agreement, dated March
29, 1999, by and between Alliant Energy and each of T.L. Aller,
D.A. Doyle, E.M. Gleason, D.K. Langer, D.L. Mineck, D.R. Sharp
and K.K. Zuhlke (incorporated by reference to Exhibit 10.4 to
Alliant Energy's Form 10-Q for the quarter ended March 31, 1999)
10.36* Employment Agreement by and between Alliant Energy and Erroll
B. Davis, Jr., amended and restated as of March 29, 1999
(incorporated by reference to Exhibit 10.5 to Alliant Energy's
Form 10-Q for the quarter ended March 31, 1999)
10.37#* Employment Agreement, dated as of April 21, 1998, by and
between Alliant Energy and Lee Liu (incorporated by reference
to Exhibit 10.2 to Alliant Energy's Form 8-K dated April 21,
1998)
10.38#* Severance Agreement by and between Alliant Energy and Anthony
J. Amato (incorporated by reference to Exhibit 10.28 to Alliant
Energy's Form 10-Q for the quarter ended June 30, 1998)
10.39#* Executive Guaranty Plan (incorporated by reference to Exhibit
10(p) to IES's Form 10-K for the year 1987)
10.40#* Early Retirement Agreement, dated as of October 7, 1998, by
and between Alliant Energy et al. and Michael R. Chase
(incorporated by reference to Exhibit 10.1 to Alliant Energy's
Form 10-Q for the quarter ended September 30, 1998)
10.41#* Early Retirement Agreement, dated as of December 4, 1998, by
and between Alliant Energy et al. and Richard R. Ewers
(incorporated by reference to Exhibit 10.46 to Alliant Energy's
Form 10-K for the year 1998)
10.42#* Consulting Agreement by and between Alliant Energy and Wayne
H. Stoppelmoor (incorporated by reference to Exhibit 10.2 to
Alliant Energy's Form 10-Q for the quarter ended June 30, 1999)
10.43#* Executive Tenure Compensation Plan as revised November 1992
(incorporated by reference to Exhibit 10A to Alliant Energy's
Form 10-K for the year 1992)
127
10.43a#* Amendment to Executive Tenure Compensation Plan adopted
February 23, 1998 (incorporated by reference to Exhibit 10.19a
to Alliant Energy's Form 10-Q for the quarter ended June 30,
1998)
21 Subsidiaries of Alliant Energy
23 Consent of Independent Public Accountants for Alliant Energy
27.1 Financial Data Schedule for Alliant Energy at and for the
period ended December 31, 1999
27.2 Financial Data Schedule for IESU at and for the period ended
December 31, 1999
27.3 Financial Data Schedule for WP&L at and for the period ended
December 31, 1999
Pursuant to Item 601(b)(4)(iii) of Regulation S-K, the registrants agree
to furnish to the SEC, upon request, any instrument defining the rights
of holders of unregistered long-term debt not filed as an exhibit to this
Form 10-K. No such instrument authorizes securities in excess of 10% of
the total assets of Alliant Energy, WP&L or IESU, as the case may be.
Documents incorporated by reference to filings made by Alliant Energy
under the Securities Exchange Act of 1934, as amended, are under File No.
1-9894. Documents incorporated by reference to filings made by WP&L
under the Securities Exchange Act of 1934, as amended, are under File No.
0-337. Documents incorporated by reference to filings made by IES under
the Securities Exchange Act of 1934, as amended, are under File No.
1-9187. Documents incorporated by reference to filings made by IESU
under the Securities Exchange Act of 1934, as amended, are under File No.
0-4117-1. Documents incorporated by reference to filings made by IPC
under the Securities Exchange Act of 1934, as amended, are under File No.
1-3632.
# - A management contract or compensatory plan or arrangement.
(b) Reports on Form 8-K
--------------------
Alliant Energy - None.
IESU - None.
WP&L - None.
128
ALLIANT ENERGY, IESU AND WP&L
SCHEDULE II -VALUATION AND QUALIFYING ACCOUNTS AND RESERVES
FOR THE YEARS ENDED DECEMBER 31, 1999, 1998 AND 1997
Additions -
Balance, Charged to Balance,
Description January 1 Expense Deductions (1) December 31
- -------------------------------------------------------------------------------------------------------------------
(in thousands)
Valuation and Qualifying Accounts Which are Deducted in the Balance Sheet From the Assets to Which They Apply:
Accumulated Provision for Uncollectible Accounts:
Alliant Energy
Year ended December 31, 1999 $3,128 $2,909 $2,677 $3,360
Year ended December 31, 1998 2,636 3,740 3,248 3,128
Year ended December 31, 1997 3,319 3,315 3,998 2,636
IESU
Year ended December 31, 1999 $1,415 $2,268 $2,042 $1,641
Year ended December 31, 1998 854 2,840 2,279 1,415
Year ended December 31, 1997 757 2,439 2,342 854
WP&L
Year ended December 31, 1999 $8 $-- $2 $6
Year ended December 31, 1998 12 -- 4 8
Year ended December 31, 1997 45 -- 33 12
Note: The above provisions relate to various customer, notes and other receivable balances included in various
line items on the respective Consolidated Balance Sheets.
Other Reserves:
Accumulated Provision for Injuries & Damages, Workers' Compensation, Litigation and Other Miscellaneous Reserves:
Alliant Energy
Year ended December 31, 1999 $7,458 $5,479 $4,942 $7,995
Year ended December 31, 1998 6,400 7,738 6,680 7,458
Year ended December 31, 1997 4,616 3,728 1,944 6,400
IESU
Year ended December 31, 1999 $3,129 $2,036 $2,547 $2,618
Year ended December 31, 1998 5,033 215 2,119 3,129
Year ended December 31, 1997 3,219 3,384 1,570 5,033
WP&L
Year ended December 31, 1999 $2,799 $1,937 $1,742 $2,994
Year ended December 31, 1998 1 2,798 -- 2,799
Year ended December 31, 1997 -- 1 -- 1
Reserve for Merger-Related Employee Separation Charges:
Alliant Energy
Year ended December 31, 1999 $5,712 $-- $4,744 $968
Year ended December 31, 1998 -- 9,950 4,238 5,712
Year ended December 31, 1997 -- -- -- --
IESU
Year ended December 31, 1999 $1,893 $-- $1,215 $678
Year ended December 31, 1998 -- 3,551 1,658 1,893
Year ended December 31, 1997 -- -- -- --
WP&L
Year ended December 31, 1999 $766 $-- $766 $--
Year ended December 31, 1998 -- 867 101 766
Year ended December 31, 1997 -- -- -- --
(1) Deductions are of the nature for which the reserves were created. In the case of the accumulated provision
for uncollectible accounts, deductions from this reserve are reduced by recoveries of amounts previously written
off.
129
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 on the 29th day of March 2000.
ALLIANT ENERGY CORPORATION
By: /s/ Erroll B. Davis, Jr.
Erroll B. Davis, Jr.
President and Chief Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
registrant and in the capacities indicated on the 29th day of March 2000.
/s/ Erroll B. Davis, Jr. President, Chief Executive Officer and Director (Principal Executive Officer)
- ----------------------
Erroll B. Davis, Jr.
/s/ Thomas M. Walker Executive Vice President and Chief Financial Officer (Principal Financial Officer)
- ---------------------
Thomas M. Walker
/s/ Daniel A. Doyle Vice President - Chief Accounting and Financial Planning Officer
- --------------------
Daniel A. Doyle (Principal Accounting Officer)
/s/ Alan B. Arends Director /s/ Milton E. Neshek Director
- ----------------------------------------- -------------------------------------------
Alan B. Arends Milton E. Neshek
/s/ Jack B. Evans Director /s/ Judith D.Pyle Director
- ----------------------------------------- -------------------------------------------
Jack B. Evans Judith D. Pyle
/s/ Rockne G. Flowers Director /s/ Robert D. Ray Director
- ----------------------------------------- -------------------------------------------
Rockne G. Flowers Robert D. Ray
/s/ Joyce L. Hanes Director /s/ Robert W. Schlutz Director
- ----------------------------------------- -------------------------------------------
Joyce L. Hanes Robert W. Schlutz
/s/ Lee Liu Director /s/ Wayne H. Stoppelmoor Director
- ----------------------------------------- -------------------------------------------
Lee Liu Wayne H. Stoppelmoor
/s/ Katharine C. Lyall Director /s/ Anthony R. Weiler Director
- ----------------------------------------- -------------------------------------------
Katharine C. Lyall Anthony R. Weiler
/s/ Arnold M. Nemirow Director
- -----------------------------------------
Arnold M. Nemirow
130
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 on the 29h day of
March 2000.
IES UTILITIES INC.
By: /s/ Erroll B. Davis, Jr.
Erroll B. Davis, Jr.
Chief Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
registrant and in the capacities indicated on the 29th day of
March 2000.
/s/ Erroll B. Davis, Jr. Chief Executive Officer and Director (Principal Executive Officer)
- ----------------------
Erroll B. Davis, Jr.
/s/ Thomas M. Walker Executive Vice President and Chief Financial Officer (Principal Financial Officer)
- ---------------------
Thomas M. Walker
/s/ Daniel A. Doyle Vice President - Chief Accounting and Financial Planning Officer
- --------------------
Daniel A. Doyle (Principal Accounting Officer)
/s/ Alan B. Arends Director /s/ Milton E. Neshek Director
- ----------------------------------------- -------------------------------------------
Alan B. Arends Milton E. Neshek
/s/ Jack B. Evans Director /s/ Judith D.Pyle Director
- ----------------------------------------- -------------------------------------------
Jack B. Evans Judith D. Pyle
/s/ Rockne G. Flowers Director /s/ Robert D. Ray Director
- ----------------------------------------- -------------------------------------------
Rockne G. Flowers Robert D. Ray
/s/ Joyce L. Hanes Director /s/ Robert W. Schlutz Director
- ----------------------------------------- -------------------------------------------
Joyce L. Hanes Robert W. Schlutz
/s/ Lee Liu Director /s/ Wayne H. Stoppelmoor Director
- ----------------------------------------- -------------------------------------------
Lee Liu Wayne H. Stoppelmoor
/s/ Katharine C. Lyall Director /s/ Anthony R. Weiler Director
- ----------------------------------------- -------------------------------------------
Katharine C. Lyall Anthony R. Weiler
/s/ Arnold M. Nemirow Director
- -----------------------------------------
Arnold M. Nemirow
131
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 on the 29th day of
March 2000.
WISCONSIN POWER AND LIGHT COMPANY
By: /s/ Erroll B. Davis, Jr.
Erroll B. Davis, Jr.
Chief Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
registrant and in the capacities indicated on the 29th day of March 2000.
/s/ Erroll B. Davis, Jr. Chief Executive Officer and Director (Principal Executive Officer)
- ----------------------
Erroll B. Davis, Jr.
/s/ Thomas M. Walker Executive Vice President and Chief Financial Officer (Principal Financial Officer)
- ---------------------
Thomas M. Walker
/s/ Daniel A. Doyle Vice President - Chief Accounting and Financial Planning Officer
- --------------------
Daniel A. Doyle (Principal Accounting Officer)
/s/ Alan B. Arends Director /s/ Milton E. Neshek Director
- ----------------------------------------- -------------------------------------------
Alan B. Arends Milton E. Neshek
/s/ Jack B. Evans Director /s/ Judith D.Pyle Director
- ----------------------------------------- -------------------------------------------
Jack B. Evans Judith D. Pyle
/s/ Rockne G. Flowers Director /s/ Robert D. Ray Director
- ----------------------------------------- -------------------------------------------
Rockne G. Flowers Robert D. Ray
/s/ Joyce L. Hanes Director /s/ Robert W. Schlutz Director
- ----------------------------------------- -------------------------------------------
Joyce L. Hanes Robert W. Schlutz
/s/ Lee Liu Director /s/ Wayne H. Stoppelmoor Director
- ----------------------------------------- -------------------------------------------
Lee Liu Wayne H. Stoppelmoor
/s/ Katharine C. Lyall Director /s/ Anthony R. Weiler Director
- ----------------------------------------- -------------------------------------------
Katharine C. Lyall Anthony R. Weiler
/s/ Arnold M. Nemirow Director
- -----------------------------------------
Arnold M. Nemirow
132
EXHIBIT INDEX
Exhibit Description
3.2 Bylaws of Alliant Energy, as amended, effective as of March 15, 2000
3.4 Bylaws of WP&L, as amended, effective as of March 15, 2000
3.6 Bylaws of IESU, as amended, effective as of March 15, 2000
10.15 Second Amended and Restated November 1998 Stockholders' Agreement entered into as of December
17, 1999, by and among McLeod, Alliant Energy, Investments and certain other principal
stockholders of McLeod
10.16 Second Amended and Restated January 1999 Stockholders' Agreement entered into as of December 17,
1999, by and among McLeod, Alliant Energy, Investments and certain other principal stockholders
of McLeod
21 Subsidiaries of Alliant Energy
23 Consent of Independent Public Accountants for Alliant Energy
27.1 Financial Data Schedule for Alliant Energy at and for the period ended December 31, 1999
27.2 Financial Data Schedule for IESU at and for the period ended December 31, 1999
27.3 Financial Data Schedule for WP&L at and for the period ended December 31, 1999
EX-3.2
2
BYLAWS OF ALLIANT ENERGY CORPORATION
EXHIBIT 3.2
BYLAWS
OF
ALLIANT ENERGY CORPORATION
Effective as of March 15, 2000
ARTICLE I
OFFICES
Section 1.1 PRINCIPAL AND BUSINESS OFFICES. - The Corporation may have such
principal and other business offices, either within or without the State of
Wisconsin, as the Board of Directors may designate or as the business of the
Corporation may require from time to time.
Section 1.2 REGISTERED OFFICE. - The registered office of the Corporation
required by the Wisconsin Business Corporation Law to be maintained in the
State of Wisconsin may be, but need not be, identical with the principal
office in the State of Wisconsin, and the address of the registered office
may be changed from time to time by the Board of Directors or by the
registered agent. The business office of the registered agent of the
Corporation shall be identical to such registered office.
ARTICLE II
SEAL
Section 2.1 CORPORATE SEAL. - The corporate seal shall have inscribed thereon
the name of the Corporation and the words "CORPORATE SEAL, WISCONSIN." Said
seal may be used by causing it or a facsimile thereof to be impressed or
affixed or reproduced.
ARTICLE III
SHAREOWNERS
Section 3.1 ANNUAL MEETING. - The annual meeting of the shareowners (the
"Annual Meeting") shall be held at such date and time as the Board of
Directors may determine. In fixing a meeting date for any Annual Meeting,
the Board of Directors may consider such factors as it deems relevant within
the good faith exercise of its business judgment. At each Annual Meeting,
the shareowners shall elect that number of directors equal to the number of
directors in the class whose term expires at the time of such meeting. At
any such Annual Meeting, only other business properly brought before the
meeting in accordance with Section 3.14 of these Bylaws may be transacted.
If the election of directors shall not be held on the date fixed as herein
provided, for any Annual Meeting, or any adjournment thereof, the Board of
Directors shall cause the election to be held at a special meeting of
shareowners (a "Special Meeting") as soon thereafter as is practicable.
Section 3.2 SPECIAL MEETINGS. - A Special Meeting may be called only by (i)
the Board of Directors or (ii) the Chief Executive Officer and shall be
called by the Chief Executive Officer upon the demand, in accordance with
this Section 3.2, of the holders of record of shares representing at least
10% of all the votes entitled to be cast on any issue proposed to be
considered at the Special Meeting.
(a) In order that the Corporation may determine the shareowners entitled to
demand a Special Meeting, the Board of Directors may fix a record date to
determine the shareowners entitled to make such a demand (the "Demand Record
Date"). The Demand Record Date shall not precede the date upon which the
resolution fixing the Demand Record Date is adopted by the Board of Directors
and shall not be more than ten days after the date upon which the resolution
fixing the Demand Record Date is adopted by the Board of Directors. Any
shareowner of record seeking to have shareowners demand a Special Meeting
shall, by sending written notice to the Secretary of the Corporation by hand
or by certified or registered mail, return receipt requested, request the
Board of Directors to fix a Demand Record Date. The Board of Directors shall
promptly, but in all events within ten days after the date on which a valid
request to fix a Demand Record Date is received, adopt a resolution fixing
the Demand Record Date and shall make a public announcement of such Demand
Record Date. If no Demand Record Date has been fixed by the Board of
Directors within ten days after the date on which such request is received by
the Secretary, the Demand Record Date shall be the 10th day after the first
date on which a valid written request to set a Demand Record Date is received
by the Secretary. To be valid, such written request shall set forth the
purpose or purposes for which the Special Meeting is to be held, shall be
signed by one or more shareowners of record (or their duly authorized proxies
or other representatives), shall bear the date of signature of each such
shareowner (or proxy or other representative) and shall set forth all
information about each such shareowner and about the beneficial owner or
owners, if any, on whose behalf the request is made that would be required to
be set forth in a shareowner's notice described in paragraph (a) (ii) of
Section 3.14 of these Bylaws.
(b) In order for a shareowner or shareowners to demand a Special Meeting, a
written demand or demands for a Special Meeting by the holders of record as
of the Demand Record Date of shares representing at least 10% of all the
votes entitled to be cast on any issue proposed to be considered at the
Special Meeting must be delivered to the Corporation. To be valid, each
written demand by a shareowner for a Special Meeting shall set forth the
specific purpose or purposes for which the Special Meeting is to be held
(which purpose or purposes shall be limited to the purpose or purposes set
forth in the written request to set a Demand Record Date received by the
Corporation pursuant to paragraph (b) of this Section 3.2), shall be signed
by one or more persons who as of the Demand Record Date are shareowners of
record (or their duly authorized proxies or other representatives), shall
bear the date of signature of each such shareowner (or proxy or other
representative), and shall set forth the name and address, as they appear in
the Corporation's books, of each shareowner signing such demand and the class
and number of shares of the Corporation which are owned of record and
beneficially by each such shareowner, shall be sent to the Secretary by hand
or by certified or registered mail, return receipt requested, and shall be
received by the Secretary within seventy days after the Demand Record Date.
(c) The Corporation shall not be required to call a Special Meeting upon
shareowner demand unless, in addition to the documents required by paragraph
(c) of this Section 3.2, the Secretary receives a written agreement signed by
each Soliciting Shareowner (as defined below), pursuant to which each
Soliciting Shareowner, jointly and severally, agrees to pay the Corporation's
costs of holding the Special Meeting, including the costs of preparing and
mailing proxy materials for the Corporation's own solicitation, provided that
if each of the resolutions introduced by any Soliciting Shareowner at such
meeting is adopted, and each of the individuals nominated by or on behalf of
any Soliciting Shareowner for election as a director at such meeting is
elected, then the Soliciting Shareowners shall not be required to pay such
costs. For purposes of this paragraph (d), the following terms shall have
the meanings set forth below:
(i) "Affiliate" of any Person (as defined herein) shall mean any Person
controlling, controlled by or under common control with such
first Person.
(ii) "Participant" shall have the meaning assigned to such term in Rule
14a-11 promulgated under the Securities Exchange Act of 1934, as
amended (the "Exchange Act").
(iii) "Person" shall mean any individual, firm, corporation, partnership,
joint venture, association, trust, unincorporated organization or
other entity.
(iv) "Proxy" shall have the meaning assigned to such term in Rule 14a-1
promulgated under the Exchange Act.
(v) "Solicitation" shall have the meaning assigned to such term in Rule
14a-11 promulgated under the Exchange Act.
(vi) "Soliciting Shareowner" shall mean, with respect to any Special Meeting
demanded by a shareowner or shareowners, any of the following
Persons:
(A) if the number of shareowners signing the demand or demands of meeting
delivered to the Corporation pursuant to paragraph
(c) of this Section 3.2 is ten or fewer, each
shareowner signing any such demand;
(B) if the number of shareowners signing the demand or demands of meeting
delivered to the Corporation pursuant to paragraph
(c) of this Section 3.2 is more than ten, each Person
who either (I) was a Participant in any Solicitation
of such demand or demands or (II) at the time of the
delivery to the Corporation of the documents
described in paragraph (c) of this Section 3.2 had
engaged or intends to engage in any Solicitation of
Proxies for use at such Special Meeting (other than a
Solicitation of Proxies on behalf of the
Corporation); or
(C) any Affiliate of a Soliciting Shareowner, if a majority of the
directors then in office determine, reasonably and in
good faith, that such Affiliate should be required to
sign the written notice described in paragraph (c) of
this Section 3.2 and/or the written agreement
described in this paragraph (d) in order to prevent
the purposes of this Section 3.2 from being evaded.
(d) Except as provided in the following sentence, any Special Meeting shall
be held at such hour and day as may be designated by whichever of the Board
of Directors or the Chief Executive Officer shall have called such meeting.
In the case of any Special Meeting called by the Chief Executive Officer upon
the demand of shareowners (a "Demand Special Meeting"), such meeting shall be
held at such hour and day as may be designated by the Board of Directors;
provided, however, that the date of any Demand Special Meeting shall be not
more than seventy days after the Meeting Record Date (as defined in Section
3.6 hereof); and provided further that in the event that the directors then
in office fail to designate an hour and date for a Demand Special Meeting
within ten days after the date that valid written demands for such meeting by
the holders of record as of the Demand Record Date of shares representing at
least 10% of all the votes entitled to be cast on each issue proposed to be
considered at the Special Meeting are delivered to the Corporation (the
"Delivery Date"), then such meeting shall be held at 2:00 P.M. local time on
the 100th day after the Delivery Date or, if such 100th day is not a Business
Day (as defined below), on the first preceding Business Day. In fixing a
meeting date for any Special Meeting, the Board of Directors or the Chief
Executive Officer may consider such factors as it or he deems relevant within
the good faith exercise of its or his business judgment, including, without
limitation, the nature of the action proposed to be taken, the facts and
circumstances surrounding any demand for such meeting, and any plan of the
Board of Directors to call an Annual Meeting or a Special Meeting for the
conduct of related business.
(e) The Corporation may engage regionally or nationally recognized
independent inspectors of elections to act as an agent of the Corporation for
the purpose of promptly performing a ministerial review of the validity of
any purported written demand or demands for a Special Meeting received by the
Secretary. For the purpose of permitting the inspectors to perform such
review, no purported demand shall be deemed to have been delivered to the
Corporation until the earlier of (i) five Business Days following receipt by
the Secretary of such purported demand and (ii) such date as the independent
inspectors certify to the Corporation that the valid demands received by the
Secretary represent at least 10% of all the votes entitled to be cast on each
issue proposed to be considered at the Special Meeting. Nothing contained in
this paragraph (f) shall in any way be construed to suggest or imply that the
Board of Directors or any shareowner shall not be entitled to contest the
validity of any demand, whether during or after such five Business Day
period, or to take any other action (including, without limitation, the
commencement, prosecution or defense of any litigation with respect thereto).
(f) For purposes of these Bylaws, "Business Day" shall mean any day other
than a Saturday, a Sunday or a day on which banking institutions in the State
of Wisconsin are authorized or obligated by law or executive order to close.
Section 3.3 PLACE OF MEETING. - The Board of Directors or the Chief Executive
Officer may designate any place, either within or without the State of
Wisconsin, as the place for any Annual Meeting or any Special Meeting, or for
any postponement thereof. If no designation is made, the place of meeting
shall be the principal office of the Corporation. Any meeting may be
adjourned to reconvene at any place designated by vote of the Board of
Directors or determined by the Chief Executive Officer.
Section 3.4 NOTICE OF MEETINGS - Written notice stating the date, time and
place of any meeting of shareowners shall be delivered not less than ten days
nor more than seventy days before the date of the meeting (unless a different
time period is provided by the Wisconsin Business Corporation Law or the
Articles of Incorporation), either personally or by mail, by or at the
direction of the Chief Executive Officer or the Secretary, to each shareowner
of record entitled to vote at such meeting and to such other persons as
required by the Wisconsin Business Corporation Law. In the event of any
Demand Special Meeting, such notice of meeting shall be sent not more than
thirty days after the Delivery Date. For purposes of this Section 3.4,
notice by "electronic transmission" (as such term is defined in Section
180.0103(7m) of the Wisconsin Business Corporation Law") shall be deemed to
constitute written notice. Written notice pursuant to this Section 3.4 shall
be deemed to be effective (a) when mailed, if mailed postpaid and addressed
to the shareowner's address shown in the Corporation's current record of
shareowners or (b) when electronically transmitted to the shareowner in a
manner authorized by the shareowner. Unless otherwise required by the
Wisconsin Business Corporation Law or the Articles of Incorporation, a notice
of an Annual Meeting need not include a description of the purpose for which
the meeting is called. In the case of any Special Meeting, (i) the notice of
meeting shall describe any business that the Board of Directors shall have
theretofore determined to bring before the meeting and (ii) in the case of a
Demand Special Meeting, the notice of meeting (A) shall describe any business
set forth in the statement of purpose of the demands received by the
Corporation in accordance with Section 3.2 of these Bylaws and (B) shall
contain all of the information required in the notice received by the
Corporation in accordance with Section 3.14(b) of these Bylaws. If an Annual
Meeting or Special Meeting is adjourned to a different date, time or place,
the Corporation shall not be required to give notice of the new date, time or
place if the new date, time or place is announced at the meeting before
adjournment; provided, however, that if a new Meeting Record Date for an
adjourned meeting is or must be fixed, the Corporation shall give notice of
the adjourned meeting to persons who are shareowners as of the new Meeting
Record Date.
Section 3.5 WAIVER OF NOTICE - A shareowner may waive any notice required by
the Wisconsin Business Corporation Law, the Articles of Incorporation or
these Bylaws before or after the date and time stated in the notice. The
waiver shall be in writing and signed by the shareowner entitled to the
notice, contain the same information that would have been required in the
notice under applicable provisions of the Wisconsin Business Corporation Law
(except that the time and place of meeting need not be stated) and be
delivered to the Corporation for inclusion in the corporate records. A
shareowner's attendance at any Annual Meeting or Special Meeting, in person
or by proxy, waives objection to all of the following: (a) lack of notice or
defective notice of the meeting, unless the shareowner at the beginning of
the meeting or promptly upon arrival objects to holding the meeting or
transacting business at the meeting; and (b) consideration of a particular
matter at the meeting that is not within the purpose described in the meeting
notice, unless the shareowner objects to considering the matter when it is
presented.
Section 3.6 FIXING OF RECORD DATE. - The Board of Directors may fix in
advance a date not less than ten days and not more than seventy days prior to
the date of an Annual Meeting or Special Meeting as the record date for the
determination of shareowners entitled to notice of, or to vote at, such
meeting (the "Meeting Record Date"). In the case of any Demand Special
Meeting, (i) the Meeting Record Date shall be not later than the 30th day
after the Delivery Date and (ii) if the Board of Directors fails to fix the
Meeting Record Date within thirty days after the Delivery Date, then the
close of business on such 30th day shall be the Meeting Record Date. The
shareowners of record on the Meeting Record Date shall be the shareowners
entitled to notice of and to vote at the meeting. Except as provided by the
Wisconsin Business Corporation Law for a court-ordered adjournment, a
determination of shareowners entitled to notice of and to vote at an Annual
Meeting or Special Meeting is effective for any adjournment of such meeting
unless the Board of Directors fixes a new Meeting Record Date, which it shall
do if the meeting is adjourned to a date more than 120 days after the date
fixed for the original meeting. The Board of Directors may also fix in
advance a date as the record date for the purpose of determining shareowners
entitled to take any other action or determining shareowners for any other
purpose. Such record date shall be not more than seventy days prior to the
date on which the particular action, requiring such determination of
shareowners, is to be taken. The record date for determining shareowners
entitled to a distribution (other than a distribution involving a purchase,
redemption or other acquisition of the Corporation's shares) or a share
dividend is the date on which the Board of Directors authorizes the
distribution or share dividend, as the case may be, unless the Board of
Directors fixes a different record date.
Section 3.7 SHAREOWNER LIST. - The Corporation shall have available,
beginning two (2) days after the notice of the meeting is given for which the
list was prepared and continuing to the date of the meeting, a complete
record of each shareowner entitled to vote at such meeting, or any
adjournment thereof, showing the address of and number of shares held by each
shareowner. The shareowner list shall be available for inspection by any
shareowner during normal business hours at the Corporation's principal office
or at a place identified in the meeting notice in the city where the meeting
will be held. The Corporation shall make the shareowners' list available at
the meeting and any shareowner or his agent or attorney may inspect the list
at any time the meeting or any adjournment thereof.
Section 3.8 QUORUM AND VOTING REQUIREMENTS.
(a) Shares entitled to vote as a separate voting group may take action on a
matter at any Annual Meeting or Special Meeting only if a quorum of those
shares exists with respect to that matter. If the Corporation has only one
class of stock outstanding, such class shall constitute a separate voting
group for purposes of this Section 3.8. Except as otherwise provided in the
Articles of Incorporation or the Wisconsin Business Corporation Law, a
majority of the votes entitled to be cast on the matter shall constitute a
quorum of the voting group for action on that matter. Once a share is
represented for any purpose at any Annual Meeting or Special Meeting, other
than for the purpose of objecting to holding the meeting or transacting
business at the meeting, it is considered present for purposes of determining
whether a quorum exists for the remainder of the meeting and for any
adjournment of that meeting unless a new Meeting Record Date is or must be
set for the adjourned meeting. If a quorum exists, except in the case of the
election of directors, action on a matter shall be approved if the votes cast
within the voting group favoring the action exceed the votes cast opposing
the action, unless the Articles of Incorporation or the Wisconsin Business
Corporation Law requires a greater number of affirmative votes. Unless
otherwise provided in the Articles of Incorporation, each director to be
elected shall be elected by a plurality of the votes cast by the shares
entitled to vote in the election of directors at an Annual Meeting or Special
Meeting at which a quorum is present.
(b) The Board of Directors acting by resolution may postpone and reschedule
any previously scheduled Annual Meeting or Special Meeting; provided,
however, that a Demand Special Meeting shall not be postponed beyond the
100th day following the Delivery Date. Any Annual Meeting or Special Meeting
may be adjourned from time to time, whether or not there is a quorum, (i) at
any time, upon a resolution by shareowners if the votes cast in favor of such
resolution by the holders of shares of each voting group entitled to vote on
any matter theretofore properly brought before the meeting exceed the number
of votes cast against such resolution by the holders of shares of each such
voting group or (ii) at any time prior to the transaction of any business at
such meeting, by the Chairperson of the Board or pursuant to a resolution of
the Board of Directors. No notice of the time and place of adjourned
meetings need be given except as required by the Wisconsin Business
Corporation Law. At any adjourned meeting at which a quorum shall be present
or represented, any business may be transacted which might have been
transacted at the meeting as originally notified.
Section 3.9 CONDUCT OF MEETING. - The Chairperson of the Board shall preside
at each meeting of shareowners. In the absence of the Chairperson of the
Board, such persons, in the following order, shall act as chair of the
meeting; the Vice Chairperson of the Board, the Chief Executive Officer, the
President, any Vice President, and the Director in attendance with the
longest tenure in that office. The Secretary, or if absent, an Assistant
Secretary, of the Company shall act as Secretary of each shareowner meeting.
Section 3.10 PROXIES. - At any Annual Meeting or Special Meeting, a
shareowner entitled to vote may vote his or her shares in person or by
proxy. A shareowner entitled to vote at an Annual Meeting or Special Meeting
may authorize another person to act for the shareowner by appointing the
person as proxy. Without limiting the manner in which a shareowner may
appoint a proxy, a shareowner or the shareowner's authorized officer,
director, employee, agent or attorney-in-fact may use any of the following as
a valid means to make such an appointment:
(a) Appointment of a proxy in writing by signing or causing the
shareowner's signature to be affixed to an appointment form by any reasonable
means, including, but not limited to, by facsimile signature.
(b) Appointment of a proxy by transmitting or authorizing the
transmission of an electronic transmission of the appointment to the person
who will be appointed as proxy or to a proxy solicitation firm, proxy support
service organization or like agent authorized to receive the transmission by
the person who will be appointed as proxy. Every electronic transmission
shall contain, or be accompanied by, information that can be used to
reasonably determine that the shareowner transmitted or authorized the
transmission of the electronic transmission. Any person charged with
determining whether a shareholder transmitted or authorized the transmission
of the electronic transmission shall specify the information upon which the
determination is made.
An appointment of a proxy is effective when a signed appointment form or an
electronic transmission of the appointment is received by the inspector of
election or the officer or agent of the Corporation authorized to tabulate
votes. An appointment is valid for eleven months unless a different period
is expressly provided in the appointment. Unless otherwise provided, a proxy
may be revoked any time before it is voted, either by appointing a new proxy
in accordance with the Wisconsin Business Corporation Law or by oral notice
given by the shareowner to the presiding officer during the meeting. The
presence of a shareowner who has made an effective proxy appointment shall
not itself constitute a revocation. The Board of Directors shall have the
power and authority to make rules establishing presumptions as to the
validity and sufficiency of proxies.
Section 3.11 VOTING OF SHARES. - Except as provided in the Articles of
Incorporation or statute, each outstanding share entitled to vote shall be
entitled to one (1) vote upon each matter submitted to a vote at a meeting of
shareowners.
Section 3.12 VOTING OF SHARES BY CERTAIN HOLDERS. - Shares standing in
the name of another corporation may be voted by such officer, agent or proxy
as the Bylaws of such corporation may prescribe, or, in the absence of such
provision, as the Board of Directors of such corporation may determine.
Shares held by an administrator, executor, guardian or
conservator may be voted by such person, either in person or by proxy,
without a transfer of such shares into that person's name. Shares standing
in the name of a trustee may be voted by such trustee, either in person or by
proxy, without a transfer of such shares into the trustee's name. The
Corporation may request evidence of such fiduciary status with respect to the
vote, consent, waiver, or proxy appointment.
Shares standing in the name of a receiver or trustee in
bankruptcy may be voted by such receiver or trustee, and shares held by or
under the control of a receiver may be voted by such receiver without the
transfer of the shares into such person's name if authority so to do is
contained in an appropriate order of the court by which such receiver was
appointed.
A pledgee, beneficial owner, or attorney-in-fact of the shares
held in the name of a shareholder shall be entitled to vote such shares. The
Corporation may request evidence of such signatory's authority to sign for
the shareholder with respect to the vote, consent, waiver, or proxy
appointment.
Neither treasury shares nor shares held by another corporation,
if a majority of the shares entitled to vote for the election of Directors of
such other corporation is held by the Corporation, shall be voted at any
meeting or counted in determining the total number of outstanding shares at
any given time.
Section 3.13 Action without Meeting. - Any action required or permitted
by the Articles of Incorporation or these Bylaws or any provision of the
Wisconsin Business Corporation Law to be taken at an Annual Meeting or
Special Meeting may be taken without a meeting if a written consent or
consents, describing the action so taken, is signed by all of the shareowners
entitled to vote with respect to the subject matter thereof and delivered to
the Corporation for inclusion in the corporate records.
Section 3.14 Notice of Shareowner Business and Nomination of Directors.
(a) Annual Meetings.
(i) Nominations of persons for election to the Board of Directors of the
Corporation and the proposal of business to be considered by the
shareowners may be made at an Annual Meeting (A) pursuant to the
Corporation's notice of meeting, (B) by or at the direction of
the Board of Directors or (C) by any shareowner of the
Corporation who is a shareowner of record at the time of giving
of notice provided for in this Bylaw and who is entitled to vote
at the meeting and complies with the notice procedures set forth
in this Section 3.14.
(ii) For nominations or other business to be properly brought before an
Annual Meeting by a shareowner pursuant to clause (C) of
paragraph (a)(i) of this Section 3.14, the shareowner must have
given timely notice thereof in writing to the Secretary of the
Corporation. To be timely, a shareowner's notice shall be
received by the Secretary of the Corporation at the principal
offices of the Corporation not later than the earlier of (A) 45
days in advance of the first annual anniversary (the "Anniversary
Date") of the date set forth in the Corporation's proxy statement
for the prior year's Annual Meeting as the date on which the
Corporation first mailed definitive proxy materials for the prior
year's Annual Meeting and (B) the later of (x) the 70th day prior
to such Annual Meeting and (y) the 10th day following the day on
which public announcement of the date of such meeting is first
made. Such shareowner's notice shall be signed by the shareowner
of record who intends to make the nomination or introduce the
other business (or his duly authorized proxy or other
representative), shall bear the date of signature of such
shareowner (or proxy or other representative) and shall set
forth: (A) the name and address, as they appear on this
Corporation's books, of such shareowner and the beneficial owner
or owners, if any, on whose behalf the nomination or proposal is
made; (B) the class and number of shares of the Corporation which
are beneficially owned by such shareowner or beneficial owner or
owners; (C) a representation that such shareowner is a holder of
record of shares of the Corporation entitled to vote at such
meeting and intends to appear in person or by proxy at the
meeting to make the nomination or introduce the other business
specified in the notice; (D) in the case of any proposed
nomination for election or re-election as a director, (I) the
name and residence address of the person or persons to be
nominated, (II) a description of all arrangements or
understandings between such shareowner or beneficial owner or
owners and each nominee and any other person or persons (naming
such person or persons) pursuant to which the nomination is to be
made by such shareowner, (III) such other information regarding
each nominee proposed by such shareowner as would be required to
be disclosed in solicitations of proxies for elections of
directors, or would be otherwise required to be disclosed, in
each case pursuant to Regulation 14A under the Exchange Act,
including any information that would be required to be included
in a proxy statement filed pursuant to Regulation 14A had the
nominee been nominated by the Board of Directors and (IV) the
written consent of each nominee to be named in a proxy statement
and to serve as a director of the Corporation if so elected; and
(E) in the case of any other business that such shareowner
proposes to bring before the meeting, (I) a brief description of
the business desired to be brought before the meeting and, if
such business includes a proposal to amend these Bylaws, the
language of the proposed amendment, (II) such shareowner's and
beneficial owner's or owners' reasons for conducting such
business at the meeting and (III) any material interest in such
business of such shareowner and beneficial owner or owners.
(iii) Notwithstanding anything in the second sentence of paragraph (a)(ii) of
this Section 3.14 to the contrary, in the event that the number
of directors to be elected to the Board of Directors of the
Corporation is increased and there is no public announcement
naming all of the nominees for director or specifying the size of
the increased Board of Directors made by the Corporation at least
45 days prior to the Anniversary Date, a shareowner's notice
required by this Section 3.14 shall also be considered timely,
but only with respect to nominees for any new positions created
by such increase, if it shall be received by the Secretary at the
principal offices of the Corporation not later than the close of
business on the 10th day following the day on which such public
announcement is first made by the Corporation.
(b) Special Meetings. Only such business shall be conducted at a Special
Meeting as shall have been described in the notice of meeting sent to
shareowners pursuant to Section 3.4 of these Bylaws. Nominations of persons
for election to the Board of Directors may be made at a Special Meeting at
which directors are to be elected pursuant to such notice of meeting (i) by
or at the direction of the Board of Directors or (ii) by any shareowner of
the Corporation who (A) is a shareowner of record at the time of giving of
such notice of meeting, (B) is entitled to vote at the meeting and (C)
complies with the notice procedures set forth in this Section 3.14. Any
shareowner desiring to nominate persons for election to the Board of
Directors at such a Special Meeting shall cause a written notice to be
received by the Secretary of the Corporation at the principal offices of the
Corporation not earlier than ninety days prior to such Special Meeting and
not later than the close of business on the later of (x) the 60th day prior
to such Special Meeting and (y) the 10th day following the day on which
public announcement is first made of the date of such Special Meeting and of
the nominees proposed by the Board of Directors to be elected at such
meeting. Such written notice shall be signed by the shareowner of record who
intends to make the nomination (or his duly authorized proxy or other
representative), shall bear the date of signature of such shareowner (or
proxy or other representative) and shall set forth: (A) the name and address,
as they appear on the Corporation's books, of such shareowner and the
beneficial owner or owners, if any, on whose behalf the nomination is made;
(B) the class and number of shares of the Corporation which are beneficially
owned by such shareowner or beneficial owner or owners; (C) a representation
that such shareowner is a holder of record of shares of the Corporation
entitled to vote at such meeting and intends to appear in person or by proxy
at the meeting to make the nomination specified in the notice; (D) the name
and residence address of the person or persons to be nominated; (E) a
description of all arrangements or understandings between such shareowner or
beneficial owner or owners and each nominee and any other person or persons
(naming such person or persons) pursuant to which the nomination is to be
made by such shareowner; (F) such other information regarding each nominee
proposed by such shareowner as would be required to be disclosed in
solicitations of proxies for elections of directors, or would be otherwise
required to be disclosed, in each case pursuant to Regulation 14A under the
Exchange Act, including any information that would be required to be included
in a proxy statement filed pursuant to Regulation 14A had the nominee been
nominated by the Board of Directors; and (G) the written consent of each
nominee to be named in a proxy statement and to serve as a director of the
Corporation if so elected.
(c) General.
(i) Only persons who are nominated in accordance with the procedures set
forth in this Section 3.14 shall be eligible to serve as
directors. Only such business shall be conducted at an Annual
Meeting or Special Meeting as shall have been brought before such
meeting in accordance with the procedures set forth in this
Section 3.14. The chairman of the meeting shall have the power
and duty to determine whether a nomination or any business
proposed to be brought before the meeting was made in accordance
with the procedures set forth in this Section 3.14 and, if any
proposed nomination or business is not in compliance with this
Section 3.14, to declare that such defective proposal shall be
disregarded.
(ii) For purposes of this Section 3.14, "public announcement" shall mean
disclosure in a press release reported by the Dow Jones News
Service, Associated Press or comparable national news service or
in a document publicly filed by the Corporation with the
Securities and Exchange Commission pursuant to Section 13, 14 or
15(d) of the Exchange Act.
(iii) Notwithstanding the foregoing provisions of this Section 3.14, a
shareowner shall also comply with all applicable requirements of
the Exchange Act and the rules and regulations thereunder with
respect to the matters set forth in this Section 3.14. Nothing
in this Section 3.14 shall be deemed to limit the Corporation's
obligation to include shareowner proposals in its proxy statement
if such inclusion is required by Rule 14a-8 under the Exchange
Act.
ARTICLE IV
BOARD OF DIRECTORS
Section 4.1 GENERAL POWER. - The business and affairs of the Corporation
shall be managed by its Board of Directors.
Section 4.2 NUMBER. CLASSES & TERM. - The number of Directors of the
Corporation shall be fixed from time to time exclusively by the Board of
Directors pursuant to a resolution adopted by the affirmative vote of a
majority of the total number of Directors that the Corporation would have if
there were no vacancies, but shall not be less than nine (9) nor more than
thirteen (13). The Directors of the Corporation shall be divided, with
respect to the time for which they severally hold office, into three classes,
as nearly equal in number as possible. At each Annual Meeting, the
successors to the class of Directors whose terms shall expire at the time of
such Annual Meeting shall be elected to hold office until the third
succeeding Annual Meeting, and until their successors are duly elected and
qualified.
Section 4.3 CHAIRPERSON OF THE BOARD. - The Chairperson of the Board if not
designated as the Chief Executive Officer of the Company shall assist the
Board in the formulation of policies and may make recommendations therefore.
Information as to the affairs of the Company in addition to that contained in
the regular reports shall be furnished to him or her on request. He or she
may make suggestions and recommendations to the Chief Executive Officer
regarding any matters relating to the affairs of the Company and shall be
available for consultation and advice.
Section 4.4 VICE CHAIRPERSON OF THE BOARD. - The Vice Chairperson of the
Board shall assist the Board in the formulation of policies and make
recommendations therefore. The Vice Chairperson shall have such other powers
and duties as may be prescribed for him or her by the Chairperson of the
Board or the Board of Directors. In the absence of or the inability of the
Chairperson of the Board to act as Chairperson of the Board, the Vice
Chairperson of the Board shall assume the powers and duties of the
Chairperson of the Board.
Section 4.5 QUALIFICATIONS AND REMOVAL. - No person who has attained 70 years
of age shall be eligible for election or re-election to the Board of
Directors. Any Director who has attained seventy (70) years of age shall
resign from the Board of Directors effective as of the next Annual Meeting.
For a period of five (5) years following April 21, 1998, no person, except
any of the initial Directors serving as such on April 21, 1998, who is an
executive officer or employee of the Corporation or any of its subsidiaries
shall be eligible to serve as a Director of the Corporation; provided,
however, that any individual serving as Chief Executive Officer of the
Corporation shall be eligible to serve as a Director of the Corporation. In
the event the Chief Executive Officer resigns or retires from his or her
office or employment with the Corporation, he or she shall simultaneously
submit his or her resignation from the Board of Directors. In the event that
the Chief Executive Officer is removed from his or her office by the Board of
Directors, or is involuntarily terminated from employment with the
Corporation, he or she shall simultaneously submit his or her resignation
from the Board of Directors. In the event that a Director experiences a
change in their principal occupation or primary business affiliation, the
Director must submit their resignation from the Board to the Nominating and
Governance Committee. The Nominating and Governance Committee shall
recommend to the Board of Directors whether the Board should accept such
resignation. If the Nominating and Governance Committee recommends
acceptance of the resignation, an affirmative vote of two-thirds of the
remaining Directors holding office is required to affirm the Nominating and
Governance Committee's recommendation. A resignation may be tendered by any
Director at any meeting of the shareholders or of the Board of Directors, who
shall at such meeting accept the same.
Section 4.6 REGULAR MEETINGS. - Regular meetings of the Board of Directors
shall be held at such time and place as may be determined by the Board of
Directors, but in no event shall the Board meet less than once a year.
Section 4.7 SPECIAL MEETINGS. - Special meetings of the Board of Directors
may be called by or at the request of the Chairman of the Board, the Vice
Chairman of the Board, the Chief Executive Officer or any two (2) Directors.
The Chief Executive Officer or Secretary may fix any place, either within or
without the State of Wisconsin, whether in person or by telecommunications,
as the place for holding any special meeting.
Section 4.8 NOTICE; WAIVER. - Notice of any meeting of the Board of
Directors, unless otherwise provided pursuant to Section 4.6, shall be given
at least forty-eight (48) hours prior to the meeting by written notice
delivered personally or mailed to each Director at such address designed by
each Director, by telegram or other form of wire or wireless communication.
The notice need not describe the purpose of the meeting of the Board of
Directors or the business to be transacted at such meeting. If mailed, such
notice shall be deemed to be delivered when deposited in the United States
mail, so addressed, with postage prepared. Any Director may waive notice of
any meeting. The attendance of a Director at a meeting shall constitute a
waiver of notice of such meeting, except where a Director attends a meeting
for the express purpose of objecting to the transaction of business because
the meeting is not lawfully called or convened.
Section 4.9 QUORUM. - A majority of the Board of Directors shall constitute a
quorum for the transaction of business at any meeting of the Board of
Directors, but if less than such majority is present at a meeting, a majority
of the Directors present may adjourn the meeting to some other day without
further notice.
Section 4.10 MEETING PARTICIPATION.
(a) Any or all members of the Board of Directors, or any committee thereof,
may participate in a regular or special meeting by, or to conduct the meeting
through, the use of any means of communication by which any of the following
occurs:
(i) All participating directors may simultaneously hear each other during
the meeting.
(ii) All communication during the meeting is immediately transmitted to each
participating director, and each participating director is able
to immediately send messages to all other participating directors.
(b) If a meeting is conducted by the means of communication described
herein, all participating directors shall be informed that a meeting is
taking place at which official business may be transacted.
(c) A director participating in a meeting by means of such communication is
deemed to be present in person at the meeting.
Section 4.11 ACTION WITHOUT MEETING. - Any action required or permitted
to be taken at any meeting of the Directors of the Corporation or of any
committee of the Board may be taken without a meeting if a consent in writing
setting forth the action so taken shall be signed by all of the Directors or
all of the members of the Committee of Directors, as the case may be. Such
consent shall have the same force and effect as a unanimous vote at a meeting
and shall be filed with the Secretary of the Corporation to be included in
the official records of the Corporation. The action taken is effective when
the last Director signs the consent unless the consent specifies a different
effective date.
Section 4.12 PRESUMPTION OF ASSENT. - A Director of the Corporation who
is present at a meeting of the Board of Directors at which action on any
corporate matter is taken shall be presumed to have assented to the action
taken unless (a) the Director objects at the beginning of the meeting or
promptly upon arrival to the holding of or transacting business at the
meeting, (b) the Director's dissent or abstention shall be entered in the
minutes of the meeting, (c) the Director shall file a written dissent or
abstention to such action with the presiding officer of the meeting before
the adjournment thereof or shall forward such dissent or abstention by
registered or certified mail to the Secretary of the Corporation immediately
after the adjournment of the meeting, or (d) the Director shall file a
written notice to the Secretary of the Corporation promptly after receiving
the minutes of the meeting that the minutes failed to show the Director's
dissention or abstention from the action taken. Such right to dissent or
abstain shall not apply to a Director who voted in favor of such action.
Section 4.13 VACANCIES. - Except as provided below, any vacancy
occurring in the Board of Directors or on any Committee of the Board of
Directors and any directorship to be filled by reason of an increase in the
number of Directors may be filled by the affirmative vote of a majority of
the Directors then in office, even if less than a quorum of the Board of
Directors. For a period of time commencing on formation of Interstate Energy
Corporation and expiring on the date of the third annual meeting of
shareowners of the Corporation, the initially appointed IES, IPC and WPLH
directors, each as a separate group, shall be entitled to nominate those
persons who will be eligible to be appointed, elected or re-elected as IES,
IPC and WPLH Directors. The Director or Directors so chosen shall hold
office until the next election of the Class for which such Director or
Directors shall have been chosen and until their successors shall have been
duly elected and qualified.
Section 4.14 COMPENSATION. - Compensation and expenses for attendance at
a regular or special meeting of the Board of Directors, or at any committee
meeting, shall be payable in such amounts as determined from time to time by
the Board of Directors. No such payment shall preclude any Director from
serving the Corporation in any other capacity and receiving compensation
therefor. Directors who are full time employees or officers of the
Corporation shall not receive any compensation.
ARTICLE V
COMMITTEES
Section 5.1 COMMITTEES. - The Board of Directors may, by resolution passed by
a majority of the whole Board, designate from their number various Committees
from time to time as corporate needs may dictate. The Committees may make
their own rules of procedure and shall meet where and as provided by such
rules, or by resolution of the Board of Directors. A majority of the members
of the Committee shall constitute a quorum for the transaction of business.
Each Committee shall keep regular minutes of its meetings and report the same
to the Board of Directors when required. The Committee may be authorized by
the Board of Directors to perform specified functions, except that a
committee may not do any of the following: (a) authorize distributions; (b)
approve or propose to shareowners action that the Wisconsin Business
Corporation Law requires to be approved by shareowners; (c) fill vacancies on
the Board of Directors, or, unless the Board of Directors provides by
resolution that vacancies on a committee shall be filled by the affirmative
vote of the remaining committee members, on any Board committee; (d) amend
the Corporation's Articles of Incorporation; (e) adopt, amend or repeal
bylaws; (f) approve a plan of merger not requiring shareowner approval; (g)
authorize or approve reacquisition of shares, except according to a formula
or method prescribed by the Board of Directors; and (h) authorize or approve
the issuance or sale or contract for sale of shares or determine the
designation and relative rights, preferences and limitations of a class or
series of shares, except that the Board of Directors may authorize a
committee to do so within limits prescribed by the Board of Directors.
Section 5.2 EXECUTIVE COMMITTEE. - An Executive Committee is hereby
established and shall consist of at least three (3) members, including the
Chairman of the Board. The Executive Committee shall possess all the powers
and authority of the Board of Directors when said Board of Directors is not
in session, except for the powers and authorities set forth in Section 5.1.
Section 5.3 AUDIT COMMITTEE. - An Audit Committee is hereby established and
shall consist of at least three (3) Directors, all of whom shall be outside
members of the Board of Directors. The members of the Committee shall be
elected annually by a majority vote of the members of the Board of
Directors. Said Committee shall meet at the call of any one of its members,
but in no event shall it meet less than once a year. Subsequent to each such
Committee meeting, a report of the actions taken by such Committee shall be
made to the Board of Directors.
Section 5.4 COMPENSATION AND PERSONNEL COMMITTEE. - A Compensation and
Personnel Committee is hereby established and shall consist of at least three
(3) Directors who are not and never have been officers, employees or legal
counsel of the Company. The Chairperson and the members of the Compensation
and Personnel Committee shall be elected annually by a majority vote of the
members of the Board of Directors. Said Committee shall meet at such times
as it determines, but at least twice each year, and shall meet at the request
of the Chairman of the Board, the Chief Executive Officer, or any Committee
member. Subsequent to each such Committee meeting, a report of the actions
taken by such Committee shall be made to the Board of Directors.
Section 5.5 NOMINATING AND GOVERNANCE COMMITTEE. - A Nominating and
Governance Committee shall be established and shall consist of at least three
(3) Directors, all of whom shall be outside members of the Board of
Directors. The Chairperson and the members of the Nominating and Governance
Committee shall be elected annually by a majority vote of the members of the
Board of Directors. Said Committee shall meet at the call of any one of its
members, but in no event shall it meet less than once a year. Subsequent to
each such Committee meeting, a report of the actions taken by such Committee
shall be made to the Board of Directors.
ARTICLE VI
OFFICERS
Section 6.1 OFFICERS. - The Board of Directors shall elect a Chief Executive
Officer, a President, such number of Vice Presidents with such designations
as the Board of Directors at the time may decide upon, a Secretary, a
Treasurer and a Controller. The Chief Executive Officer may appoint such
other officers and assistant officers as may be deemed necessary. The same
person may simultaneously hold more than one such office.
Section 6.2 TERM OF OFFICERS. - All Officers, unless sooner removed, shall
hold their respective offices until their successors, willing to serve, shall
have been elected but any Officer may be removed from Office at any time by
the Board of Directors.
Section 6.3 REMOVAL OF OFFICERS. - Any officer may be removed by the Board of
Directors whenever in its judgment the best interests of the Corporation will
be served thereby, but such removal shall be without prejudice to the
contract rights, if any, of the person so removed. Election or appointment
of an officer shall not of itself create contract rights.
Section 6.4 CHIEF EXECUTIVE OFFICER. - Subject to the control of the Board of
Directors the Chief Executive Officer designated by the Board of Directors
shall have and be responsible for the general management and direction of the
business of the Corporation, shall establish the lines of authority and
supervision of the Officers and employees of the Corporation, shall have the
power to appoint and remove and discharge any and all agents and employees of
the Corporation not elected or appointed directly by the Board of Directors.
and shall assist the Board in the formulation of policies of the
Corporation. The Chairperson of the Board, if Chief Executive Officer, may
delegate any part of his or her duties to the President, or to one or more of
the Vice Presidents of the Corporation.
Section 6.5 PRESIDENT. - The President, when he or she is not designated as
and does not have the powers of the Chief Executive Officer, shall have such
other powers and duties as may from time to time be prescribed by the Board
of Directors or be delegated to him or her by the Chairperson of the Board or
the Chief Executive Officer.
Section 6.6 VICE PRESIDENTS. - The Vice Presidents shall have such powers and
duties as may be prescribed for him or her by the Board of Directors and the
Chief Executive Officer. In the absence of or in the event of the death of
the Chief Executive Officer and the President, the inability or refusal to
act, or in the event for any reason it shall be impracticable for Chief
Executive Officer and the President to act personally, the Vice President (or
in the event there be more than one Vice President, the Vice Presidents in
the order designated by the Board of Directors, or in the absence of any
designation, then in the order of their election) shall perform the duties of
the Chief Executive Officer and the President, and when so acting, shall have
all the powers of and be subject to all the restrictions upon the Chief
Executive Officer and the President. The execution of any instrument of the
Corporation by any Vice President shall be conclusive evidence, as to third
parties, of his or her authority to act in the stead of the Chief Executive
Officer and the President.
Section 6.7 SECRETARY. - The Secretary shall attend all meetings of the Board
of Directors, shall keep a true and faithful record thereof in proper books
to be provided for that purpose, and shall be responsible for the custody and
care of the corporate seal, corporate records and minute books of the
Corporation, and of all other books, documents and papers as in the practical
business operation of the Corporation shall naturally belong in the office or
custody of the Secretary, or shall be placed in his or her custody by the
Chief Executive Officer or by the Board of Directors. He or she shall also
act as Secretary of all shareowners' meetings, and keep a record thereof. He
or she shall, except as may be otherwise required by statute or by these
bylaws, sign, issue and publish all notices required for meetings of
shareowners and of the Board of Directors. He or she shall be responsible
for the custody of the stock books of the Corporation and shall keep a
suitable record of the addresses of shareowners. He or she shall also be
responsible for the collection, custody and disbursement of the funds
received for dividend reinvestment. He or she shall sign stock certificates,
bonds and mortgages, and all other documents and papers to which his or her
signature may be necessary or appropriate, shall affix the seal of the
Corporation to all instruments requiring the seal, and shall have such other
powers and duties as are commonly incidental to the office of Secretary, or
as may be prescribed for him or her by the President or by the Board of
Directors.
Section 6.8 TREASURER. - The Treasurer shall have charge of, and be
responsible for, the collection, receipt, custody and disbursement of the
funds of the Corporation, and shall deposit its funds in the name of the
Corporation in such banks or trust companies as he or she shall designate and
shall keep a proper record of cash receipts and disbursements. He or she
shall be responsible for the custody of such books, receipted vouchers and
other books and papers as in the practical business operation of the
Corporation shall naturally belong in the office or custody of the Treasurer,
or shall be placed in his or her custody by the President, or by the Board of
Directors. He or she shall sign checks, drafts, and other paper providing
for the payment of money by the Corporation for operating purposes in the
usual course or business. He or she may, in the absence of the Secretary and
Assistant Secretaries sign stock certificates. The Treasurer shall have such
other powers and duties as are commonly incidental to the office of
Treasurer, or as may be prescribed for him or her by the President or by the
Board of Directors.
Section 6.9 CONTROLLER. - The Controller shall be the principal accounting
Officer of the Corporation. He or she shall have general supervision over
the books of accounts of the Corporation. He or she shall examine the
accounts of all Officers and employees from time to time and as often as
practicable, and shall see that proper returns are made of all receipts from
all sources. All bills, properly made in detail and certified, shall be
submitted to him or her, and he or she shall audit and approve the same if
found satisfactory and correct, but he or she shall not approve any voucher
unless charges covered by the voucher have been previously approved through
work orders, requisition or otherwise by the head of the department in which
it originated, or unless he or she shall be otherwise satisfied of its
propriety and correctness. He or she shall have full access to all minutes,
contracts, correspondence and other papers and records of the Corporation
relating to its business matters, and shall be responsible for the custody of
such books and documents as shall naturally belong in the custody of the
Controller and as shall be placed in his or her custody by the President or
by the Board of Directors. The Controller shall have such other powers and
duties as are commonly incidental to the office of Controller, or as may be
prescribed for him or her by the President or by the Board of Directors.
Section 6.10 ASSISTANT OFFICERS. - The Assistant Secretaries, Assistant
Treasurers, Assistant Controllers, and other Assistant Officers shall
respectively assist the Secretary, Treasurer, Controller, and other Officers
of the Corporation in the performance of the respective duties assigned to
such principal Officer, and in assisting his or her principal Officer each
assistant Officer shall to that extent and for such purpose have the same
powers as his or her principal Officer. The powers and duties of any such
principal Officer shall temporarily devolve upon an assistant Officer in case
of the absence, disability, death, resignation or removal from office of such
principal Officer.
ARTICLE VII
CERTIFICATES FOR SHARES AND THEIR TRANSFER
Section 7.1 CERTIFICATES FOR SHARES. - Each certificate representing shares
of the Corporation shall state upon the fact (a) that the Corporation is
organized under the laws of the State of Wisconsin, (b) the name of the
person to whom issued, (c) the number and class of shares, and the
designation of the series, if any, which such certificate represents, and (d)
the par value of each share, if any, and each such certificate shall
otherwise be in such form as shall be determined by the Board of Directors.
Such certificates shall be signed by the Chairman of the Board, or the Chief
Executive Officer or the President and by the Secretary or an Assistant
Secretary and shall be sealed with the corporate seal or a facsimile
thereof. The signatures of such officers upon a certificate may be
facsimiles if the certificate is manually signed on behalf of a transfer
agent and registrar. In case any officer or other authorized person who has
signed or whose facsimile signature has been placed upon such certificate for
the Corporation shall have ceased to be such officer or employee or agent
before such certificate is issued, it may be issued by the Corporation with
the same effect as if such person where an officer or employee or agent at
the date of its issue. Each certificate for shares shall be consecutively
numbered or otherwise identified.
All certificates surrendered to the Corporation for transfer
shall be canceled and no new certificate shall be issued until the former
certificate for a like number of shares shall have been surrendered and
canceled, except that in case of a lost, destroyed or mutilated certificate a
new one may be issued therefor upon such terms and indemnity to the
Corporation as the Board of Directors may prescribe.
Section 7.2 TRANSFER OF SHARES. - Transfer of shares of the Corporation shall
be made only on the stock transfer books of the Corporation by the holder of
record thereof or by such person's legal representative, who shall furnish
proper evidence of authority to transfer, or authorized attorney, by power of
attorney duly executed and filed with the Secretary of the Corporation, and
on surrender for cancellation of the certificate for such shares.
Subject to the provisions of Section 3.12 of Article III of these
Bylaws, the person in whose name shares stand on the books of the Corporation
shall be treated by the Corporation as the owner thereof for all purposes,
including all rights deriving from such shares, and the Corporation shall not
be bound to recognize any equitable or other claim to, or interest in, such
shares or rights deriving from such shares, on the part of any other person,
including (without limitation) a purchaser, assignee or transferee of such
shares, or rights deriving from such shares, unless and until such purchaser,
assignee, transferee or other person becomes the record holder of such
shares, whether or not the Corporation shall have either actual or
constructive notice of the interest of such purchaser, assignee, transferee
or other person. Except as provided in said Section 3.12 hereof, no such
purchaser, assignee, transferee or other person shall be entitled to receive
notice of the meetings of shareholders, to vote at such meetings, to examine
the complete record of the shareholders entitled to vote at meetings, or to
own, enjoy or exercise any other property or rights deriving from such shares
against the Corporation, until such purchaser, assignee, transferee or other
person has become the record holder of such shares.
Section 7.3 LOST, DESTROYED OR STOLEN CERTIFICATES. - When the owner claims
that certificates for shares have been lost, destroyed or wrongfully taken, a
new certificate shall be issued in place thereof if the owner (a) so requests
before the Corporation has notice that such shares have been acquired by a
bona fide purchaser, (b) files with the Corporation a sufficient indemnity
bond if required by the Corporation and (c) satisfies such other reasonable
requirements as may be provided by the Corporation.
Section 7.4 STOCK REGULATIONS. - The Board of Directors shall have the power
and authority to make all such further rules and regulations not inconsistent
with law as it may deem expedient concerning the issue, transfer and
registration of shares of the Corporation.
ARTICLE VIII
INDEMNIFICATION AND LIABILITY OF DIRECTOR AND OFFICERS
Section 8.1 INDEMNIFICATION. - The Corporation shall, to the fullest extent
permitted or required by Sections 180.0850 to 180.0859, inclusive, of the
Wisconsin Business Corporation Law, including any amendments thereto (but in
the case of any such amendment, only to the extent such amendment permits or
requires the corporation to provide broader indemnification rights than prior
to such amendment), indemnify its Directors, Officers, employees and agents
against any and all Liabilities, and advance any and all reasonable Expenses,
incurred thereby in any Proceeding to which any such Director, Officer,
employee or agent is a Party because he or she is or was a Director, Officer,
employee or agent of the Corporation. The rights to indemnification granted
hereunder shall not be deemed exclusive of any other rights to
indemnification against Liabilities or the advancement of Expenses which a
Director, Officer, employee or agent may be entitled under any written
agreement, Board resolution, vote of shareowners, the Wisconsin Business
Corporation Law or otherwise. The Corporation may, but shall not be required
to, supplement the foregoing rights to indemnification against Liabilities
and advancement of Expenses under this Section 8.1 by the purchase of
insurance on behalf of any one or more of such Directors, Officers, employees
or agents, whether or not the Corporation would be obligated to indemnify or
advance Expenses to such Director, Officer, employee or agent under this
Section 8.1. All capitalized terms used in this Article VIII and not
otherwise defined herein shall have the meaning set forth in Section 180.0850
of the Wisconsin Business Corporation Law.
ARTICLE IX
MISCELLANEOUS
Section 9.1 FISCAL YEAR. - The fiscal year of the Corporation shall be the
calendar year.
Section 9.2 DIVIDENDS. - Subject to the provisions of law or the Articles of
Incorporation, the Board of Directors may, at any regular or special meeting,
declare dividends upon the capital stock of the Corporation payable out of
surplus (whether earned or paid-in) or profits as and when they deem
expedient. Before declaring any dividend there may be set apart out of
surplus or profits such sum or sums as the directors from time to time in
their discretion deem proper for working capital or as a reserve fund to meet
contingencies or for such other purposes as the directors shall deem
conducive to the interests of the Corporation.
Section 9.3 CONTRACTS, CHECKS, DRAFTS, DEEDS, LEASES AND OTHER INSTRUMENTS. -
All contracts, checks, drafts or other orders for the payment of money, notes
or other evidences of indebtedness issued in the name of the Corporation,
shall be signed by such officer or officers, agent or agents of the
Corporation and in such manner as shall from time to time be determined by
resolution of the Board of Directors. The Board may authorize by resolution
any officer or officers to enter into and execute any contract or instrument
of indebtedness in the name of the Corporation, and such authority may be
general or confined to specific instances. All funds of the Corporation not
otherwise employed shall be deposited from time to time to the credit of the
Corporation in such banks or other depositories as the Treasurer may
authorize.
All contracts, deeds, mortgages, leases or instruments that
require the corporate seal of the Corporation to be affixed thereto shall be
signed by the President or a Vice President, and by the Secretary, or an
Assistant Secretary, or by such other officer or officers, or person or
persons, as the Board of Directors may be resolution prescribe.
Section 9.4 VOTING OF SHARES OWNED BY THE CORPORATION. - Subject always to
the specific directions of the Board of Directors, any share or shares of
stock issued by any other corporation and owned or controlled by the
Corporation may be voted at any shareholders' meeting of such other
corporation by the Chief Executive Officer of the Corporation, if present, or
if absent by any other officer of the Corporation who may be present.
Whenever, in the judgment of the Chief Executive Officer, or if absent, of
any officer, it is desirable for the Corporation to execute a proxy or give a
shareholders' consent in respect to any share or shares of stock issued by
any other corporation and owned by the Corporation, such proxy or consent
shall be executed in the name of the Corporation by the Chief Executive
Officer or one of the officers of the Corporation and shall be attested by
the Secretary or an Assistant Secretary of the Corporation without necessity
of any authorization by the Board of Directors. Any person or persons
designated in the manner above stated as the proxy or proxies of the
Corporation shall have full right, power and authority to vote the share or
shares of stock issued by such other corporation and owned by the Corporation
in the same manner as such share or shares might be voted by the Corporation.
ARTICLE X
AMENDMENT OR REPEAL OF BYLAWS
Section 10.1 AMENDMENTS BY BOARD OF DIRECTORS. - Except as otherwise
provided by the Wisconsin Business Corporation Law or the Articles of
Incorporation, these Bylaws may be amended or repealed and new Bylaws may be
adopted by the Board of Directors by the affirmative vote of a majority of
the number of directors present at any meeting at which a quorum is in
attendance; provided, however, that the shareowners in adopting, amending or
repealing a particular bylaw may provide therein that the Board of Directors
may not amend, repeal or readopt that bylaw.
Section 10.2 IMPLIED AMENDMENT. - Any action taken or authorized by the
shareowners or by the Board of Directors which would be inconsistent with the
Bylaws then in effect but which is taken or authorized by affirmative vote of
not less than the number of shares or the number of directors required to
amend the Bylaws so that the Bylaws would be consistent with such action
shall be given the same effect as though the Bylaws had been temporarily
amended or suspended so far, but only so far, as is necessary to permit the
specific action so taken or authorized.
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I,_______________________, do hereby certify that I am the duly elected and
acting _______________ Corporate Secretary of Alliant Energy Corporation, a
Wisconsin corporation, organized under the laws of the State, and that I have
access to the corporate records of said Company, and as such officer, I do
further certify that the foregoing Bylaws were adopted as of March 15, 2000.
IN WITNESS WHEREOF, I have hereunto set my hand and affixed the
corporate seal of said Company this ____________ day of ___________________,
_______.
___________________________________