-----BEGIN PRIVACY-ENHANCED MESSAGE----- Proc-Type: 2001,MIC-CLEAR Originator-Name: webmaster@www.sec.gov Originator-Key-Asymmetric: MFgwCgYEVQgBAQICAf8DSgAwRwJAW2sNKK9AVtBzYZmr6aGjlWyK3XmZv3dTINen TWSM7vrzLADbmYQaionwg5sDW3P6oaM5D3tdezXMm7z1T+B+twIDAQAB MIC-Info: RSA-MD5,RSA, DvaNR1OqfqTnF7Fd4USrmujAP77v87E9dzzfrKaHpcfBAseOLISvgK5FcPzrZGk5 gqOm5iBplU0/CIU8cPMPiQ== 0001002910-04-000300.txt : 20041110 0001002910-04-000300.hdr.sgml : 20041110 20041109171543 ACCESSION NUMBER: 0001002910-04-000300 CONFORMED SUBMISSION TYPE: 10-Q PUBLIC DOCUMENT COUNT: 30 CONFORMED PERIOD OF REPORT: 20040930 FILED AS OF DATE: 20041109 DATE AS OF CHANGE: 20041109 FILER: COMPANY DATA: COMPANY CONFORMED NAME: AMEREN CORP CENTRAL INDEX KEY: 0001002910 STANDARD INDUSTRIAL CLASSIFICATION: ELECTRIC & OTHER SERVICES COMBINED [4931] IRS NUMBER: 431723446 STATE OF INCORPORATION: MO FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 001-14756 FILM NUMBER: 041130600 BUSINESS ADDRESS: STREET 1: 1901 CHOUTEAU AVE STREET 2: MC 1370 CITY: ST LOUIS STATE: MO ZIP: 63166-6149 BUSINESS PHONE: 314-621-3222 MAIL ADDRESS: STREET 1: 1901 CHOUTEAU AVE STREET 2: MC 1370 CITY: ST LOUIS STATE: MO ZIP: 63103 FILER: COMPANY DATA: COMPANY CONFORMED NAME: CENTRAL ILLINOIS LIGHT CO CENTRAL INDEX KEY: 0000018651 STANDARD INDUSTRIAL CLASSIFICATION: ELECTRIC & OTHER SERVICES COMBINED [4931] IRS NUMBER: 370211050 STATE OF INCORPORATION: IL FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 001-02732 FILM NUMBER: 041130604 BUSINESS ADDRESS: STREET 1: 300 LIBERTY ST CITY: PEORIA STATE: IL ZIP: 61602 BUSINESS PHONE: 309-677-5230 MAIL ADDRESS: STREET 1: 300 LIBERTY STREET CITY: PEORIA STATE: IL ZIP: 61602 FILER: COMPANY DATA: COMPANY CONFORMED NAME: CENTRAL ILLINOIS PUBLIC SERVICE CO CENTRAL INDEX KEY: 0000018654 STANDARD INDUSTRIAL CLASSIFICATION: ELECTRIC & OTHER SERVICES COMBINED [4931] IRS NUMBER: 370211380 STATE OF INCORPORATION: IL FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 001-03672 FILM NUMBER: 041130603 BUSINESS ADDRESS: STREET 1: 607 E ADAMS ST CITY: SPRINGFIELD STATE: IL ZIP: 62739 BUSINESS PHONE: 217-523-3600 MAIL ADDRESS: STREET 1: CENTRAL ILLINOIS PUBLIC SERVICE CO STREET 2: 607 E ADAMS ST CITY: SPRINGFIELD STATE: IL ZIP: 62739 FILER: COMPANY DATA: COMPANY CONFORMED NAME: UNION ELECTRIC CO CENTRAL INDEX KEY: 0000100826 STANDARD INDUSTRIAL CLASSIFICATION: ELECTRIC SERVICES [4911] IRS NUMBER: 430559760 STATE OF INCORPORATION: MO FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 001-02967 FILM NUMBER: 041130601 BUSINESS ADDRESS: STREET 1: 1901 CHOUTEAU AVENUE STREET 2: MC 1370 CITY: ST LOUIS STATE: MO ZIP: 63166 BUSINESS PHONE: 314-621-3222 MAIL ADDRESS: STREET 1: 1901 CHOUTEAU AVENUE STREET 2: MC 1370 CITY: ST LOUIS STATE: MO ZIP: 63166 FILER: COMPANY DATA: COMPANY CONFORMED NAME: CILCORP INC CENTRAL INDEX KEY: 0000762129 STANDARD INDUSTRIAL CLASSIFICATION: ELECTRIC & OTHER SERVICES COMBINED [4931] IRS NUMBER: 371169387 STATE OF INCORPORATION: IL FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 002-95569 FILM NUMBER: 041130602 BUSINESS ADDRESS: STREET 1: 300 LIBERTY ST STREET 2: STE 300 CITY: PEORIA STATE: IL ZIP: 61602 BUSINESS PHONE: 309-677-5230 MAIL ADDRESS: STREET 1: 300 LIBERTY STREET CITY: PEORIA STATE: IL ZIP: 61602 FILER: COMPANY DATA: COMPANY CONFORMED NAME: AMERENENERGY GENERATING CO CENTRAL INDEX KEY: 0001135361 STANDARD INDUSTRIAL CLASSIFICATION: ELECTRIC SERVICES [4911] IRS NUMBER: 371395586 STATE OF INCORPORATION: IL FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 333-56594 FILM NUMBER: 041130605 BUSINESS ADDRESS: STREET 1: 1901 CHOUTEAU AVENUE CITY: ST LOUIS STATE: MO ZIP: 63103 BUSINESS PHONE: 314-621-3222 MAIL ADDRESS: STREET 1: 1901 CHOUTEAU AVENUE CITY: ST LOUIS STATE: MO ZIP: 63103 10-Q 1 form10-q.htm AMEREN 10-Q 9-30-2004 Ameren 10-Q 9-30-2004


UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, DC 20549

FORM 10-Q

(X) Quarterly report pursuant to Section 13 or 15(d)
of the Securities Exchange Act of 1934
for the Quarterly Period Ended September 30, 2004

OR
( ) Transition report pursuant to Section 13 or 15(d)
of the Securities Exchange Act of 1934
for the transition period from   to  .

 
Exact Name of Registrant as specified in its charter;
 
Commission
State of Incorporation;
IRS Employer
File Number
Address and Telephone Number 
Identification No.
     
1-14756 
Ameren Corporation
43-1723446
 
(Missouri Corporation)
 
 
1901 Chouteau Avenue
 
 
St. Louis, Missouri 63103
 
 
(314) 621-3222
 
     
1-2967
Union Electric Company
43-0559760
 
(Missouri Corporation)
 
 
1901 Chouteau Avenue
 
 
St. Louis, Missouri 63103
 
 
(314) 621-3222
 
     
1-3672
Central Illinois Public Service Company
37-0211380
 
(Illinois Corporation)
 
 
607 East Adams Street
 
 
Springfield, Illinois 62739
 
 
(217) 523-3600
 
     
333-56594
Ameren Energy Generating Company
37-1395586
 
(Illinois Corporation)
 
 
1901 Chouteau Avenue
 
 
St. Louis, Missouri 63103
 
 
(314) 621-3222
 
     
2-95569
CILCORP Inc.
37-1169387
 
(Illinois Corporation)
 
 
300 Liberty Street
 
 
Peoria, Illinois 61602
 
 
(309) 677-5230
 
     
1-2732
Central Illinois Light Company
37-0211050
 
(Illinois Corporation)
 
 
300 Liberty Street
 
 
Peoria, Illinois 61602
 
 
(309) 677-5230
 


  
1

 

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 whether each Registrant is an accelerated filer (as defined in Rule 12b-2 of the Securities Exchange Act of 1934).

Ameren Corporation
Yes
(X)
No
(   )
Union Electric Company
Yes
(   )
No
(X)
Central Illinois Public Service Company
Yes
(   )
No
(X)
Ameren Energy Generating Company
Yes
(   )
No
(X)
CILCORP Inc.
Yes
(   )
No
(X)
Central Illinois Light Company
Yes
(   )
No
(X)

The number of shares outstanding of each Registrant's classes of common stock as of July 30, 2004, was as follows:

Ameren Corporation
Common stock, $.01 par value - 194,796,533
   
Union Electric Company
Common stock, $5 par value, held by Ameren Corporation (parent company of the Registrant) - 102,123,834
   
Central Illinois Public Service Company
Common stock, no par value, held by Ameren Corporation (parent company of the Registrant) - 25,452,373
   
Ameren Energy Generating Company
Common stock, no par value, held by Ameren Energy Development Company (parent company of the Registrant and indirect subsidiary of Ameren Corporation) - 2,000
   
CILCORP Inc.
Common stock, no par value, held by Ameren Corporation (parent company of the Registrant) - 1,000
   
Central Illinois Light Company
Common stock, no par value, held by CILCORP Inc. (parent company of the Registrant and subsidiary of Ameren Corporation) - 13,563,871

This combined Form 10-Q is separately filed by Ameren Corporation, Union Electric Company, Central Illinois Public Service Company, Ameren Energy Generating Company, CILCORP Inc. and Central Illinois Light Company. Each Registrant hereto is filing on its own behalf all of the information contained in this quarterly report that relates to such Registrant. Each Registrant hereto is not filing any information that does not relate to such Registrant, and therefore makes no representation as to any such information.
 
       On September 30, 2004, Ameren Corporation completed its acquisition of Illinois Power Company (see Note 2 - Acquisitions to our financial statements under Part I, Item 1 of this report for further information). Illinois Power Company is making a separate filing of its Quarterly Report on Form 10-Q for the period ended September 30, 2004 (see Commission File No. 1-3004). The Registrants hereto are making no representation as to any information in that filing. Commencing with its Annual Report on Form 10-K for the fiscal year ending December 31, 2004, Illinois Power Company is expected to be included in the combined filing of Ameren Corporation and its other subsidiaries.
 
OMISSION OF CERTAIN INFORMATION

  Ameren Energy Generating Company and CILCORP Inc. meet the conditions set forth in General Instruction H(1)(a) and (b) of Form 10-Q and are therefore filing this Form 10-Q with the reduced disclosure format allowed under that General Instruction.

 
2

 



TABLE OF CONTENTS


 
Page
Glossary of Terms and Abbreviations
5
   
Forward-looking Statements
9
     
PART I.
Financial Information
 
     
ITEM 1.
Financial Statements (Unaudited)
 
     
 
Ameren Corporation
 
 
Consolidated Statement of Income
10
 
Consolidated Balance Sheet    
11
 
Consolidated Statement of Cash Flows
12
     
 
Union Electric Company
 
 
Consolidated Statement of Income
13
 
Consolidated Balance Sheet    
14
 
Consolidated Statement of Cash Flows
15
     
 
Central Illinois Public Service Company
 
 
Statement of Income
16
 
Balance Sheet    
17
 
Statement of Cash Flows
18
     
 
Ameren Energy Generating Company
 
 
Statement of Income
19
 
Balance Sheet    
20
 
Statement of Cash Flows
21
     
 
CILCORP Inc.
 
 
Consolidated Statement of Income
22
 
Consolidated Balance Sheet    
23
 
Consolidated Statement of Cash Flows
24
     
 
Central Illinois Light Company
 
 
Consolidated Statement of Income
25
 
Consolidated Balance Sheet    
26
 
Consolidated Statement of Cash Flows
27
     
 

 
3

 

 
Combined Notes to Financial Statements
28
     
ITEM 2.
Management's Discussion and Analysis of Financial Condition and Results of Operations
64
     
ITEM 3.
Quantitative and Qualitative Disclosures About Market Risk
91
     
ITEM 4.
Controls and Procedures
96
     
PART II.
Other Information
 
     
ITEM 1.
Legal Proceedings
97
     
ITEM 2.
Unregistered Sales of Equity Securities and Use of Proceeds
97
     
ITEM 6.
Exhibits
98
     
SIGNATURES
99
 

This Form 10-Q contains “forward-looking statements” within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements should be read with the cautionary statements and important factors included in this Form 10-Q under the heading Forward-looking Statements. Forward-looking statements are all statements other than statements of historical fact, including those statements that are identified by the use of the words “anticipates,” “estimates,” “expects,” “intends,” “plans,” “predicts,” “projects” and similar expressions.



 
 
4

 
GLOSSARY OF TERMS AND ABBREVIATIONS

When we use the words our, we or us, with respect to certain information, it indicates that such information relates to all Ameren Companies and IP. When we refer to financing or acquisition activities, we are defining Ameren as the parent holding company. When appropriate, subsidiaries of Ameren are specifically referenced in order to distinguish among their different business activities.

AERG - AmerenEnergy Resources Generating Company, a subsidiary of CILCO, which operates a non rate-regulated electric generation business in Illinois and which was formerly known as Central Illinois Generation, Inc.

AES - The AES Corporation.

AFS - Ameren Energy Fuels and Services Company, a subsidiary of Resources Company, which procures fuel and gas and manages the related risks for the Ameren Companies.

Ameren - Ameren Corporation and its subsidiaries on a consolidated basis. When referring to financing or acquisition activities, or liquidity arrangements, Ameren is defined as Ameren Corporation, the parent.

Ameren Companies - The individual Registrants within the Ameren consolidated group, except for IP, which is filing separately its Quarterly Report on Form 10-Q for the period ended September 30, 2004.

Ameren Energy - Ameren Energy, Inc., a subsidiary of Ameren Corporation, which serves as a power marketing and risk management agent for UE and Genco for transactions of primarily less than one year.

Ameren Services - Ameren Services Company, a subsidiary of Ameren Corporation, which provides a variety of support services to Ameren and its subsidiaries.

AmerGen - AmerGen Energy Company, which is not affiliated with the Ameren Companies.

Capacity factor - A measure that indicates the percent of an electric power generating unit’s(s’) capacity that was used during a period.

CILCO - Central Illinois Light Company, a subsidiary of CILCORP, which operates a rate-regulated electric transmission and distribution business, a primarily non rate-regulated electric generation business, and a rate-regulated natural gas distribution business, all in Illinois, as AmerenCILCO. CILCO owns all of the common stock of AERG.

CILCORP - CILCORP Inc., a subsidiary of Ameren Corporation, which operates as a holding company for CILCO.

CIPS - Central Illinois Public Service Company, a subsidiary of Ameren Corporation, which operates a rate-regulated electric and natural gas transmission and distribution business in Illinois as AmerenCIPS.

Cooling degree days - The summation of positive differences between the mean daily temperature and a 65° Fahrenheit base. This statistic is useful as an indicator of demand for electricity for summer space cooling for residential and commercial customers.

CT - Combustion turbine  electric generation equipment.

Development Company - Ameren Energy Development Company, a subsidiary of Resources Company and parent of Genco, which develops and constructs generating facilities for Genco.

DMG - Dynegy Midwest Generation, Inc., a Dynegy subsidiary.

DOE - Department of Energy, a governmental agency of the United States of America.

DOJ - Department of Justice, a governmental agency of the United States of America.


 
 
5

 
 
DRPlus - Ameren Corporation’s dividend reinvestment and direct stock purchase plan.
 
Dynegy - Dynegy Inc.

EEI - Electric Energy, Inc., an 80%-owned subsidiary of Ameren Corporation, which is 40% owned by UE and 40% owned by Resources Company, and which operates electric generation and transmission facilities in Illinois.

EPA - Environmental Protection Agency, a governmental agency of the United States of America.

Equivalent availability factor - A measure that indicates the percent of time an electric power generating unit(s) was available for service during a period.

ERISA - Employee Retirement Income Security Act of 1974, as amended.

Exchange Act - Securities Exchange Act of 1934, as amended.

FASB - Financial Accounting Standards Board, a rulemaking organization that establishes financial accounting and reporting standards in the United States of America.

FCC - Federal Communications Commission, a governmental agency of the United States of America.

FERC - Federal Energy Regulatory Commission, a governmental agency of the United States of America that, among other things, regulates interstate transmission and wholesale sales of electricity and natural gas and related matters and hydroelectric facilities.

FIN - FASB Interpretation intended to clarify accounting pronouncements previously issued by the FASB.

Fitch - Fitch Ratings, a credit rating agency.

FSP - FASB Staff Position, which provides application guidance on FASB literature.

FTC - Federal Trade Commission, a governmental agency of the United States of America.

GAAP - Generally accepted accounting principles in the United States of America.

Genco - Ameren Energy Generating Company, a subsidiary of Development Company, which operates a non rate-regulated electric generation business in Illinois and Missouri.

GridAmerica Companies - UE, CIPS, American Transmission Systems, Inc., a subsidiary of FirstEnergy Corp., and Northern Indiana Public Service Company, a subsidiary of NiSource, Incorporated.

Hart-Scott-Rodino Act - Hart-Scott-Rodino Antitrust Improvements Act of 1976, which establishes procedures for companies involved in transactions that meet certain criteria to file a premerger notification with the FTC and the DOJ Antitrust Division and establishes prescribed time periods for government review prior to completing their transaction.

Heating degree days - The summation of negative differences between the mean daily temperature and a 65° Fahrenheit base. This statistic is useful as an indicator of demand for electricity and natural gas for winter space heating for residential and commercial customers.

IBEW - International Brotherhood of Electrical Workers.

ICC - Illinois Commerce Commission, a state agency that regulates the Illinois utility businesses and operations of UE, CIPS, CILCO and IP.

Illinois Customer Choice Law - Illinois Electric Service Customer Choice and Rate Relief Law of 1997, which provides for electric utility restructuring and introduces competition into the retail supply of electric energy in Illinois.


 
 
6

 
 
IP - Illinois Power Company, which was acquired by, and became a subsidiary of, Ameren Corporation on September 30, 2004. IP operates a rate-regulated electric and natural gas transmission and distribution business in Illinois as AmerenIP.
 
IP LLC - Illinois Power Securitization Limited Liability Company, which is a special purpose Delaware limited liability company. Under FIN No. 46R guidance, IP LLC was no longer consolidated within IP’s financial statements as of December 31, 2003.

IP SPT - Illinois Power Special Purpose Trust, which was created as a subsidiary of IP LLC to issue TFNs as allowed under Illinois’ deregulation legislation. Pursuant to FIN No. 46R, IP SPT is a variable interest entity, as the equity investment is not sufficient to permit IP SPT to finance its activities without additional subordinated debt. As of December 31, 2003, under FIN No. 46R guidance, IP SPT was no longer consolidated within IP’s financial statements.

IUOE - International Union of Operating Engineers.

Marketing Company - Ameren Energy Marketing Company, a subsidiary of Resources Company, which markets power for periods primarily over one year.

Medina Valley - AmerenEnergy Medina Valley Cogen (No. 4), LLC and its subsidiaries, which are subsidiaries of Resources Company, which indirectly own a 40 megawatt, gas-fired electric generation plant.

MGP - Manufactured gas plant.

Midwest ISO - Midwest Independent Transmission System Operator Inc.

Missouri Environmental Authority - State Environmental Improvement and Energy Resources Authority of the State of Missouri, a governmental instrumentality that is authorized to finance environmental projects through the issuance of tax exempt bonds and notes.

Money pool - Borrowing arrangements with and among the Ameren Companies and IP to coordinate and provide for certain short-term cash and working capital requirements. Separate money pools are maintained between rate-regulated and non rate-regulated businesses referred to as the utility money pool and the non-state regulated subsidiary money pool, respectively.

Moody’s - Moody’s Investors Service, Inc., a credit rating agency.

MoPSC - Missouri Public Service Commission, a state agency that regulates the Missouri utility business and operations of UE.

NRC - Nuclear Regulatory Commission, a governmental agency of the United States of America.

NOx - Nitrogen oxide.

NOPR - Notice of the Proposed Rulemaking issued by the FERC.

NYMEX - New York Mercantile Exchange.

OATT - Open Access Transmission Tariff.

OCI - Other Comprehensive Income (Loss) as defined by GAAP.

PJM - PJM Interconnection LLC.

PUHCA - Public Utility Holding Company Act of 1935, as amended.

Resources Company - Ameren Energy Resources Company, a subsidiary of Ameren Corporation, which consists of non rate-regulated operations, including Development Company, Genco, Marketing Company, AFS and Medina Valley.


 
 
7

 
RRO - Regional Reliability Organization.

RTO - Regional Transmission Organization.

S&P - Standard and Poor’s Inc., a credit rating agency.

SEC - Securities and Exchange Commission, a governmental agency of the United States of America.

SFAS - Statement of Financial Accounting Standards, the accounting and financial reporting rules issued by the FASB.

SO2 - Sulfur dioxide.

TFN - Transitional Funding Trust Notes issued by IP SPT as allowed under Illinois’ deregulation legislation.  IP must designate a percentage of cash received from customer billings to fund payment of the TFNs. The proceeds received by IP are remitted to IP SPT and are restricted for the sole purpose of making payments of principal and interest on, and paying other fees and expenses related to, the TFNs. Subsequent to the application of FIN No. 46R, IP does not consolidate IP SPT and reflects the obligation to IP SPT on IP’s balance sheet.

UE - Union Electric Company, a subsidiary of Ameren Corporation, which operates a rate-regulated electric generation, transmission and distribution business, and a rate-regulated natural gas distribution business in Missouri and Illinois as AmerenUE.

 
 
8

 

FORWARD-LOOKING STATEMENTS


Statements made in this report, which are not based on historical facts, are "forward-looking" and, accordingly, involve risks and uncertainties that could cause actual results to differ materially from those discussed. Although such "forward-looking" statements have been made in good faith and are based on reasonable assumptions, there is no assurance that the expected results will be achieved. These statements include (without limitation) statements as to future expectations, beliefs, plans, strategies, objectives, events, conditions, and financial performance. In connection with the "safe harbor" provisions of the Private Securities Litigation Reform Act of 1995, we are providing this cautionary statement to identify important factors that could cause actual results to differ materially from those anticipated. The following factors, in addition to those discussed elsewhere in this report and in past and subsequent filings with the SEC, could cause actual results to differ materially from management expectations as suggested by such "forward-looking" statements:

  • the effects of the stipulation and agreement relating to the UE Missouri electric excess earnings complaint case and other regulatory actions, including changes in regulatory policies;     
  • changes in laws and other governmental actions, including monetary and fiscal policies;
  • the effects of increased competition in the future due to, among other things, deregulation of certain aspects of our business at both the state and federal levels, and the implementation of deregulation, such as in Illinois when current power supply contracts expire in 2006;
  • the effects of participation in the Midwest ISO;
  • the availability of fuel for the production of electricity, such as coal and natural gas, and purchased power and natural gas for distribution, and the level and volatility of future market prices for such commodities, including the ability to recover any increased costs;
  • the use of financial and derivative instruments;
  • average rates for electricity in the Midwest;
  • business and economic conditions, including their impact on interest rates;
  • disruptions of the capital markets or other events making the Ameren Companies’ and IP’s access to necessary capital more difficult or costly;
  • the impact of the adoption of new accounting standards and the application of appropriate technical accounting rules and guidance;
  • actions of ratings agencies and the effects of such actions;
  • weather conditions;
  • generation plant construction, installation and performance;
  • operation of our nuclear power facility, including planned and unplanned outages, and decommissioning costs;
  • the effects of strategic initiatives, including acquisitions and divestitures;
  • the impact of current environmental regulations on utilities and generating companies and the expectation that more stringent requirements will be introduced over time, which could potentially have a negative financial effect;
  • labor disputes, future wages and employee benefits costs, including changes in returns on benefit plan assets;
  • difficulties in integrating CILCO and IP with Ameren’s other businesses;
  • changes in the energy markets, environmental laws or regulations, interest rates or other factors adversely impacting assumptions in connection with the CILCORP and IP acquisitions;
  • the impact of conditions imposed by regulators in connection with their approval of Ameren’s acquisition of IP;
  • cost and availability of transmission capacity for the energy generated by the Ameren Companies’ generating facilities or required to satisfy energy sales made by the Ameren Companies and IP; and
  • legal and administrative proceedings.
Given these uncertainties, undue reliance should not be placed on these forward-looking statements. Except to the extent required by the federal securities laws, we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

 
 
9

 

PART I.   FINANCIAL INFORMATION
 
                   
ITEM 1.   FINANCIAL STATEMENTS.
                 
                   
AMEREN CORPORATION
 
CONSOLIDATED STATEMENT OF INCOME
 
(Unaudited) (In millions, except per share amounts)
 
                   
   
Three Months Ended
 
Nine Months Ended
 
   
September 30,
 
September 30,
 
   
2004
 
2003
 
2004
 
2003
 
Operating Revenues:
                 
Electric
 
$
1,237
 
$
1,269
 
$
3,182
 
$
3,101
 
Gas
   
78
   
82
   
498
   
450
 
Other
   
2
   
2
   
5
   
6
 
Total operating revenues
   
1,317
   
1,353
   
3,685
   
3,557
 
Operating Expenses:
                         
Fuel and purchased power
   
330
   
336
   
890
   
814
 
Gas purchased for resale
   
47
   
51
   
335
   
316
 
Other operations and maintenance
   
314
   
302
   
956
   
901
 
Coal contract settlement
   
-
   
(51
)
 
-
   
(51
)
Depreciation and amortization
   
136
   
132
   
398
   
388
 
Taxes other than income taxes
   
77
   
83
   
231
   
238
 
Total operating expenses
   
904
   
853
   
2,810
   
2,606
 
Operating Income
   
413
   
500
   
875
   
951
 
Other Income and (Deductions):
                         
Miscellaneous income
   
8
   
4
   
20
   
16
 
Miscellaneous expense
   
(1
)
 
(3
)
 
(6
)
 
(14
)
Total other income and (deductions)
   
7
   
1
   
14
   
2
 
Interest Charges and Preferred Dividends:
                         
Interest
   
62
   
69
   
192
   
204
 
Preferred dividends of subsidiaries
   
3
   
3
   
8
   
8
 
Net interest charges and preferred dividends
   
65
   
72
   
200
   
212
 
Income Before Income Taxes and Cumulative Effect of Change
                         
in Accounting Principle
   
355
   
429
   
689
   
741
 
Income Taxes
   
123
   
154
   
242
   
273
 
Income Before Cumulative Effect of Change in Accounting
                         
Principle
   
232
   
275
   
447
   
468
 
Cumulative Effect of Change in Accounting Principle,
                         
Net of Income Taxes of $-, $-, $- and $12
   
-
   
-
   
-
   
18
 
Net Income
 
$
232
 
$
275
 
$
447
 
$
486
 
Earnings per Common Share - Basic and Diluted:
                         
Income before cumulative effect of change
                         
in accounting principle
 
$
1.20
 
$
1.70
 
$
2.44
 
$
2.91
 
Cumulative effect of change in accounting
                         
principle, net of income taxes
   
-
   
-
   
-
   
0.11
 
Earnings per Common Share - Basic and Diluted
 
$
1.20
 
$
1.70
 
$
2.44
 
$
3.02
 
                           
Dividends per Common Share
 
$
0.635
 
$
0.635
 
$
1.905
 
$
1.905
 
Average Common Shares Outstanding
   
193.5
   
161.8
   
183.5
   
160.7
 
                           
The accompanying notes are an integral part of these consolidated financial statements.
           


  
10

 


AMEREN CORPORATION
 
CONSOLIDATED BALANCE SHEET
 
(Unaudited) (In millions, except per share amounts)
 
           
   
September 30,
 
December 31,
 
   
2004
 
2003
 
ASSETS
         
Current Assets:
         
Cash and cash equivalents
 
$
647
 
$
111
 
Accounts receivables - trade (less allowance for doubtful
             
accounts of $14 and $13, respectively)
   
466
   
326
 
Unbilled revenue
   
265
   
221
 
Miscellaneous accounts and notes receivable
   
51
   
126
 
Materials and supplies, at average cost
   
605
   
487
 
Other current assets
   
108
   
46
 
Total current assets
   
2,142
   
1,317
 
Property and Plant, Net
   
13,052
   
10,920
 
Investments and Other Non-Current Assets:
             
Investments in leveraged leases
   
140
   
152
 
Nuclear decommissioning trust fund
   
219
   
212
 
Goodwill and other intangibles, net
   
979
   
574
 
Other assets
   
448
   
332
 
Total investments and other non-current assets
   
1,786
   
1,270
 
Regulatory Assets
   
784
   
729
 
TOTAL ASSETS
 
$
17,764
 
$
14,236
 
               
               
LIABILITIES AND STOCKHOLDERS' EQUITY
             
Current Liabilities:
             
Current maturities of long-term debt
 
$
263
 
$
498
 
Short-term debt
   
31
   
161
 
Accounts and wages payable
   
320
   
480
 
Taxes accrued
   
357
   
103
 
Other current liabilities
   
403
   
215
 
Total current liabilities
   
1,374
   
1,457
 
Long-term Debt, Net
   
6,164
   
4,070
 
Preferred Stock of Subsidiary Subject to Mandatory Redemption
   
20
   
21
 
Deferred Credits and Other Non-Current Liabilities:
             
Accumulated deferred income taxes, net
   
1,616
   
1,853
 
Accumulated deferred investment tax credits
   
142
   
151
 
Regulatory liabilities
   
945
   
824
 
Asset retirement obligations
   
431
   
413
 
Accrued pension and other postretirement benefits
   
726
   
699
 
Other deferred credits and liabilities
   
305
   
190
 
Total deferred credits and other non-current liabilities
   
4,165
   
4,130
 
Preferred Stock of Subsidiaries Not Subject to Mandatory Redemption
   
196
   
182
 
Minority Interest in Consolidated Subsidiaries
   
13
   
22
 
Commitments and Contingencies (Note 9)
             
Stockholders' Equity:
             
Common stock, $.01 par value, 400.0 shares authorized -
             
shares outstanding of 194.8 and 162.9, respectively
   
2
   
2
 
Other paid-in capital, principally premium on common stock
   
3,924
   
2,552
 
Retained earnings
   
1,945
   
1,853
 
Accumulated other comprehensive loss
   
(27
)
 
(44
)
Other
   
(12
)
 
(9
)
Total stockholders’ equity
   
5,832
   
4,354
 
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY
 
$
17,764
 
$
14,236
 
               
               
The accompanying notes are an integral part of these consolidated financial statements.
     

  
11

 

AMEREN CORPORATION
 
CONSOLIDATED STATEMENT OF CASH FLOWS
 
(Unaudited) (In millions)
 
           
   
Nine Months Ended
 
   
September 30,
 
   
2004
 
2003
 
           
           
Cash Flows From Operating Activities:
         
Net income
 
$
447
 
$
486
 
Adjustments to reconcile net income to net cash
             
provided by operating activities:
             
Cumulative effect of change in accounting principle
   
-
   
(18
)
Depreciation and amortization
   
398
   
388
 
Amortization of nuclear fuel
   
21
   
25
 
Amortization of debt issuance costs and premium/discounts
   
8
   
8
 
Deferred income taxes, net
   
52
   
30
 
Deferred investment tax credits, net
   
(9
)
 
(9
)
Coal contract settlement
   
28
   
(45
)
Pension contribution
   
(295
)
 
(25
)
Other
   
29
   
(8
)
Changes in assets and liabilities, excluding the effects of the acquisitions:
             
Receivables, net
   
21
   
17
 
Materials and supplies
   
(32
)
 
(69
)
Accounts and wages payable
   
(192
)
 
(171
)
Taxes accrued
   
257
   
167
 
Assets, other
   
(86)
 
 
(8
)
Liabilities, other
   
89
   
84
 
Net cash provided by operating activities
   
736
   
852
 
               
Cash Flows From Investing Activities:
             
Construction expenditures
   
(547
)
 
(457
)
Acquisitions, net of cash acquired
   
(451
)
 
(489
)
Nuclear fuel expenditures
   
(7
)
 
(2
)
Other
   
28
   
10
 
Net cash used in investing activities
   
(977
)
 
(938
)
               
Cash Flows From Financing Activities:
             
Dividends on common stock
   
(356
)
 
(308
)
Capital issuance costs
   
(40
)
 
(13
)
Redemptions, repurchases, and maturities:
             
Nuclear fuel lease
   
(67
)
 
(38
)
Short-term debt
   
(130
)
 
(268
)
Long-term debt
   
(451
)
 
(648
)
Preferred stock
   
(1
)
 
(1
)
Issuances:
             
Common stock
   
1,418
   
336
 
Long-term debt
   
404
   
498
 
Net cash provided by (used in) financing activities
   
777
   
(442
)
               
Net change in cash and cash equivalents
   
536
   
(528
)
Cash and cash equivalents at beginning of year
   
111
   
628
 
Cash and cash equivalents at end of period
 
$
647
 
$
100
 
               
Cash Paid During the Periods:
             
Interest
 
$
187
 
$
189
 
Income taxes, net
   
20
   
156
 
               
               
The accompanying notes are an integral part of these consolidated financial statements.
     
 
  
12

 

UNION ELECTRIC COMPANY
 
CONSOLIDATED STATEMENT OF INCOME
 
(Unaudited) (In millions)
 
                   
                   
   
Three Months Ended
 
Nine Months Ended
 
   
September 30,
 
September 30,
 
   
2004
 
2003
 
2004
 
2003
 
Operating Revenues:
                 
Electric
 
$
776
 
$
801
 
$
1,982
 
$
1,972
 
Gas
   
17
   
15
   
114
   
100
 
Total operating revenues
   
793
   
816
   
2,096
   
2,072
 
                           
Operating Expenses:
                         
Fuel and purchased power
   
156
   
158
   
445
   
431
 
Gas purchased for resale
   
11
   
10
   
69
   
62
 
Other operations and maintenance
   
186
   
187
   
579
   
551
 
Coal contract settlement
   
-
   
(51
)
 
-
   
(51
)
Depreciation and amortization
   
73
   
71
   
219
   
212
 
Taxes other than income taxes
   
61
   
61
   
172
   
168
 
Total operating expenses
   
487
   
436
   
1,484
   
1,373
 
                           
Operating Income
   
306
   
380
   
612
   
699
 
                           
Other Income and (Deductions):
                         
Miscellaneous income
   
5
   
5
   
14
   
14
 
Miscellaneous expense
   
(1
)
 
(2
)
 
(6
)
 
(5
)
Total other income and (deductions)
   
4
   
3
   
8
   
9
 
                           
Interest Charges
   
23
   
23
   
74
   
74
 
                           
Income Before Income Taxes
   
287
   
360
   
546
   
634
 
                           
Income Taxes
   
105
   
135
   
197
   
234
 
                           
Net Income
   
182
   
225
   
349
   
400
 
                           
Preferred Stock Dividends
   
1
   
1
   
4
   
4
 
                           
Net Income Available to Common Stockholder
 
$
181
 
$
224
 
$
345
 
$
396
 
                           
                           
                           
                           
                           
                           
                           
                           
                           
                           
                           
                           
                           
The accompanying notes as they relate to UE are an integral part of these consolidated financial statements.


  
13

 


UNION ELECTRIC COMPANY
 
CONSOLIDATED BALANCE SHEET
 
(Unaudited) (In millions, except per share amounts)
 
           
   
September 30,
 
December 31,
 
   
2004
 
2003
 
ASSETS
         
Current Assets:
         
Cash and cash equivalents
 
$
13
 
$
15
 
Accounts receivable - trade (less allowance for doubtful
             
accounts of $4 and $6, respectively)
   
208
   
172
 
Unbilled revenue
   
116
   
111
 
Miscellaneous accounts and notes receivable
   
36
   
117
 
Materials and supplies, at average cost
   
199
   
175
 
Other current assets
   
23
   
26
 
Total current assets
   
595
   
616
 
Property and Plant, Net
   
6,950
   
6,758
 
Investments and Other Non-Current Assets:
             
Nuclear decommissioning trust fund
   
220
   
212
 
Other assets
   
264
   
246
 
Total investments and other non-current assets
   
484
   
458
 
Regulatory Assets
   
615
   
685
 
TOTAL ASSETS
 
$
8,644
 
$
8,517
 
               
               
LIABILITIES AND STOCKHOLDERS' EQUITY
             
Current Liabilities:
             
Current maturities of long-term debt
 
$
88
 
$
344
 
Short-term debt
   
-
   
150
 
Borrowings from money pool
   
189
   
-
 
Accounts and wages payable
   
132
   
314
 
Taxes accrued
   
284
   
66
 
Other current liabilities
   
97
   
102
 
Total current liabilities
   
790
   
976
 
Long-term Debt, Net
   
2,062
   
1,758
 
Deferred Credits and Other Non-Current Liabilities:
             
Accumulated deferred income taxes, net
   
1,224
   
1,289
 
Accumulated deferred investment tax credits
   
109
   
114
 
Regulatory liabilities
   
689
   
652
 
Asset retirement obligations
   
426
   
408
 
Accrued pension and other postretirement benefits
   
211
   
317
 
Other deferred credits and liabilities
   
77
   
80
 
Total deferred credits and other non-current liabilities
   
2,736
   
2,860
 
Commitments and Contingencies (Note 9)
             
Stockholders' Equity:
             
Common stock, $5 par value, 150.0 shares authorized - 102.1 shares outstanding
   
511
   
511
 
Preferred stock not subject to mandatory redemption
   
113
   
113
 
Other paid-in capital, principally premium on common stock
   
715
   
702
 
Retained earnings
   
1,745
   
1,630
 
Accumulated other comprehensive loss
   
(28
)
 
(33
)
Total stockholders' equity
   
3,056
   
2,923
 
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY
 
$
8,644
 
$
8,517
 
               
               
The accompanying notes as they relate to UE are an integral part of these consolidated financial statements.


  
14

 

 
 
UNION ELECTRIC COMPANY
 
CONSOLIDATED STATEMENT OF CASH FLOWS
 
(Unaudited) (In millions)
 
           
   
Nine Months Ended
 
   
September 30,
 
   
2004
 
2003
 
Cash Flows From Operating Activities:
         
Net income
 
$
349
 
$
400
 
Adjustments to reconcile net income to net cash
             
provided by operating activities:
             
Depreciation and amortization
   
219
   
212
 
Amortization of nuclear fuel
   
21
   
25
 
Amortization of debt issuance costs and premium/discounts
   
4
   
3
 
Deferred income taxes, net
   
24
   
16
 
Deferred investment tax credits, net
   
(5
)
 
(5
)
Coal contract settlement
   
28
   
(45
)
Pension contribution
   
(186
)
 
(18
)
Other
   
5
   
(3
)
Changes in assets and liabilities:
             
Receivables, net
   
(27
)
 
(38
)
Materials and supplies
   
(24
)
 
(20
)
Accounts and wages payable
   
(164
)
 
(147
)
Taxes accrued
   
231
   
95
 
Assets, other
   
(36
)
 
(46
)
Liabilities, other
   
90
   
57
 
Net cash provided by operating activities
   
529
   
486
 
               
Cash Flows From Investing Activities:
             
Construction expenditures
   
(374
)
 
(310
)
Nuclear fuel expenditures
   
(7
)
 
(2
)
Other
   
-
   
4
 
Net cash used in investing activities
   
(381
)
 
(308
)
               
Cash Flows From Financing Activities:
             
Dividends on common stock
   
(230
)
 
(224
)
Dividends on preferred stock
   
(4
)
 
(4
)
Other
   
(4
)
 
(5
)
Redemptions, repurchases, and maturities:
             
Nuclear fuel lease
   
(67
)
 
(38
)
Short-term debt
   
(150
)
 
(250
)
Long-term debt
   
(288
)
 
(364
)
Issuances:
             
Long-term debt
   
404
   
498
 
Borrowings from money pool
   
189
   
215
 
Net cash used in financing activities
   
(150
)
 
(172
)
               
Net change in cash and cash equivalents
   
(2
)
 
6
 
Cash and cash equivalents at beginning of year
   
15
   
9
 
Cash and cash equivalents at end of period
 
$
13
 
$
15
 
               
Cash Paid During the Periods:
             
Interest
 
$
72
 
$
78
 
Income taxes, net
   
33
   
199
 
               
               
The accompanying notes as they relate to UE are an integral part of these consolidated financial statements.
 


  
15

 


CENTRAL ILLINOIS PUBLIC SERVICE COMPANY
 
STATEMENT OF INCOME
 
(Unaudited) (In millions)
 
                   
                   
   
Three Months Ended
 
Nine Months Ended
 
   
September 30,
 
September 30,
 
   
2004
 
2003
 
2004
 
2003
 
Operating Revenues:
                 
Electric
 
$
166
 
$
176
 
$
432
 
$
445
 
Gas
   
21
   
20
   
134
   
127
 
Total operating revenues
   
187
   
196
   
566
   
572
 
                           
Operating Expenses:
                         
Purchased power
   
85
   
96
   
244
   
264
 
Gas purchased for resale
   
10
   
9
   
82
   
80
 
Other operations and maintenance
   
37
   
41
   
109
   
121
 
Depreciation and amortization
   
13
   
13
   
39
   
39
 
Taxes other than income taxes
   
6
   
6
   
20
   
22
 
Total operating expenses
   
151
   
165
   
494
   
526
 
                           
Operating Income
   
36
   
31
   
72
   
46
 
                           
Other Income and (Deductions):
                         
Miscellaneous income
   
6
   
7
   
19
   
21
 
Miscellaneous expense
   
-
   
-
   
(1
)
 
(2
)
Total other income and (deductions)
   
6
   
7
   
18
   
19
 
                           
Interest Charges
   
8
   
8
   
24
   
26
 
                           
Income Before Income Taxes
   
34
   
30
   
66
   
39
 
                           
Income Taxes
   
11
   
4
   
25
   
8
 
                           
Net Income
   
23
   
26
   
41
   
31
 
                           
Preferred Stock Dividends
   
1
   
1
   
2
   
2
 
                           
Net Income Available to Common Stockholder
 
$
22
 
$
25
 
$
39
 
$
29
 
                           
                           
The accompanying notes as they relate to CIPS are an integral part of these financial statements.
     


  
16

 


CENTRAL ILLINOIS PUBLIC SERVICE COMPANY
 
BALANCE SHEET
 
(Unaudited) (In millions)
 
           
   
September 30,
 
December 31,
 
   
2004
 
2003
 
ASSETS
         
Current Assets:
         
Cash and cash equivalents
 
$
4
 
$
16
 
Accounts receivable - trade (less allowance for doubtful
             
accounts of $1 and $1, respectively)
   
44
   
48
 
Unbilled revenue
   
65
   
64
 
Miscellaneous accounts and notes receivable
   
11
   
22
 
Current portion of intercompany note receivable - Genco
   
324
   
49
 
Current portion of intercompany tax receivable - Genco
   
11
   
12
 
Materials and supplies, at average cost
   
64
   
51
 
Other current assets
   
16
   
6
 
Total current assets
   
539
   
268
 
Property and Plant, Net
   
951
   
955
 
Investments and Other Non-Current Assets:
             
Intercompany note receivable - Genco
   
-
   
324
 
Intercompany tax receivable - Genco
   
141
   
150
 
Other assets
   
27
   
17
 
Total investments and other non-current assets
   
168
   
491
 
Regulatory Assets
   
31
   
28
 
TOTAL ASSETS
 
$
1,689
 
$
1,742
 
               
               
LIABILITIES AND STOCKHOLDERS' EQUITY
             
Current Liabilities:
             
Current maturities of long-term debt
 
$
20
 
$
-
 
Accounts and wages payable
   
64
   
71
 
Borrowings from money pool
   
61
   
121
 
Taxes accrued
   
40
   
19
 
Other current liabilities
   
34
   
27
 
Total current liabilities
   
219
   
238
 
Long-term Debt, Net
   
465
   
485
 
Deferred Credits and Other Non-Current Liabilities:
             
Accumulated deferred income taxes, net
   
276
   
269
 
Accumulated deferred investment tax credits
   
10
   
11
 
Regulatory liabilities
   
147
   
145
 
Other deferred credits and liabilities
   
40
   
62
 
Total deferred credits and other non-current liabilities
   
473
   
487
 
Commitments and Contingencies (Note 9)
             
Stockholders' Equity:
             
Common stock, no par value, 45.0 shares authorized - 25.5 shares outstanding
   
-
   
-
 
Other paid-in capital
    121     120  
Preferred stock not subject to mandatory redemption
   
50
   
50
 
Retained earnings
   
362
   
369
 
Accumulated other comprehensive loss
   
(1)
 
(7)
 
Total stockholders' equity
   
532
   
532
 
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY
 
$
1,689
 
$
1,742
 
               
               
The accompanying notes as they relate to CIPS are an integral part of these financial statements.
     


  
17

 

CENTRAL ILLINOIS PUBLIC SERVICE COMPANY
 
STATEMENT OF CASH FLOWS
 
(Unaudited) (In millions)
 
           
           
   
Nine Months Ended
 
   
September 30,
 
   
2004
 
2003
 
           
Cash Flows From Operating Activities:
         
Net income
 
$
41
 
$
31
 
Adjustments to reconcile net income to net cash
             
provided by operating activities:
             
Depreciation and amortization
   
39
   
39
 
Amortization of debt issuance costs and premium/discounts
   
1
   
1
 
Deferred income taxes, net
   
(11
)
 
(11
)
Deferred investment tax credits, net
   
(1
)
 
(1
)
Pension contribution
   
(33
)
 
(4
)
Other
   
6
   
(3
)
Changes in assets and liabilities:
             
Receivables, net
   
14
   
18
 
Materials and supplies
   
(13
)
 
(16
)
Accounts and wages payable
   
(7
)
 
23
 
Taxes accrued
   
22
   
2
 
Assets, other
   
(12
)
 
9
 
Liabilities, other
   
33
   
14
 
Net cash provided by operating activities
   
79
   
102
 
               
Cash Flows From Investing Activities:
             
Construction expenditures
   
(32
)
 
(36
)
Intercompany note receivable - Genco
   
49
   
62
 
Net cash provided by investing activities
   
17
   
26
 
               
Cash Flows From Financing Activities:
             
Dividends on common stock
   
(46
)
 
(54
)
Dividends on preferred stock
   
(2
)
 
(2
)
Repayments to money pool
   
(60
)
 
-
 
Redemptions, repurchases, and maturities:
             
Long-term debt
   
-
   
(95
)
Borrowings from money pool
   
-
   
23
 
Net cash used in financing activities
   
(108
)
 
(128
)
               
Net change in cash and cash equivalents
   
(12
)
 
-
 
Cash and cash equivalents at beginning of year
   
16
   
17
 
Cash and cash equivalents at end of period
 
$
4
 
$
17
 
               
Cash Paid During the Periods:
             
Interest
 
$
19
 
$
23
 
Income taxes, net
   
11
   
18
 
               
               
The accompanying notes as they relate to CIPS are an integral part of these financial statements.


  
18

 


AMEREN ENERGY GENERATING COMPANY
 
STATEMENT OF INCOME
 
(Unaudited) (In millions)
 
                   
                   
   
Three Months Ended
 
Nine Months Ended
 
   
September 30,
 
September 30,
 
   
2004
 
2003
 
2004
 
2003
 
Operating Revenues:
                 
Electric
 
$
233
 
$
217
 
$
657
 
$
596
 
Total operating revenues
   
233
   
217
   
657
   
596
 
                           
Operating Expenses:
                         
Fuel and purchased power
   
107
   
104
   
292
   
269
 
Other operations and maintenance
   
32
   
36
   
103
   
100
 
Depreciation and amortization
   
19
   
19
   
57
   
56
 
Taxes other than income taxes
   
5
   
5
   
16
   
18
 
Total operating expenses
   
163
   
164
   
468
   
443
 
                           
Operating Income
   
70
   
53
   
189
   
153
 
                           
Other Income and (Deductions):
                         
Miscellaneous income
   
1
   
-
   
-
   
-
 
Total other income and (deductions)
   
1
   
-
   
-
   
-
 
                           
Interest Charges
   
25
   
25
   
72
   
76
 
                           
Income Before Income Taxes and Cumulative Effect of Change
                         
in Accounting Principle
   
46
   
28
   
117
   
77
 
                           
Income Taxes
   
17
   
11
   
42
   
30
 
                           
Income Before Cumulative Effect of Change in Accounting
                         
Principle
   
29
   
17
   
75
   
47
 
                           
Cumulative Effect of Change in Accounting Principle,
                         
Net of Income Taxes of $-, $-, $- and $12
   
-
   
-
   
-
   
18
 
                           
Net Income
 
$
29
 
$
17
 
$
75
 
$
65
 
                           
                           
The accompanying notes as they relate to Genco are an integral part of these financial statements.
           


  
19

 


AMEREN ENERGY GENERATING COMPANY
 
BALANCE SHEET
 
(Unaudited) (In millions, except shares)
 
           
   
September 30,
 
December 31,
 
   
2004
 
2003
 
ASSETS
         
Current Assets:
         
Cash and cash equivalents
 
$
-
 
$
2
 
Accounts receivable
   
93
   
88
 
Materials and supplies, at average cost
   
90
   
90
 
Other current assets
   
3
   
4
 
Total current assets
   
186
   
184
 
Property and Plant, Net
   
1,743
   
1,774
 
Other Non-Current Assets
   
19
   
19
 
TOTAL ASSETS
 
$
1,948
 
$
1,977
 
               
               
LIABILITIES AND STOCKHOLDER'S EQUITY
             
Current Liabilities:
             
Accounts and wages payable
 
$
45
 
$
75
 
Borrowings from money pool
   
79
   
124
 
Current portion of intercompany notes payable - CIPS and Ameren
   
358
   
53
 
Current portion of intercompany tax payable - CIPS
   
11
   
12
 
Taxes accrued
   
36
   
30
 
Other current liabilities
   
36
   
23
 
Total current liabilities
   
565
   
317
 
Long-term Debt, Net
   
698
   
698
 
Intercompany Notes Payable - CIPS and Ameren
   
-
   
358
 
Deferred Credits and Other Non-Current Liabilities:
             
Accumulated deferred income taxes, net
   
115
   
99
 
Accumulated deferred investment tax credits
   
12
   
13
 
Intercompany tax payable - CIPS
   
141
   
150
 
Accrued pension and other postretirement benefits
   
1
   
19
 
Other deferred credits and liabilities
   
3
   
2
 
Total deferred credits and other non-current liabilities
   
272
   
283
 
Commitments and Contingencies (Note 9)
             
Stockholder's Equity:
             
Common stock, no par value, 10,000 shares authorized - 2,000 shares outstanding
   
-
   
-
 
Other paid-in capital
   
225
   
150
 
Retained earnings
   
189
   
170
 
Accumulated other comprehensive (loss) income
   
(1
)
 
1
 
Total stockholder's equity
   
413
   
321
 
TOTAL LIABILITIES AND STOCKHOLDER'S EQUITY
 
$
1,948
 
$
1,977
 
               
               
The accompanying notes as they relate to Genco are an integral part of these financial statements.
     


  
20

 


AMEREN ENERGY GENERATING COMPANY
 
STATEMENT OF CASH FLOWS
 
(Unaudited) (In millions)
 
           
           
   
Nine Months Ended
 
   
September 30,
 
   
2004
 
2003
 
           
Cash Flows From Operating Activities:
         
Net income
 
$
75
 
$
65
 
Adjustments to reconcile net income to net cash
             
provided by operating activities:
             
Cumulative effect of change in accounting principle
   
-
   
(18
)
Amortization of debt issuance costs and discounts
   
1
   
1
 
Depreciation and amortization
   
57
   
56
 
Deferred income taxes, net
   
29
   
37
 
Pension contribution
   
(29
)
 
(3
)
Other
   
(2
)
 
(1
)
Changes in assets and liabilities:
             
Accounts receivable
   
(5
)
 
(63
)
Materials and supplies
   
-
   
(18
)
Taxes accrued
   
6
   
64
 
Accounts and wages payable
   
(20
)
 
(4
)
Assets, other
   
1
   
(1
)
Liabilities, other
   
2
   
10
 
Net cash provided by operating activities
   
115
   
125
 
               
Cash Flows From Investing Activities:
             
Construction expenditures
   
(37
)
 
(39
)
Net cash used in investing activities
   
(37
)
 
(39
)
               
Cash Flows From Financing Activities:
             
Dividends on common stock
   
(57
)
 
(22
)
Redemptions, repurchases, and maturities:
             
Repayments to money pool
   
(45
)
 
(14
)
Intercompany notes payable - CIPS and Ameren
   
(53
)
 
(51
)
Capital contribution from parent
   
75
   
-
 
Net cash used in financing activities
   
(80
)
 
(87
)
               
Net change in cash and cash equivalents
   
(2
)
 
(1
)
Cash and cash equivalents at beginning of year
   
2
   
3
 
Cash and cash equivalents at end of period
 
$
-
 
$
2
 
               
Cash Paid During the Periods:
             
Interest
 
$
58
 
$
60
 
Income taxes, net paid (refunded)
   
11
   
(66
)
               
               
The accompanying notes as they relate to Genco are an integral part of these financial statements.


  
21

 




CILCORP INC.
 
CONSOLIDATED STATEMENT OF INCOME
 
(Unaudited) (In millions)
 
                        
                        
   
---------------Successor---------------
 
---------------Successor---------------
 
 -Predecessor-
 
   
Three
 
Three
 
Nine
 
Eight
      
   
Months
 
Months
 
Months
 
Months
      
   
Ended
 
Ended
 
Ended
 
Ended
      
   
September 30,
 
September 30,
 
September 30,
 
September 30,
 
 January
 
   
2004
 
2003
 
2004
 
2003
 
 2003
 
Operating Revenues:
                      
Electric
 
$108
 
$171
 
$295
 
$384
 
$49
 
Gas
 
 37
 
 46
 
 228
 
 215
 
 58
 
Other
 
 1
 
 1
 
 3
 
 3
 
 -
 
Total operating revenues
 
 146
 
 218
 
 526
 
 602
 
 107
 
                            
Operating Expenses:
                          
Fuel and purchased power
 
 39
 
 88
 
 117
 
 203
 
 26
 
Gas purchased for resale
 
 24
 
 32
 
 162
 
 166
 
 44
 
Other operations and maintenance
 
 53
 
 38
 
 143
 
 95
 
 14
 
Depreciation and amortization
 
 18
 
 18
 
 51
 
 54
 
 6
 
Taxes other than income taxes
 
 4
 
 9
 
 18
 
 26
 
 4
 
Total operating expenses
   
138
   
185
   
491
   
544
   
94
 
                                 
Operating Income
   
8
   
33
   
35
   
58
   
13
 
                                 
Other Income and (Deductions):
                               
Miscellaneous expense
   
(2
)
 
(2
)
 
(4
)
 
(3
)
 
-
 
Total other income and (deductions)
   
(2
)
 
(2
)
 
(4
)
 
(3
)
 
-
 
                                 
Interest Charges and Preferred Dividends:
                               
Interest
   
13
   
15
   
39
   
35
   
5
 
Preferred dividends of subsidiaries
   
-
   
-
   
1
   
1
   
-
 
Net interest charges and preferred dividends
   
13
   
15
   
40
   
36
   
5
 
                                 
Income  (Loss) Before Income Taxes and Cumulative Effect of
                               
Change in Accounting Principle
   
(7
)
 
16
   
(9
)
 
19
   
8
 
                                 
Income Taxes (Benefit)
   
(9
)
 
5
   
(11
)
 
5
   
3
 
                                 
Income Before Cumulative Effect of Change in
   
2
   
11
   
2
   
14
   
5
 
Accounting Principle
                               
                                 
Cumulative Effect of Change in Accounting Principle,
                               
Net of Income Taxes of $-, $-, $-, $- and $2
   
-
   
-
   
-
   
-
   
4
 
                                 
Net Income
 
$
2
 
$
11
 
$
2
 
$
14
 
$
9
 
                                 
                                 
The accompanying notes as they relate to CILCORP are an integral part of these consolidated financial statements.
           


  
22

 


CILCORP INC.
 
CONSOLIDATED BALANCE SHEET
 
(Unaudited) (In millions, except shares)
 
           
   
--------------Successor--------------
 
   
September 30,
 
December 31,
 
   
2004
 
2003
 
           
ASSETS
         
Current Assets:
         
Cash and cash equivalents
 
$
9
 
$
11
 
Accounts receivables - trade (less allowance for doubtful
             
accounts of $4 and $6, respectively)
   
28
   
59
 
Unbilled revenue
   
18
   
40
 
Miscellaneous accounts and notes receivable
   
8
   
16
 
Materials and supplies, at average cost
   
146
   
154
 
Other current assets
   
5
   
5
 
Total current assets
   
214
   
285
 
Property and Plant, Net
   
1,161
   
1,127
 
Investments and Other Non-Current Assets:
             
Investments in leveraged leases
   
114
   
118
 
Goodwill and other intangibles, net
   
558
   
567
 
Other assets
   
41
   
23
 
Total investments and other non-current assets
   
713
   
708
 
Regulatory Assets
   
13
   
16
 
TOTAL ASSETS
 
$
2,101
 
$
2,136
 
               
               
LIABILITIES AND STOCKHOLDER'S EQUITY
             
Current Liabilities:
             
Current maturities of long-term debt
 
$
-
 
$
100
 
Borrowings from money pool
   
191
   
145
 
Intercompany note payable - Ameren
   
56
   
46
 
Accounts and wages payable
   
73
   
108
 
Other current liabilities
   
58
   
38
 
Total current liabilities
   
378
   
437
 
Long-term Debt, Net
   
641
   
669
 
Preferred Stock of Subsidiary Subject to Mandatory Redemption
   
20
   
21
 
Deferred Credits and Other Non-Current Liabilities:
             
Accumulated deferred income taxes, net
   
184
   
181
 
Accumulated deferred investment tax credits
   
10
   
11
 
Regulatory liabilities
   
35
   
24
 
Accrued pension and other postretirement benefits
   
238
   
259
 
Other deferred credits and liabilities
   
27
   
37
 
Total deferred credits and other non-current liabilities
   
494
   
512
 
Preferred Stock of Subsidiary Not Subject to Mandatory Redemption
   
19
   
19
 
Commitments and Contingencies (Note 9)
             
Common stock, no par value, 10,000 shares authorized - 1,000 shares outstanding
   
-
   
-
 
Other paid-in capital
   
565
   
490
 
Retained earnings
   
(29
)
 
(13
)
Accumulated other comprehensive income
   
13
   
1
 
Total stockholder's equity
   
549
   
478
 
TOTAL LIABILITIES AND STOCKHOLDER'S EQUITY
 
$
2,101
 
$
2,136
 
               
               
The accompanying notes as they relate to CILCORP are an integral part of these consolidated financial statements.
               


  
23

 


CILCORP INC.
 
CONSOLIDATED STATEMENT OF CASH FLOWS
 
(Unaudited) (In millions)
 
                
   
---------------Successor---------------
 
 ---Predecessor---
 
   
Nine
 
Eight
      
   
Months
 
Months
      
   
Ended
 
Ended
      
   
September 30,
 
September 30,
 
 January
 
   
2004
 
2003
 
2003
 
                
Cash Flows From Operating Activities:
              
Net income
 
$
2
 
$
14
 
$
9
 
Adjustments to reconcile net income to net cash
                   
provided by operating activities:
                   
Cumulative effect of change in accounting principle
   
-
   
-
   
(4
)
Depreciation and amortization
   
51
   
55
   
6
 
Deferred income taxes, net
   
11
   
(5
)
 
(5
)
Deferred investment tax credits, net
   
(1
)
 
(1
)
 
-
 
Pension contribution
   
(41
)
 
-
   
-
 
Other
   
17
   
(9
)
 
-
 
Changes in assets and liabilities:
                   
Receivables, net
   
61
   
36
   
(20
)
Materials and supplies
   
8
   
(18
)
 
13
 
Accounts and wages payable
   
(26
)
 
(37
)
 
20
 
Taxes accrued
   
11
   
(3
)
 
11
 
Assets, other
   
(15
)
 
5
   
6
 
Liabilities, other
   
22
 
 
7
   
(5
)
Net cash provided by operating activities
   
100
   
44
   
31
 
                     
Cash Flows From Investing Activities:
                   
Construction expenditures
   
(95
)
 
(52
)
 
(16
)
Other
   
4
   
3
   
1
 
Net cash used in investing activities
   
(91
)
 
(49
)
 
(15
)
                     
Cash Flows From Financing Activities:
                   
Dividends on common stock
   
(18
)
 
(10
)
 
-
 
Redemptions, repurchases, and maturities:
                   
Short-term debt
   
-
   
-
   
(10
)
Long-term debt
   
(123
)
 
(153
)
 
-
 
Preferred stock
   
(1
)
 
(1
)
 
-
 
Issuances:
                   
Borrowings from money pool
   
46
   
109
   
-
 
Intercompany note payable - Ameren
   
10
   
31
   
-
 
Capital contribution from parent
   
75
   
-
   
-
 
Net cash used in financing activities
   
(11
)
 
(24
)
 
(10
)
                     
Net change in cash and cash equivalents
   
(2
)
 
(29
)
 
6
 
Cash and cash equivalents at beginning of period
   
11
   
38
   
32
 
Cash and cash equivalents at end of period
 
$
9
 
$
9
 
$
38
 
                     
Cash Paid During the Periods:
                   
Interest
 
$
19
 
$
14
 
$
5
 
Income taxes, net (refunded) paid
   
(17
)
 
10
   
-
 
                     
                     
                     
The accompanying notes as they relate to CILCORP are an integral part of these consolidated financial statements.


  
24

 


CENTRAL ILLINOIS LIGHT COMPANY
 
CONSOLIDATED STATEMENT OF INCOME
 
(Unaudited) (In millions)
 
                   
   
Three Months Ended
 
Nine Months Ended
 
   
September 30,
 
September 30,
 
   
2004
 
2003
 
2004
 
2003
 
Operating Revenues:
                         
Electric
 
$
108
 
$
171
 
$
295
 
$
433
 
Gas
   
34
   
35
   
206
   
201
 
Total operating revenues
   
142
   
206
   
501
   
634
 
                           
Operating Expenses:
                         
Fuel and purchased power
   
33
   
88
   
109
   
227
 
Gas purchased for resale
   
21
   
21
   
140
   
136
 
Other operations and maintenance
   
55
   
43
   
150
   
123
 
Depreciation and amortization
   
16
   
16
   
48
   
53
 
Taxes other than income taxes
   
4
   
9
   
18
   
30
 
Total operating expenses
   
129
   
177
   
465
   
569
 
                           
Operating Income
   
13
   
29
   
36
   
65
 
                           
Other Income and (Deductions):
                         
Miscellaneous expense
   
(1
)
 
(2
)
 
(4
)
 
(3
)
Total other income and (deductions)
   
(1
)
 
(2
)
 
(4
)
 
(3
)
                           
Interest Charges
   
5
   
3
   
12
   
13
 
                           
Income Before Income Taxes and Cumulative Effect of Change
                         
in Accounting Principle
   
7
   
24
   
20
   
49
 
                           
Income Taxes (Benefit)
   
(2
)
 
9
   
2
   
18
 
                           
Income Before Cumulative Effect of Change in Accounting
                         
Principle
   
9
   
15
   
18
   
31
 
                           
Cumulative Effect of Change in Accounting Principle,
                         
Net of Income Taxes of $-, $-, $- and $16
   
-
   
-
   
-
   
24
 
                           
Net Income
   
9
   
15
   
18
   
55
 
                           
Preferred Stock Dividends
   
-
   
-
   
1
   
1
 
                           
Net Income Available to Common Stockholder
 
$
9
 
$
15
 
$
17
 
$
54
 
                           
                           
The accompanying notes as they relate to CILCO are an integral part of these consolidated financial statements.
                           


  
25

 


CENTRAL ILLINOIS LIGHT COMPANY
 
CONSOLIDATED BALANCE SHEET
 
(Unaudited) (In millions)
 
           
   
September 30,
 
December 31,
 
   
2004
 
2003
 
ASSETS
         
Current Assets:
         
Cash and cash equivalents
 
$
5
 
$
8
 
Accounts receivable - trade (less allowance for doubtful
             
accounts of $4 and $6, respectively)
   
28
   
57
 
Unbilled revenue
   
17
   
35
 
Miscellaneous accounts and notes receivable
   
7
   
14
 
Materials and supplies, at average cost
   
77
   
69
 
Other current assets
   
5
   
5
 
Total current assets
   
139
   
188
 
Property and Plant, Net
   
1,145
   
1,101
 
Other Non-Current Assets
   
39
   
19
 
Regulatory Assets
   
13
   
16
 
TOTAL ASSETS
 
$
1,336
 
$
1,324
 
               
               
LIABILITIES AND STOCKHOLDER'S EQUITY
             
Current Liabilities:
             
Current maturities of long-term debt
 
$
-
 
$
100
 
Borrowings from money pool
   
193
   
149
 
Accounts and wages payable
   
71
   
101
 
Taxes accrued
   
2
   
13
 
Other current liabilities
   
45
   
30
 
Total current liabilities
   
311
   
393
 
Long-term Debt, Net
   
138
   
138
 
Preferred Stock Subject to Mandatory Redemption
   
20
   
21
 
Deferred Credits and Other Non-Current Liabilities:
             
Accumulated deferred income taxes, net
   
106
   
101
 
Accumulated deferred investment tax credits
   
10
   
11
 
Regulatory liabilities
   
174
   
167
 
Accrued pension and other postretirement benefits
   
121
   
128
 
Other deferred credits and liabilities
   
19
   
23
 
Total deferred credits and other non-current liabilities
   
430
   
430
 
Commitments and Contingencies (Note 9)
             
Stockholder's Equity:
             
Common stock, no par value, 20.0 shares authorized - 13.6 shares outstanding
   
186
   
186
 
Preferred stock not subject to mandatory redemption
   
19
   
19
 
Other paid-in capital
   
127
   
52
 
Retained earnings
   
103
   
95
 
Accumulated other comprehensive income (loss)
   
2
   
(10
)
Total stockholder's equity
   
437
   
342
 
TOTAL LIABILITIES AND STOCKHOLDER'S EQUITY
 
$
1,336
 
$
1,324
 
               
The accompanying notes as they relate to CILCO are an integral part of these consolidated financial statements.


  
26

 


CENTRAL ILLINOIS LIGHT COMPANY
 
CONSOLIDATED STATEMENT OF CASH FLOWS
 
(Unaudited) (In millions)
 
   
Nine Months Ended
 
   
September 30,
 
   
2004
 
2003
 
Cash Flows From Operating Activities:
         
Net income
 
$
18
 
$
55
 
Adjustments to reconcile net income to net cash
             
provided by operating activities:
             
Cumulative effect of change in accounting principle
   
-
   
(24
)
Depreciation and amortization
   
48
   
53
 
Deferred income taxes, net
   
13
   
(8
)
Deferred investment tax credits, net
   
(1
)
 
(1
)
Pension contribution
   
(41
)
 
-
 
Other
   
13
   
(4
)
Changes in assets and liabilities:
             
Receivables, net
   
54
   
7
 
Materials and supplies
   
(8
)
 
(10
)
Accounts and wages payable
   
(30
)
 
13
 
Taxes accrued
   
(11
)
 
(6
)
Assets, other
   
(17
)
 
6
 
Liabilities, other
   
46
   
19
 
Net cash provided by operating activities
   
84
   
100
 
               
Cash Flows From Investing Activities:
             
Construction expenditures
   
(95
)
 
(68
)
Other
   
1
   
1
 
Net cash used in investing activities
   
(94
)
 
(67
)
               
Cash Flows From Financing Activities:
             
Dividends on common stock
   
(10
)
 
(44
)
Dividends on preferred stock
   
(1
)
 
(1
)
Redemptions, repurchases, and maturities:
             
Short-term debt
   
-
   
(10
)
Long-term debt
   
(100
)
 
(105
)
Preferred stock
   
(1
)
 
(1
)
Issuances:
             
Borrowings from money pool
   
44
   
109
 
Capital contribution from parent
   
75
   
-
 
Net cash provided by (used in) financing activities
   
7
   
(52
)
               
Net change in cash and cash equivalents
   
(3
)
 
(19
)
Cash and cash equivalents at beginning of year
   
8
   
22
 
Cash and cash equivalents at end of period
 
$
5
 
$
3
 
               
Cash Paid During the Periods:
             
Interest
 
$
14
 
$
17
 
Income taxes, net paid (refunded)
   
(1
)
 
11
 
               
               
The accompanying notes as they relate to CILCO are an integral part of these consolidated financial statements.

 
27

 

AMEREN CORPORATION (CONSOLIDATED)
UNION ELECTRIC COMPANY (CONSOLIDATED)
CENTRAL ILLINOIS PUBLIC SERVICE COMPANY
AMEREN ENERGY GENERATING COMPANY
CILCORP INC. (CONSOLIDATED)
CENTRAL ILLINOIS LIGHT COMPANY (CONSOLIDATED)

COMBINED NOTES TO FINANCIAL STATEMENTS (UNAUDITED)
September 30, 2004

NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES 

General

Ameren, headquartered in St. Louis, Missouri, is a public utility holding company registered with the SEC under the PUHCA. Ameren’s primary asset is the common stock of its subsidiaries. Ameren’s subsidiaries operate rate-regulated electric generation, transmission and distribution businesses, rate-regulated natural gas distribution businesses and non rate-regulated electric generation businesses in Missouri and Illinois. Dividends on Ameren’s common stock are dependent on distributions made to it by its subsidiaries. Ameren’s principal operating subsidiaries are listed below. Also see Glossary of Terms and Abbreviations.

  • UE, also known as Union Electric Company, operates a rate-regulated electric generation, transmission and distribution business, and a rate-regulated natural gas distribution business in Missouri and Illinois. UE was incorporated in Missouri in 1922 and is successor to a number of companies, the oldest of which was organized in 1881. It is the largest electric utility in Missouri and supplies electric and gas service to a 24,500 square mile area located in central and eastern Missouri and west central Illinois. This area has an estimated population of 3 million and includes most of the greater St. Louis area. UE supplies electric service to approximately 1.2 million customers and natural gas service to approximately 130,000 customers. See Note 3 - Rate and Regulatory Matters for information regarding the propose d transfer of UE’s Illinois electric and natural gas transmission and distribution businesses to CIPS.
  • CIPS, also known as Central Illinois Public Service Company, operates a rate-regulated electric and natural gas transmission and distribution business in Illinois. CIPS was incorporated in Illinois in 1902. It supplies electric and gas utility service to portions of central and southern Illinois having an estimated population of 1 million in an area of approximately 20,000 square miles. CIPS supplies electric service to approximately 325,000 customers and natural gas service to approximately 170,000 customers.
  • Genco, also known as Ameren Energy Generating Company, operates a non rate-regulated electric generation business in Illinois and Missouri. Genco was incorporated in Illinois in March 2000, in conjunction with the Illinois Customer Choice Law. Genco commenced operations on May 1, 2000, when CIPS transferred its five coal-fired power plants and related liabilities to Genco at historical net book value. Genco is a subsidiary of Development Company, which is a subsidiary of Resources Company, which is a subsidiary of Ameren. See Note 3 - Rate and Regulatory Matters for information regarding the proposed transfer of Genco’s CTs located in Pinckneyville and Kinmundy, Illinois to UE.
  • CILCO, also known as Central Illinois Light Company, is a subsidiary of CILCORP (a holding company) and operates a rate-regulated electric transmission and distribution business, a primarily non rate-regulated electric generation business and a rate-regulated natural gas distribution business, all in Illinois. CILCO was incorporated in Illinois in 1913. It supplies electric and gas utility service to portions of central and east central Illinois in areas of approximately 3,700 and 4,500 square miles, respectively, with an estimated population of 1 million. CILCO supplies electric service to approximately 205,000 customers and natural gas service to approximately 210,000 customers. In October 2003, CILCO transferred its coal-fired plants and a CT facility, representing in the aggregate approximately 1,100 megawat ts of electric generating capacity, to a wholly owned subsidiary, known as AERG, as a contribution in return for all the outstanding stock of AERG and AERG’s assumption of certain liabilities. The net book value of the transferred assets was approximately $378 million and no gain or loss was recognized as the transaction was accounted for as a transfer between entities under common control. The transfer was made in conjunction with the Illinois Customer Choice Law. CILCORP was incorporated in Illinois in 1985.

 
 
28


  • IP, also known as Illinois Power Company, operates a rate-regulated electric and natural gas transmission and distribution business in Illinois. IP was incorporated in 1923 in Illinois. It supplies electric and gas utility service to portions of central, east central, and southern Illinois contiguous to our other service territories having an estimated population of 1.4 million in an area of approximately 15,000 square miles. IP supplies electric service to approximately 600,000 customers and natural gas service to approximately 415,000 customers, including most of the Illinois portion of the greater St. Louis area. Ameren completed its acquisition of IP on September 30, 2004. See Note 2 - Acquisitions for further information.
Ameren has various other subsidiaries responsible for the short and long-term marketing of power, procurement of fuel, management of commodity risks and providing other shared services. Ameren also has an 80% ownership interest in EEI through UE, which owns 40%, and Resources Company, which owns 40%. Ameren purchased Dynegy’s 20% ownership interest in EEI now held by Resources Company as part of the IP acquisition. See Note 2 - Acquisitions for further information. Ameren consolidates EEI for financial reporting purposes, while UE and Resources Company report EEI under the equity method.
 
The financial statements of Ameren are prepared on a consolidated basis and therefore include the accounts of its majority-owned subsidiaries. As the acquisition of IP occurred on September 30, 2004, Ameren’s accompanying consolidated Statements of Income and Cash Flows for the period ended September 30, 2004 do not reflect IP’s results. However, IP’s financial position at September 30, 2004, and the cash flows relating to the IP acquisition are included in Ameren’s Consolidated Balance Sheet at September 30, 2004, and Consolidated Statement of Cash Flows for the nine months ended September 30, 2004. Results of CILCORP and CILCO reflected in Ameren’s consolidated financial statements include the period from January 31, 2003, when these two companies were acquired. See Note 2 - Acquisitions for further information. All significant intercompany transactions have been eliminated. All tabular dollar amounts are in millions, unless otherwise indicated.

Our accounting policies conform to GAAP. Our financial statements reflect all adjustments (which include normal, recurring adjustments) necessary, in our opinion, for a fair presentation of our results. The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions. Such estimates and assumptions affect reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the dates of financial statements and the reported amounts of revenues and expenses during the reported periods. Actual results could differ from those estimates. The results of operations of an interim period may not give a true indication of results for a full year. Certain reclassifications have been made to prior year’s financial statements to con form to 2004 reporting. These statements should be read in conjunction with the financial statements and the notes thereto included in the Ameren Companies’ combined 2003 Annual Reports on Form 10-K and Quarterly Reports on Form 10-Q for the periods ended March 31 and June 30, 2004, as well as IP’s 2003 Annual Report on Form 10-K and Quarterly Reports on Form 10-Q for the periods ended March 31, June 30 and September 30, 2004.

Earnings Per Share

There were no differences between the basic and diluted earnings per share amounts for the three and nine month periods ended September 30, 2004 and 2003. Assumed stock option conversions increased the number of shares outstanding in the diluted earnings per share calculation by 172,158 shares for the three months ended September 30, 2004 (2003 - 283,769 shares) and 209,271 shares for the nine months ended September 30, 2004 (2003 - 273,914 shares). Ameren’s equity security units had no dilutive effect on earnings per share in 2003 and 2004. As only the Ameren parent company has publicly held common stock, earnings per share calculations are not relevant and are not presented for any of the subsidiaries of Ameren.

Accounting Changes and Other Matters

SFAS No.143 - “Accounting for Asset Retirement Obligations”

We adopted the provisions of SFAS No. 143, effective January 1, 2003. SFAS No. 143 provides the accounting requirements for asset retirement obligations associated with tangible, long-lived assets. Upon adoption of the standard, Ameren and Genco recognized a net after-tax gain of $18 million in the first quarter of 2003 for the cumulative effect of change in accounting principle. Prior to Ameren’s acquisition of CILCORP, predecessor CILCORP and CILCO recognized a net after-tax gain upon adoption of SFAS No. 143 in 2003 of $4 million and $24 million, respectively, for the cumulative effect of change in accounting principle. In addition, in accordance with SFAS No. 143, estimated future
 
 
29

 
 
removal costs associated with Ameren’s, UE’s, CIPS’, CILCORP’s and CILCO’s rate-regulated operations that had previously been embedded in accumulated depreciation were reclassified to a regulatory liability.
 
Asset retirement obligations at Ameren and UE increased by approximately $6 million during the quarter ended September 30, 2004, and $18 million during the nine months ended September 30, 2004, to reflect the accretion of obligations to their present value. Increases to Genco’s, CILCORP’s and CILCO’s asset retirement obligations were immaterial during these periods. Substantially all of this accretion was recorded as an increase to regulatory assets.

In June 2004, the FASB issued an exposure draft on a proposed interpretation of SFAS No. 143.  The FASB is expected to issue a final interpretation in the fourth quarter of 2004. Under the interpretation, a legal obligation to perform an asset retirement activity that is conditional on a future event is within the scope of SFAS No. 143. Accordingly, an entity would be required to recognize a liability for the fair value of an asset retirement obligation that is conditional on a future event if the liability's fair value can be estimated reasonably.  The exposure draft provides examples of conditional asset retirement obligations that may need to be recognized under the provisions of the interpretation, including asbestos removal.  This proposed interpretation could require accrual of additional liabilities by Ameren and its subsidiaries and could result in increased expense, which while not yet quantified, could be material. This proposed interpretation would be effective for us no later than December 31, 2005.

FIN No. 46 - “Consolidation of Variable Interest Entities”

In January 2003, the FASB issued FIN No. 46, which changed the consolidation requirements for special purpose entities (SPEs) and non-special purpose entities (non-SPEs) that meet the criteria for designation as variable interest entities (VIEs). In December 2003, the FASB revised FIN No. 46 (FIN No. 46R) to clarify certain aspects of FIN No. 46 and modify the effective dates of the new guidance. FIN No. 46R provides guidance on the accounting for entities that are controlled through means other than voting rights by another entity. FIN No. 46R requires a VIE to be consolidated by a company if that company is designated as the primary beneficiary.

The Ameren Companies do not have any interests in entities that are considered SPEs. FIN No. 46R was effective on March 31, 2004, for any interests the Ameren Companies held in non-SPEs. The adoption of FIN No. 46R did not have a material impact on the consolidated financial statements of the Ameren Companies. However, in connection with the adoption of FIN No. 46R, we have determined that the following significant variable interests are held by the Ameren Companies:

  • EEI. Ameren has an 80% ownership interest in EEI through UE’s 40% interest and Resources Company’s 40% interest. Under the FIN No. 46R model, Ameren, UE and Resources Company have a variable interest in EEI, and Ameren is the primary beneficiary. Accordingly, Ameren will continue to consolidate EEI, and UE will continue to account for its investment in EEI under the equity method of accounting. The maximum exposure to loss as a result of these variable interests in EEI is limited to Ameren’s, UE’s and Resources Company’s equity investments in EEI.
  • Tolling agreement. CILCO has a variable interest in Medina Valley through a tolling agreement to purchase steam, chilled water and electricity. We have concluded that CILCO is not the primary beneficiary of Medina Valley, and accordingly, CILCO does not consolidate Medina Valley. The maximum exposure to loss as a result of this variable interest in the tolling agreement is not material.
  • Leveraged lease and affordable housing partnership investments. Ameren, UE and CILCORP have investments in leveraged lease and affordable housing partnership arrangements that are variable interests. We have concluded that neither Ameren, UE nor CILCORP are the primary beneficiary of any of the VIEs related to these investments. The maximum exposure to loss as a result of these variable interests is limited to the investments in these arrangements. At September 30, 2004, Ameren and CILCORP had net investments in leveraged leases of $140 million and $114 million, respectively. At September 30, 2004, Ameren, UE and CILCORP had investments in affordable housing partnerships of $19 million, $7 million and $7 million, respectively.
Ameren acquired a variable interest in IP SPT with the acquisition of IP on September 30, 2004. IP has a variable interest in IP SPT, which was established in 1998 to issue TFNs. IP has indemnified and is liable to IP SPT in the event IP does not bill the applicable charges to its customers on behalf of IP SPT or does not remit the collection to IP SPT; however, the note holders are considered the primary beneficiaries of this special purpose trust. Accordingly, Ameren does not consolidate IP SPT.

 
 
30

 

FASB Staff Position SFAS No. 106-1 and FASB Staff Position SFAS No. 106-2 - “Accounting and Disclosure Requirements Related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003”

On December 8, 2003, the Medicare Prescription Drug, Improvement and Modernization Act of 2003 (the Prescription Drug Act) was enacted.  The Prescription Drug Act introduced a prescription drug benefit to retirees under Medicare as well as a federal subsidy to sponsors of retiree healthcare benefit plans that provide a benefit that is at least actuarially equivalent to the Medicare prescription drug benefit.  Through its postretirement benefit plans, Ameren provides retirees with prescription drug coverage that we believe is actuarially equivalent to the Medicare prescription drug benefit. In January 2004, the FASB issued FSP SFAS 106-1, which permitted a plan sponsor of a postretirement healthcare plan that provides a prescription drug benefit to make a one-time election to defer the accounting for the effects of the Prescription Drug Act.  We made this one-time election allowed by FSP SFAS 106-1.  

In May 2004, the FASB issued FSP SFAS 106-2, which superceded FSP SFAS 106-1. FSP SFAS 106-2 provides guidance on accounting for the effects of the Prescription Drug Act by employers whose prescription drug benefits are actuarially equivalent to the drug benefit under Medicare Part D. Ameren elected to adopt FSP SFAS 106-2 during the second quarter ended June 30, 2004, retroactive to January 1, 2004. See Note 12 - Pension and other Postretirement Benefits for additional information on the impact of adoption of FSP SFAS 106-2.

Interchange Revenues

The following table presents the interchange revenues included in Operating Revenues - Electric for the three months and nine months ended September 30, 2004 and 2003. See Note 8 - Related Party Transactions for information on sales among affiliates.
 

 
Three Months
Nine Months
 
2004
2003
2004
2003
Ameren(a)
$    95
$    79
$    267
$    264
UE
83
72
238
239
CIPS
8
10
27
28
Genco
38
34
113
107
CILCORP(b)
9
7
30
15
CILCO
9
7
30
15
(a)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003; includes amounts for Ameren registrant and non-registrant subsidiaries and intercompany eliminations.
(b)   2003 amounts include January 2003 predecessor information, which was $3 million. CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.

Purchased Power

The following table presents the purchased power expenses included in Operating Expenses - Fuel and Purchased Power for the three months and nine months ended September 30, 2004 and 2003. See Note 8 - Related Party Transactions for information on affiliate purchased power transactions.


 
Three Months
Nine Months
 
2004
2003
2004
2003
Ameren(a)
$    112
$    100
$    271
$    231
UE
56
49
 157
  140
CIPS
85
96
244
264
Genco
43
36
117
112
CILCORP(b)
9
60
39
157
CILCO
9
60
39
154
(a)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003; includes amounts for Ameren registrant and non-registrant subsidiaries and intercompany eliminations.
(b)   2003 amounts include January 2003 predecessor information, which was $12 million. CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.

Excise Taxes

Excise taxes reflected on Missouri electric and gas, and Illinois gas, customer bills are imposed on us and are recorded gross in Operating Revenues and Taxes Other than Income Taxes. Excise taxes reflected on Illinois electric customer bills are imposed on the consumer and are recorded as tax collections payable and included in Taxes Accrued.

 
 
31

 

The following table presents excise taxes recorded in Operating Revenues and Taxes Other than Income Taxes for the three months and nine months ended September 30, 2004 and 2003:

 
Three Months
Nine Months
 
2004
2003
2004
2003
Ameren(a)
$     35
$     40
$    100
$    102
UE
31
33
82
80
CIPS
2
2
9
10
Genco
-
-
-
-
CILCORP(b)
2
5
9
14
CILCO
2
5
9
14
(a)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003.
(b)   2003 amounts include January 2003 predecessor information which was $2 million. CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.


NOTE 2 - ACQUISITIONS

IP

On September 30, 2004, Ameren completed the acquisition of all the common stock and 662,924 shares of preferred stock of Decatur, Illinois-based IP and a 20% ownership interest in EEI from Dynegy and its subsidiaries. Ameren acquired IP to complement its existing Illinois gas and electric operations.   The purchase included IP's rate-regulated electric and natural gas transmission and distribution business serving approximately 600,000 electric and 415,000 gas customers in areas contiguous to our existing Illinois utility service territories. With the acquisition, IP became an Ameren subsidiary operating as AmerenIP. See Note 1 - Summary of Significant Accounting Policies for further information on the presentation of the results of IP in Ameren’s consolidated financial statements. For a discussion of the regulatory agency approvals granted in connection with this acquisition, see Note 3 - Rate and Regulatory Matters. 

The total transaction value was approximately $2.3 billion, including the assumption of approximately $1.8 billion of IP debt and preferred stock and consideration, including transaction costs of $451 million in cash, net of $51 million cash acquired, which, under the terms of the stock purchase agreement, is subject to a final working capital adjustment. Ameren placed $100 million of the cash portion of the purchase price in a six-year escrow pending resolution of certain contingent environmental obligations of IP and other Dynegy affiliates for which Ameren has been provided indemnification by Dynegy. See Note 9 - Commitments and Contingencies for information on a pending IP environmental matter to which the indemnification and escrow applies. In addition, this transaction included a fixed price capacity po wer supply agreement for IP’s annual purchase in 2005 and 2006 of 2,800 megawatts of electricity from a subsidiary of Dynegy. This agreement is expected to supply about 70% of IP’s electric customer requirements during those two years. IP is currently in the final stages of soliciting bids to supply the remaining 30% of its power needs in 2005 and 2006. This solicitation is expected to be completed by the end of 2004. In the event that any of these suppliers are unable to supply the electricity required by the agreements, IP would be forced to find alternative suppliers to meet its load requirements thus exposing IP to market price risk, which could have a material impact on Ameren's results of operationS Existing power supply contracts expire on December 31, 2004.
 
Ameren’s financing plan for funding this acquisition included the issuance of new Ameren common stock. Ameren issued an aggregate of approximately 30 million common shares in February 2004 and July 2004, which generated net proceeds of about $1.3 billion. Proceeds from these issuances were used to finance the cash portion of the purchase price and are expected to be used to reduce IP debt assumed as part of this transaction and to pay any related premiums. See Note 5 - Long-term Debt and Equity Financings for information on redemptions and a tender offer instituted with respect to certain IP bonds after the acquisition.

The following table presents the estimated fair values of the assets acquired and liabilities assumed at the date of Ameren’s acquisition of IP. Ameren is in the process of completing its valuations of the net assets and liabilities acquired, including the fixed price capacity power supply agreement discussed above, and obtaining third party valuations of property and plant, intangible assets, acquired debt and pension and other postretirement benefit obligations.  As a result, the allocation of the purchase price is preliminary and subject to further adjustment.  The fair value of IP's power supply agreements recorded a t the acquision date resulted in a $109 million liability, net. The excess of the purchase price for IP’s common stock and preferred stock over tangible net assets acquired has been allocated preliminarily to goodwill in the amount of $302 million, net of future tax benefits. For

 
 
32

 

 income tax purposes, we expect that a portion of the purchase price will be allocated to goodwill and that such portion will be deducted ratably over a 15-year period.
 

Current assets
 
$
375
 
Property and plant
   
1,967
 
Investments and other non-current assets
   
396
 
Goodwill
   
302
 
Total assets acquired
   
3,040
 
Current liabilities
   
219
 
Long-term debt, including current maturities
   
1,979
 
Other non-current liabilities
   
452
 
Total liabilities assumed
   
2,650
 
Preferred stock assumed
   
13
 
Net assets acquired
 
$
377
 

The following unaudited pro forma financial information presents a summary of Ameren’s consolidated results of operations for the three and nine months ended September 30, 2004 and 2003 assuming the acquisition of IP had been completed at the beginning of 2003, including pro forma adjustments, which are based upon preliminary estimates, to reflect the allocation of the purchase price to the acquired net assets. The pro forma financial information does not include cost savings that may result from the combination of Ameren and IP. 
 

For the periods ended September 30,
 
Three Months
 
Nine Months
 
   
2004
 
2003
 
2004
 
2003
 
Operating revenues
 
$
1,696
 
$
1,729
 
$
4,844
 
$
4,702
 
Income before cumulative effect of change in accounting
                         
principle
   
281
   
317
   
550
   
558
 
Cumulative effect of change in account principle, net of
                         
taxes
   
-
   
-
   
-
   
16
 
Net income
 
$
281
 
$
317
 
$
550
 
$
574
 
Earnings per share - basic
  $
1.45
  $
1.65
  $
2.84
  $
3.01
 
                                 - diluted
   
1.45
 
1.65
 
2.84
 
3.01
 

This pro forma information is not necessarily indicative of the results of operations as they would have been had the transaction been effected on the assumed date, nor is it an indication of trends in future results.

The portion of the total transaction value attributable to Ameren’s acquisition of Dynegy’s 20% ownership interest in EEI was $125 million. The excess of the purchase price for this ownership interest over 20% of EEI’s net assets acquired has been preliminarily allocated to goodwill in the amount of $112 million and is subject to change based on our final valuation.
 
CILCORP and Medina Valley

On January 31, 2003, Ameren completed the acquisition of all of the outstanding common stock of CILCORP from AES. CILCORP is the parent company of Peoria, Illinois-based CILCO. With the acquisition, CILCO became an indirect Ameren subsidiary, but remains a separate utility company, operating as AmerenCILCO. On February 4, 2003, Ameren also completed the acquisition from AES of Medina Valley, which indirectly owns a 40 megawatt, gas-fired ele ctric generation plant. The results of operations for CILCORP and Medina Valley were included in Ameren’s consolidated financial statements effective with the respective January and February 2003 acquisition dates.

 
 
33

 

The purchase price allocation for the acquisition of CILCORP and Medina Valley was finalized in January 2004.  As a result, goodwill decreased by $8 million since December 31, 2003, primarily due to January 2004 adjustments to property and plant, income tax accounts and accrued severance expenses. The following table presents the final estimated fair values of the assets acquired and liabilities assumed at the dates of our acquisitions of CILCORP and Medina Valley.
 

Current assets
 
$
323
 
Property and plant
   
1,162
 
Investments and other non-current assets
   
154
 
Specifically-identifiable intangible assets
   
6
 
Goodwill
   
560
 
Total assets acquired
   
2,205
 
Current liabilities
   
189
 
Long-term debt, including current maturities
   
937
 
Other non-current liabilities
   
521
 
Total liabilities assumed
   
1,647
 
Preferred stock assumed
   
41
 
Net assets acquired
 
$
517
 

Specifically identifiable intangible assets of $6 million are comprised of retail customer contracts, which are subject to amortization with an average life of 10 years. Goodwill of $560 million (CILCORP - $553 million; Medina Valley - $7 million) was recognized in connection with the CILCORP and Medina Valley acquisitions. None of this goodwill is expected to be deductible for tax purposes.


NOTE 3 - RATE AND REGULATORY MATTERS 

IP Acquisition

The following regulatory agency approvals were granted in connection with Ameren’s acquisition, on September 30, 2004, of IP and a 20% interest in EEI from Dynegy and its subsidiaries.

In April 2004, the FCC consented to the transfer of control of FCC licenses held by IP to Ameren.

In April 2004, the initial 30 calendar day waiting period expired without a request by the FTC or DOJ for additional information or documents under the Hart-Scott-Rodino Act.

In July 2004, the FERC issued an order approving Ameren’s acquisition of IP and Dynegy’s interest in EEI. The principal conditions of the FERC’s approval were that IP join the Midwest ISO prior to closing the transaction and that 125 megawatts of EEI’s power be sold to a non-affiliate of Ameren. The Missouri Office of Public Counsel and a group of electric industrial customers of UE, both intervenors in the FERC proceeding, have requested the FERC to reconsider its order deferring to the MoPSC on the question of whether UE should be required to preserve its current entitlement to the output of EEI’s Joppa power plant facility. These appeals, which are pending, did not impede the completion of the acquisition on September 30, 2004. IP joined the Midwest ISO on September 30, 2004.

On September 22, 2004, the ICC issued an order approving Ameren’s acquisition of IP. The order contains several important provisions including the following:
  • The order requires IP to submit quarterly reports in 2005 and 2006 on certain milestones regarding IP’s progress in achieving an estimated $33 million in annual synergies by the beginning of 2007, and provides for adjustments in IP’s next electric and gas rate cases if IP fails to achieve those milestones.
  • After 2006, IP will recover over four years through rates $67 million in reorganization costs related to the integration of IP into the Ameren system and the restructuring of IP.
  • The order approves a tariff rider to recover the costs of asbestos-related litigation claims, subject to the following terms: beginning in 2007, 90% of cash expenditures in excess of the amount included in base electric rates will be recovered by IP from a $20 million trust fund established by IP and financed with contributions of $10 million each by Ameren and Dynegy; if cash expenditures are less than the amount in base rates, IP will contribute 90% of the difference to the fund; once the trust fund is depleted, 90% of allowed cash expenditures in excess of base rates will be recovered through charges assessed to customers under the tariff rider.

 
 
34

 


  • The order provides IP with the ability to declare and pay $80 million of dividends on its common stock in 2005 and $160 million of dividends on its common stock cumulatively through 2006, provided IP has achieved an investment grade credit rating from S&P or Moody’s. If, however, IP’s principal amount of mortgage bonds 11.50% Series due 2010 are not eliminated by December 31, 2006, IP may not thereafter declare or pay common dividends without seeking authority from the ICC.
  • Ameren commits to cause an aggregate of at least $750 million principal amount of IP’s long-term debt, including IP’s principal amount of mortgage bonds 11.50% Series due 2010, to be redeemed, repurchased or retired on or before December 31, 2006. Ameren will contribute a substantial amount of common equity into IP for this purpose and will cause IP’s common equity to total capitalization ratio to range between 50% to 60% by December 31, 2006.
  • IP will establish a dividend policy comparable to the dividend policy of Ameren’s other Illinois utilities consistent with achieving and maintaining a common equity to total capitalization ratio between 50% to 60%.
  • Ameren will commit IP to make between $275 million and $325 million in energy infrastructure investments over its first two years of ownership.
  • IP employees, retirees and those retirees’ surviving dependents will remain in their current IP benefit plans or be moved into appropriate Ameren benefit plans, and IP will honor all existing labor agreements.
On September 27, 2004, the SEC issued an order under the PUHCA approving Ameren’s acquisition of IP without material conditions.

Intercompany Transfer of Electric Generating Facilities and Illinois Service Territory

As a part of the settlement of the Missouri electric rate case in 2002, UE committed to making certain infrastructure investments from January 1, 2002 through June 30, 2006 of $2.25 billion to $2.75 billion, including the addition of 700 megawatts of generation capacity. The new capacity requirement is expected to be satisfied by the addition in 2002 of 240 megawatts and the proposed transfer from Genco to UE, at net book value (approximately $240 million), of approximately 550 megawatts of CTs at Pinckneyville and Kinmundy, Illinois. In July 2004, the FERC approved the generation transfer, but the transfer remains subject to receipt of SEC approval under the PUHCA. Approval by the ICC is not required contingent upon prior approval and execution of UE’s transfer of its Illinois public utility operations to CI PS as discussed below. Approval by the MoPSC is not required in order for this transfer of generating capacity to occur. However, the MoPSC has jurisdiction over UE’s ability to recover the cost of the transferred generating facilities from its electric customers in its rates. As part of the settlement of the Missouri electric rate case in 2002, UE is subject to a rate moratorium providing for no changes in its electric rates before June 30, 2006, subject to certain statutory and other exceptions.

In May 2003, UE announced its plan to limit its public utility operations to the state of Missouri and to discontinue operating as a public utility subject to ICC regulation. UE is seeking to accomplish this by transferring its Illinois-based electric and natural gas businesses, including its Illinois-based distribution assets and certain of its transmission assets, at net book value, to CIPS. In 2003, UE’s Illinois electric and gas service territory generated revenues of $155 million and had a net book property and plant value of approximately $125 million at September 30, 2004. UE's electric generating facilities and a certain minor amount of its electric transmission facilities in Illinois would not be part of the transfer. UE proposes to transfer approximately one-half of the assets directly to CIPS in co nsideration for a CIPS subordinated promissory note, and approximately one-half of the assets by means of a dividend in kind to Ameren followed by a capital contribution by Ameren to CIPS. The transfer was approved by the FERC in December 2003. In September 2004, the ICC authorized the transfer of UE’s Illinois-based natural gas utility business. The ICC had previously authorized the transfer of UE’s Illinois-based electric utility business to CIPS in 2000. As discussed below, the MoPSC, by an order issued in October 2004, approved the transfer subject to various conditions. The transfer of UE's Illinois-based utility businesses will also require the approval of the SEC under the provisions of the PUHCA. A filing seeking approval of both the transfer of UE’s Illinois-based utility businesses and Genco’s CTs was made with the SEC in October 2003. If completed, the transfers will be accounted for at book value with no gain or loss recognition, which is appropriate treatment for transactions of this type by two entities under common control.

After the completion of hearings and submission of briefs, on October 6, 2004, the MoPSC issued an order, effective October 16, 2004, approving UE's transfer of its Illinois-based utility businesses to CIPS subject to various
 
 
35

 

conditions. The principal conditions included in the order would prevent UE from recovering in rates costs related to certain pre-transfer generation-related liabilities and require amendments to the joint generation dispatch agreement among UE, Genco and CIPS. On October 15, 2004, UE filed an application for rehearing requesting the MoPSC to rehear or in the alternative, clarify its order. See Note 8 - Related Party Transactions for a discussion of an amendment to the joint dispatch agreement, which was proposed to address concerns raised before the MoPSC in this proceeding. This Note also discusses the conditions with respect to the joint dispatch agreement imposed by the MoPSC in its October 6, 2004, order.

We are unable to predict the ultimate outcome of these regulatory proceedings or the timing of the final decisions of the various agencies.

Federal - Electric Transmission

Regional Transmission Organization 

In December 1999, the FERC issued Order 2000 requiring all utilities subject to FERC jurisdiction to state their intentions for joining a RTO. The MoPSC issued an order in early 2004 authorizing UE to participate in the Midwest ISO for a five year period, with participation after that period subject to further approvals by the MoPSC. Subsequently, the FERC issued a final order allowing UE’s and CIPS’ participation in the Midwest ISO. Under these orders, the MoPSC continues to set the transmission component of UE’s rates to serve its bundled retail load. CILCO is already a member of the Midwest ISO and transferred functional control of its transmission system to the Midwest ISO prior to our acquisition of CILCO. Genco does not own transmission assets, but pays the Midwest ISO to use the transmission system to transmit power from the Genco generating plants.

On May 1, 2004, functional control, but not ownership, of the UE and CIPS transmission systems was transferred to the Midwest ISO through GridAmerica LLC. On September 30, 2004, prior to the completion of Ameren’s acquisition of IP as required by the FERC’s order approving the acquisition, IP transferred functional control, but not ownership, of its transmission system to the Midwest ISO. The transfer had no accounting impact to UE, CIPS and IP because they continue to own the transmission system assets. The participation by UE, CIPS and IP in the Midwest ISO is expected to increase annual costs by $10 million to $25 million in the aggregate and could result in a decrease in annual revenues of between $5 million and $15 million in the aggregate based on the Midwest ISO’s tariff structure. However, a ccess to the Midwest ISO market could provide UE, Genco and CILCO an opportunity to sell more, and higher margin, excess power. UE, CIPS, CILCO and IP may also be required to expand their transmission systems according to decisions made by the Midwest ISO rather than their internal planning process.

As a part of the transfer of functional control of UE’s and CIPS’ transmission systems to the Midwest ISO, Ameren received $26 million, which represented the refund of the $13 million exit fee paid by UE and the $5 million exit fee paid by CIPS, which were expensed when they left the Midwest ISO in 2001, plus $1 million interest on the exit fees and the reimbursement of $7 million that was invested in the proposed Alliance RTO.  These refunds resulted in after-tax gains of approximately $11 million, $8 million and $3 million for Ameren, UE and CIPS, respectively, which were recorded in other operations and maintenance expenses during the quarter ended June 30, 2004.  As part of the transfer of functional control of IP’s transmission system to the Midwest ISO, at the end of September 2004, IP also received a refund of its Midwest ISO exit fee and RTO development costs. This refund was provided to Dynegy pursuant to the terms of the stock purchase agreement covering Ameren’s acquisition of IP.

Through orders issued during late 2003 and early 2004, the FERC had ordered the elimination of regional through-and-out rates assessed by the Midwest ISO on transmission service between the Midwest ISO and PJM regions, to be effective May 1, 2004. However, in March 2004, the FERC accepted an agreement among affected transmission owners that retains the regional through-and-out rates until December 1, 2004, and provides for continued negotiations aimed at developing a long-term transmission pricing structure to eliminate seams between the PJM and Midwest ISO regions based on specified pricing principles. Until the long-term transmission pricing structure has been established, UE, CIPS, CILCO and IP cannot predict the ultimate impact that such structure will have on their costs and revenues.
 
In March 2004, the Midwest ISO tendered for filing at the FERC a proposed Open Access Transmission and Energy Markets Tariff (the “Energy Markets Tariff”), which is intended to supercede its existing OATT. The Energy Markets Tariff establishes rates, terms and conditions necessary for implementation of a centralized security-constrained

 
 
36

 

economic dispatch platform supported by a day-ahead and real-time energy market design, including Locational Marginal-Cost Pricing and Financial Transmission Rights for transmission service within the Midwest ISO region. The Energy Markets Tariff also establishes market monitoring and mitigation procedures and codifies existing resource adequacy requirements placed on Midwest ISO members by their states or applicable RRO. The Midwest ISO initially proposed to make the Energy Markets Tariff effective on December 1, 2004, subject to its ability to implement the Energy Markets Tariff. However, implementation of the Energy Markets Tariff is now expected to be effective on March 1, 2005. On August 6, 2004, the FERC accepted the Mi dwest ISO’s Energy Markets Tariff subject to further compliance filings. On November 8, 2004, the FERC issued an order denying the requests for rehearing that were filed by a number of Midwest ISO stakeholders including Ameren.  However, a final order from the FERC on the compliance filings made by the Midwest ISO in response to the FERC's August 6 order is still pending.  At this time, Ameren is unable to determine the full impact that the Energy Markets Tariff will have until further information is available regarding the implementation of the Energy Markets Tariff.
 
Until UE, CIPS, CILCO and IP achieve some degree of operational experience participating in the Midwest ISO, we are unable to predict the ultimate impact that such participation or ongoing RTO developments at the FERC or other regulatory authorities will have on our financial position, results of operations or liquidity.

New Market Power Analysis Screen Order

In an order issued in April 2004, the FERC replaced the Supply Margin Assessment Screen previously used to review applications by sellers of electricity at wholesale for authorization to sell power at market-based rates with two alternative measures of market power: (a) an uncommitted pivotal supplier analysis and (b) an uncommitted market share analysis which is to be prepared on a seasonal basis. If an applicant passes both screens, a rebuttable presumption will exist that it lacks generation market power. If the applicant fails either screen, a rebuttable presumption will exist that it has market power. Under such circumstances, the applicant may either seek to rebut the presumption by preparing a delivered price test (identifying the amount of economic capacity from neighboring areas that can be delivered to t he control area) or propose mitigation measures. Unless some other mitigation measure is adopted, the applicant’s authority to sell power at market-based rates in areas in which it has market power will be revoked, and the applicant will be required to sell at cost-based rates in those areas.

UE, Genco, CIPS, CILCO, AERG, Development Company, Marketing Company and Medina Valley currently have authorization from the FERC to continue to sell power at market-based rates. However, the FERC indicated in its April 2004 order that it would apply the new market analysis screens to pending and future market-based rate applications, including three-year market-based rate reviews. All of the aforementioned Ameren entities currently have three-year market-based rate reviews pending at the FERC.

As required, these Ameren companies will file an updated market power analysis with FERC in December 2004.  This updated analysis will include the results of FERC’s new screens.  These companies will apply the new screens both on the basis of individual control area markets and also on the basis of the entire Midwest ISO footprint.  We understands that the individual control area analyses will be applicable for a limited time until Midwest ISO implements its "Day 2" markets, now scheduled for March 1, 2005, and that the Midwest ISO footprint analyses will be applicable after that time.  We expects that UE and AERG it will fail one of the new screens, the wholesale market share screen, in the UE/CIPS and CILCO control areas, respectively, but pass it in all other control areas and pass the other new screen measure, the pivotal supplier screen, in all of the individual control areas that we are required to study.  We further anticipates that we will pass both screen measures for the larger market consisting of the entire Midwest ISO footprint.  We are unable to anticipate how or when FERC will respond to any screen failure by an Ameren company for the interim period before the start of Midwest ISO Day 2 markets.  Further, until we have finalized our updated analysis, we are unable to predict how the FERC will resolve a number of related issues, including resolution of evidence available to rebut any screen results indicating a failure, and resolution of any proposed mitigation measures.  Finally, we are unable to predict the ultimate impact the new screens will have on our ability to sell power at market-based rates.

Illinois Gas

In June 2004, IP filed with the ICC seeking authority to raise its natural gas delivery rates by approximately $40 million annually. In August 2004, IP filed supplemental testimony, which revised the requested rate increase to approximately $36 million annually. Testimony on this matter was filed by the ICC staff in early November 2004, and hearings are scheduled for January 2005. If approved by the ICC, new rates are expected to go into effect in Spring 2005.  In the order approving Ameren's acquisition of IP, the ICC prohibits IP from filing for any proposed increase in gas delivery rates to be effective prior to January 1, 2007, beyond IP's pending request for a gas delivery rate increase.
 
 
 
 
37

 
 

NOTE 4 - SHORT-TERM BORROWINGS AND LIQUIDITY 

Short-term borrowings typically consist of commercial paper issuances and drawings under committed bank credit facilities with maturities generally within 1 to 45 days. As of September 30, 2004, certain Ameren subsidiaries had short-term borrowings totaling $30 million, $28 million of which was borrowed by EEI. The average short-term borrowings for Ameren and its subsidiaries were $16 million for the nine months ended September 30, 2004, with a ighted-average interest rate of 1.8%. Peak short-term borrowings for Ameren and its subsidiaries were $44 million for the nine months ended September 30, 2004, with an interest rate of 1.7%. UE, CIPS, Genco, CILCORP and CILCO had no external short-term borrowings as of September 30, 2 004 and CIPS, Genco, CILCORP and CILCO had no external short-term borrowings at December 31, 2003. At December 31, 2003, Ameren on a consolidated basis and UE had short-term borrowings outstanding, which totaled $161 million and $150 million, respectively. At the completion of the acquisition of IP on September 30, 2004, IP had no external short-term borrowings outstanding.

In July 2004, Ameren entered into two new credit agreements for a total of $700 million in revolving credit facilities to be used for general corporate purposes, including support of Ameren and UE commercial paper programs. The $700 million in new facilities includes a $350 million three-year revolving credit facility and a $350 million five-year revolving credit facility. These new credit facilities replaced Ameren’s existing $235 million 364-day revolving credit facility, which matured on July 14, 2004, and a $130 million multi-year revolving credit facility, which would have matured in July 2005. In September 2004, an existing Ameren $235 million multi-year revolving facility, which matures in July 2006, was amended and restated to accommodate Ameren’s acquisition of IP and to conform with its two cre dit agreements entered into in July 2004.

At September 30, 2004, certain of the Ameren Companies had committed bank credit facilities totaling $1,164 million, all of which were available for use, subject to applicable regulatory short-term borrowing authorizations, by UE, CIPS, CILCO, IP and Ameren Services through a utility money pool arrangement. In addition, $935 million of the $1,164 million was available for use, subject to applicable regulatory short-term borrowing authorizations, by Ameren directly, and by most of the non rate-regulated affiliates including, but not limited to, Resources Company, Genco, Marketing Company, AFS, AERG and Ameren Energy, through a non state-regulated subsidiary money pool agreement. We have money pool agreements with and among our subsidiaries to coordinate and provide for certain short-term cash and working capital re quirements. Separate money pools are maintained between rate-regulated and non rate-regulated entities. On September 30, 2004, our utility money pool agreement was amended to add IP as a party. Also, on September 30, 2004, a unilateral borrowing agreement was entered into between Ameren, IP and Ameren Services, which enables IP to make short-term borrowings directly from Ameren. The aggregate amount of borrowings outstanding at any time by IP under the unilateral borrowing agreement and the utility money pool agreement may not exceed $500 million pursuant to authorization from the ICC and the SEC under the PUHCA. Ameren Services is responsible for operation and administration of the agreement. See Note 8 - Related Party Transactions for further discussion of the money pool arrangements and the unilateral borrowing agreement. The committed bank credit facilities are used to support our commercial paper programs under which there were no amounts outstanding at September 30, 2004 (December 31, 2003 - $150 milli on). Access to our credit facilities for any of Ameren’s subsidiaries is subject to reduction based on use by affiliates.

In April 2004, UE renewed, for an additional one-year term, its $75 million 364-day revolving facility that was due to expire that month.

EEI also has two committed bank credit agreements totaling $45 million with maturities through June 2005. At September 30, 2004, $28 million was borrowed and outstanding under these credit facilities.

Borrowings under Ameren’s non state-regulated subsidiary money pool agreement by Genco, Development Company and Medina Valley, each an “exempt wholesale generator,” are considered investments for purposes of the 50% SEC aggregate investment limitation. Based on Ameren’s aggregate investment in these “exempt wholesale generators” as of September 30, 2004, the maximum permissible borrowings under Ameren’s non state-regulated subsidiary money pool pursuant to this limitation for these entities were $508 million.


 
 
38

 
Indebtedness Provisions and Other Covenants

Certain of the Ameren Companies’ bank credit agreements contain provisions which, among other things, place restrictions on the ability to incur liens, sell assets and merge with other entities. Certain of these credit agreements also contain a provision that limits Ameren’s, UE’s, CIPS’, and CILCO’s total indebtedness to 60% of total capitalization pursuant to a calculation defined in the related agreement. As of September 30, 2004, the ratio of total indebtedness to total capitalization (calculated in accordance with this provision) for each of Ameren, UE, CIPS and CILCO was 52%, 43%, 51% and 44%, respectively. From and after March 31, 2005, IP's total indebtedness will also be limited by this provision. In addition, certain of these credit agreements contain indebtedness cross-defa ult provisions and material adverse change clauses which could trigger a default under these facilities in the event that any of Ameren’s subsidiaries (subject to the definition in the underlying credit agreements), other than certain project finance subsidiaries, defaults in indebtedness in excess of $50 million. The credit agreements also require us to meet minimum ERISA funding rules.

None of the Ameren Companies’, IP’s or EEI's credit agreements or financing agreements contain credit rating triggers. A $100 million CILCO bank term loan containing a credit ratings trigger was repaid in February 2004. At September 30, 2004, the Ameren Companies, IP and EEI were in compliance with their credit agreement provisions and covenants.
 
NOTE 5 - LONG-TERM DEBT AND EQUITY FINANCINGS

Ameren

In February 2004, Ameren issued, pursuant to an August 2002 SEC Form S-3 shelf registration statement, 19.1 million shares of its common stock at $45.90 per share for net proceeds of $853 million. This issuance substantially depleted all of the capacity under the August 2002 shelf registration statement. In June 2004, the SEC declared effective a Form S-3 shelf registration statement filed by Ameren covering the offering from time to time of up to $2 billion of various types of securities including long-term debt, trust preferred securities and equity securities. In July 2004, Ameren issued, pursuant to the June 2004 Form S-3 shelf registration statement, 10.9 million shares of its common stock at $42.00 per share for net proceeds of $445 million. The proceeds from both these offerings were used to pay the cash po rtion of the purchase price for our acquisition of IP and Dynegy's 20% interest in EEI and, as described below, are expected to be used to reduce IP debt assumed as part of the acquisition and to pay any related premiums. See Note 2 - Acquisitions for further information.

Ameren may sell all, or a portion of the remaining securities registered under the June 2004 shelf registration statement if warranted by market conditions and capital requirements. Any offer and sale will be made only by means of a prospectus meeting the requirements of the Securities Act of 1933 and the rules and regulations thereunder. At October 31, 2004, the amount remaining under the June 2004 shelf registration statement was $1.5 billion.

In March 2004, the SEC declared effective a Form S-3 registration statement filed by Ameren in February 2004, authorizing the offering of six million additional shares of its common stock under DRPlus. Shares of common stock sold under DRPlus are, at Ameren’s option, newly issued shares or treasury shares, or shares purchased in the open market or in privately negotiated transactions. Ameren is currently selling newly issued shares of its common stock under DRPlus. For the nine months ended September 30, 2004, Ameren issued 1.8 million new common shares valued at approximately $84 million under its DRPlus and its 401(k) plans to be used for general corporate purposes.

The purchase of IP on September 30, 2004, included the assumption of IP debt and preferred stock at closing of approximately $1.8 billion. The assumed debt and preferred stock included $936 million of mortgage bonds, $509 million of pollution control indebtedness supported by mortgage bonds, $352 million of TFNs issued by IP SPT and $13 million of preferred stock. Upon acquisition, total IP debt was increased to fair value by approximately $191 million which included early debt redemption premiums. The adjustment to the fair value of each debt series is being amortized over its remaining life, or to the expected redemption date, to interest expense.

In October 2004, pursuant to an equity clawback provision of the related bond indenture, IP unconditionally called for redemption on November 15, 2004, $192.5 million in principal amount of its mortgage bonds 11.50% Series due 2010 at a price equal to $1,115 per $1,000 principal amount of bonds, together with accrued and unpaid interest to, but not
 
 
39

 

including, the redemption date. Ameren made an equity contribution of $250 million into IP to provide funds for this purpose and to satisfy indenture provisions related to the equity clawback. Also in October 2004, IP made a cash tender offer for any and all of the remaining outstanding mortgage bonds 11.50% Series due 2010 bonds ($357.5 million in aggregate principal amount). The purchase price will be determined, as described in the offer to purchase, in accordance with standard market practice by reference to a yield of 50 basis points over the yield on the 2.625% U.S. Treasury Note due November 15, 2006, on the price determination date, scheduled for November 18, 2004. The tender offer is scheduled to expire on November 22, 2004. This tender offer is also intended to satisfy IP’s indenture obligation to of fer to purchase the bonds resulting from the change of control of IP upon its acquisition by Ameren.  Any such bonds tendered will be purchased with cash contributed as equity to IP by Ameren.

In addition, in October 2004, IP called for redemption on December 1, 2004, the following indebtedness: (i) all $65.6 million principal amount of its outstanding 7.50% Series due 2025 mortgage bonds at a redemption price of 103.105% of the principal amount plus accrued interest and (ii) all $84.2 million principal amount of the Illinois Development Finance Authority’s Pollution Control Refunding Revenue Bonds, 1994 7.40% Series B due 2024 at a redemption price of 102% of the principal amount plus accrued interest. This indebtedness will be redeemed with cash contributed as equity to IP by Ameren.

UE

UE had a lease agreement, which was scheduled to expire on August 31, 2031, that provided for the financing of a portion of its nuclear fuel that was processed for use or was consumed at UE’s Callaway nuclear plant. In February 2004, UE terminated this lease with a final payment of $67 million.

In February and March 2004, in connection with the delivery of bond insurance policies to secure the environmental improvement and pollution control revenue bonds (Series 1991, 1992, 1998A, 1998B, 1998C, 2000A, 2000B and 2000C) previously issued by the Missouri Environmental Authority, UE delivered separate series of its first mortgage bonds (which are subject to fallaway provisions, as defined in the related financing agreements, similar to those included in its first mortgage bonds which secure UE’s senior secured notes) to secure its respective obligations under the existing loan agreements with the Missouri Environmental Authority relating to such environmental improvement and pollution control revenue bonds. As a result, the environmental improvement and poll ution control revenue bonds were rated Aaa, AAA and AAA by Moody’s, S&P and Fitch, respectively.

In May 2004, UE issued, pursuant to the September 2003 SEC Form S-3 shelf registration statement, $104 million of 5.50% senior secured notes due May 15, 2014, with interest payable semi-annually on May 15 and November 15 of each year beginning in November 2004. UE received net proceeds of $103 million, which were used along with other funds to redeem its $100 million 7% first mortgage bonds due 2024.

In September 2004, UE issued, pursuant to the September 2003 SEC Form S-3 shelf registration statement, $300 million of 5.10% senior secured notes due October 1, 2019, with interest payable semi-annually on April 1 and October 1 of each year beginning in April 2005. UE received net proceeds of approximately $298 million, which were used to repay short-term debt temporarily incurred to fund the maturity of UE’s $188 million 6.875% first mortgage bonds on August 1, 2004 and to repay other short-term debt which consisted of borrowings under the utility money pool arrangement.

UE may sell all, or a portion of, the remaining securities registered under the September 2003 shelf registration statement if warranted by market conditions and capital requirements. Any offer and sale will be made only by means of a prospectus meeting the requirements of the Securities Act of 1933 and the rules and regulations thereunder. At October 31, 2004, the amount remaining under the September 2003 shelf registration statement was $396 million.
 
CILCORP

In May 2004, CILCORP repurchased $15 million in principal amount of its 9.375% senior bonds and in July 2004, repurchased an additional $2 million in principal amount of these bonds. In conjunction with these debt repurchases, the fair value adjustment on these bonds was reduced by $5 million for the nine months ended September 30, 2004.


 
 
40

 

The amortization related to debt fair value adjustments recorded in connection with the CILCORP acquisition for the three month and nine month periods ended September 30, 2004, was $2 million (2003 - $2 million) and $6 million (2003 - $5 million), respectively, and was recorded in interest expense in the Consolidated Statements of Income for Ameren and CILCORP.

CILCO

In February 2004, CILCO repaid its secured bank term loan totaling $100 million with available cash and borrowings from the utility money pool. In July 2004, CILCO redeemed 11,000 shares of its 5.85% Class A preferred stock at a redemption price of $100 per share plus accrued and unpaid dividends. The redemption satisfied CILCO’s mandatory sinking fund redemption requirement for this series of preferred stock for 2004.

EEI

In June 2004, EEI repaid its $40 million 7.61% bank term loan due 2004 with proceeds received from EEI’s credit facilities.

Amortization of Interest-related Costs

The following table presents the amortization of debt issuance costs, fair value adjustments and any premium or discounts included in interest expense for the Ameren Companies for the three months and nine months ended September 30, 2004 and 2003, respectively:
 

   
                                       Three Months
 
Nine Months
 
   
                                      2004
 
2003
 
2004
 
2003
 
Ameren(a)(c)
       
$
5
 
$
5
 
$
15
 
$
13
 
UE
         
2
   
1
   
4
   
3
 
CIPS
         
1
   
1
   
1
   
1
 
Genco
         
-
   
-
   
1
   
1
 
CILCORP(b)(c)
         
2
   
3
   
6
   
6
 
CILCO
         
1
   
-
   
1
   
-
 
(a)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003; includes amounts for Ameren registrant and non-registrant subsidiaries and intercompany eliminations.
(b)   January 2003 predecessor amounts were zero. CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.
(c)   In conjunction with the acquisition of CILCORP in 2003, CILCORP’s long-term debt was adjusted to fair value.

Indenture Provisions and Other Covenants

UE

UE’s indenture agreements and articles of incorporation include covenants and provisions related to the issuance of first mortgage bonds and preferred stock. For the issuance of additional first mortgage bonds, earnings coverage of twice the annual interest charges on first mortgage bonds outstanding and to be issued is required. For the 12 months ended September 30, 2004, UE had a coverage ratio of 8.1 times the annual interest charges on the first mortgage bonds outstanding, which would permit UE to issue an additional $3.8 billion of first mortgage bonds at an assumed interest rate of 7%. For the issuance of additional preferred stock, earnings coverage of at least 2.5 times the annual dividend on preferred stock outstanding and to be issued is required under UE’s articles of incorporation. For the 12 months ended September 30, 2004, UE had a coverage ratio of 66.1 times the annual dividend requirement on preferred stock outstanding, which would permit UE to issue an additional $2.1 billion in preferred stock at an assumed dividend rate of 7%. The ability to issue such securities in the future will depend on such coverage ratios at that time.

In addition, UE’s mortgage indenture contains certain provisions which restrict the amount of common dividends that can be paid by UE. Under this mortgage indenture, $31 million of total retained earnings was restricted against the payment of common dividends, except for those dividends payable in common stock, leaving $1.7 billion of free and unrestricted retained earnings at September 30, 2004.

CIPS

CIPS’ indenture agreements and articles of incorporation include covenants which must be complied with in order to issue first mortgage bonds and preferred stock. For the issuance of additional first mortgage bonds, earnings coverage
 
 
41

 
 
of twice the annual interest charges on first mortgage bonds outstanding and to be issued is required except in certain cases when additional first mortgage bonds are issued on the basis of retired bonds.  For the 12 months ended September 30, 2004, CIPS had a coverage ratio of 3.77 times the annual interest charges for one year on the aggregate amount of first mortgage bonds outstanding and, subsequently, the most restrictive test under the indenture agreements would allow CIPS to issue an additional $126 million of first mortgage bonds. For the issuance of additional preferred stock, earnings coverage of 1.5 times annual interest charges on all long-term debt outstanding and the annual preferred stock dividends is required under CIPS’ articles of incorporation. For the 12 months ended September 30, 2004, CIPS had a coverage ratio of 2.08 times the sum of the annual interest charges and dividend requirements on all long-term debt and preferred stock outstanding as of Septemb er 30, 2004, and consequently had the availability to issue $188 million of preferred stock, assuming a dividend rate of 7%. The ability to issue such securities in the future will depend on such coverage ratios at that time.
 
Genco

Genco’s senior note indenture includes provisions that require it to maintain a senior debt service coverage ratio of at least 1.75 to 1 (for both the prior four fiscal quarters and projected next succeeding four six-month periods) in order to pay dividends or to make payments of principal or interest under certain subordinated indebtedness excluding amounts payable under its intercompany note payable to CIPS. For the 12 months ended September 30, 2004, this ratio was 4.47 to 1. In addition, the indenture also restricts Genco from incurring any additional indebtedness, with the exception of certain permitted indebtedness as defined in the indenture, unless its senior debt service coverage ratio equals at least 2.5 to 1 for the most recently ended four fiscal quarters and its senior debt to total capital ratio would not exceed 60%, both after giving effect to the additional indebtedness on a pro-forma basis. This debt incurrence restriction is disregarded in the event certain rating agencies reaffirm the ratings of Genco after considering the additional indebtedness. As of September 30, 2004, Genco’s senior debt to total capital ratio was 50%.

CILCORP

Covenants in CILCORP's indenture governing its $475 million (original issuance amount) senior notes and bonds require CILCORP to maintain a debt to capital ratio of no greater than 0.67 to 1 and an interest coverage ratio of at least 2.2 to 1 in order to make any payment of dividends or intercompany loans to affiliates other than to its direct and indirect subsidiaries, including CILCO. However, in the event CILCORP is not in compliance with these tests, CILCORP may only make such payments of dividends or intercompany loans if its senior long-term debt rating is at least BB+ from S&P, Baa2 from Moody’s and BBB from Fitch. For the 12 months ended September 30, 2004, CILCORP's debt to capital ratio was 0.58 to 1 and its interest coverage ratio was 2.1 to 1, calculated in accordance with applicable provision s of this indenture. At September 30, 2004, CILCORP’s senior long-term debt ratings from S&P, Moody’s and Fitch were BBB+, Baa2 and BBB+, respectively. The common stock of CILCO is pledged as security to the holders of these senior notes and bonds.

IP

IP’s indenture agreements and articles of incorporation include covenants and provisions related to the issuance of first mortgage bonds and preferred stock. For the issuance of additional first mortgage bonds based on property additions, earnings coverage of twice the annual interest charges on first mortgage bonds outstanding and to be issued is required. For the 12 months ended September 30, 2004, IP had a coverage ratio of 1.5 times the annual interest charges on the first mortgage bonds outstanding, which would not permit IP to issue any additional first mortgage bonds based on property additions. However, as of September 30, 2004, IP had the ability to issue $569 million of bonds based upon retired bond capacity, for which no earnings coverage test is requir ed. For the issuance of additional preferred stock, earnings coverage of at least 1.5 times the annual dividend on preferred stock outstanding and to be issued is required under IP’s articles of incorporation. For the 12 months ended September 30, 2004, IP had a coverage ratio of 1.1times the annual dividend requirement on preferred stock outstanding, which would not permit IP to issue any additional preferred stock.  The ability to issue such securities in the future will depend on such tests at that time.

IP’s indenture governing its mortgage bonds 11.50% Series due 2010 contain triggering event provisions that would give the holders of at least 25% in principal amount of these bonds then outstanding the right to require IP to redeem the bonds, if IP takes certain actions defined in the bond indenture as restricted payments, incurrence of indebtedness and issuance of preferred stock, dividend and other payment restrictions affecting subsidiaries, and repurchase at the option of bondholders due to asset sales. These triggering events have been suspended with the upgrade to an investment grade credit rating of IP’s long-term debt after completion of Ameren’s acquisition of IP and will remain non-applicable
 
 
42

 
 
as long as IP maintains an investment grade credit rating. Triggering events remain in effect on IP’s ability to incur liens, to merge, consolidate or sell assets, provide subsidiary guarantees, and engage in sale and leaseback transactions and certain business activities as defined in the indenture. See discussion of IP’s redemption and tender offer activities with respect to these bonds under "Ameren" above.

The IP SPT TFNs contain restrictions, which prohibit IP LLC from making any loan or advance to or certain investments in any other person. Also, as long as the TFNs are outstanding, the IP SPT shall not, directly or indirectly, pay any dividend or make any distribution (by reduction of capital or otherwise) to any owner of a beneficial interest in the IP SPT.

See Note 3 - Rate and Regulatory Matters for restrictions on IP’s ability to declare and pay common stock dividends imposed by the ICC order approving Ameren’s acquisition of IP.
 
Off-Balance Sheet Arrangements

At September 30, 2004, neither Ameren nor any of its subsidiaries had any off-balance sheet financing arrangements, other than operating leases entered into in the ordinary course of business. Neither Ameren nor any of its subsidiaries expects to engage in any significant off-balance sheet financing arrangements in the near future.

NOTE 6 - OTHER INCOME AND DEDUCTIONS

The following table presents Other Income and Deductions for each of the Ameren Companies for the three months and nine months ended September 30, 2004 and 2003:


   
Three Months
 
Nine Months
 
   
2004
 
2003
 
2004
 
2003
 
Ameren:(a)
                 
Miscellaneous income:
                 
Interest and dividend income
 
$
5
 
$
1
 
$
10
 
$
3
 
Allowance for equity funds used during construction
   
2
   
1
   
6
   
1
 
Other
   
1
   
2
   
4
   
12
 
Total miscellaneous income 
 
$
8
 
$
4
 
$
20
 
$
16
 
Miscellaneous expense:
                         
Minority interest in subsidiary
 
$
(1
)
$
(1
)
$
(4
)
$
(6
)
Other
   
-
   
(2
)
 
(2
)
 
(8
)
Total miscellaneous expense
 
$
(1
)
$
(3
)
$
(6
)
$
(14
)
UE:
                         
Miscellaneous income:
                         
Interest and dividend income
 
$
1
 
$
1
 
$
3
 
$
1
 
Equity in earnings of subsidiary
   
1
   
1
   
4
   
6
 
Allowance for equity funds used during construction
   
2
   
1
   
6
   
1
 
Gain on disposition of property
   
1
   
-
   
1
   
-
 
Other
   
-
   
2
   
-
   
6
 
Total miscellaneous income
 
$
5
 
$
5
 
$
14
 
$
14
 
Miscellaneous expense:
                         
Other
 
$
(1
)
$
(2
)
$
(6
)
$
(5
)
Total miscellaneous expense
 
$
(1
)
$
(2
)
$
(6
)
$
(5
)
CIPS:
                         
Miscellaneous income:
                         
Interest and dividend income
 
$
6
 
$
7
 
$
19
 
$
21
 
Total miscellaneous income
 
$
6
 
$
7
 
$
19
 
$
21
 
Miscellaneous expense:
                         
Other
 
$
-
 
$
-
 
$
(1
)
$
(2
)
Total miscellaneous expense
 
$
-
 
$
-
 
$
(1
)
$
(2
)
 

 
43

 

 
 
Three Months
 
Nine Months
 
   
2004
 
2003
 
2004
 
2003
 
Genco:
                         
Miscellaneous income:
                         
Other
 
$
1
 
$
-
 
$
-
 
$
-
 
Total miscellaneous income
 
$
1
 
$
-
 
$
-
 
$
-
 
CILCORP:(b)
                         
Miscellaneous expense:
                         
Other
 
$
(2
)
$
(2
)
$
(4
)
$
(3
)
Total miscellaneous expense
 
$
(2
)
$
(2
)
$
(4
)
$
(3
)
CILCO:
                         
Miscellaneous expense:
                         
Other
 
$
(1
)
$
(2
)
$
(4
)
$
(3
)
Total miscellaneous expense
 
$
(1
)
$
(2
)
$
(4
)
$
(3
)
(a)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003; includes amounts for Ameren registrant and non-registrant subsidiaries and intercompany eliminations.
(b)   January 2003 predecessor amounts were zero. CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.

 
NOTE 7 - DERIVATIVE FINANCIAL INSTRUMENTS

Cash Flow Hedges

The following table presents balances in certain accounts for cash flow hedges as of September 30, 2004:


   
Ameren
 
UE
 
CIPS
 
Genco
 
CILCORP(a)
 
CILCO
 
Balance Sheet:
                         
Other assets
 
$
56
 
$
10
 
$
11
 
$
7
 
$
25
 
$
25
 
Other deferred credits and liabilities
   
7
   
6
   
-
   
1
   
-
   
-
 
Accumulated OCI  income/(loss):
                                     
Power forwards(b)
   
(1
)
 
-
   
-
   
(1
)
 
-
   
-
 
Interest rate swaps(c) 
   
5
   
-
   
-
   
5
   
-
   
-
 
Gas swaps and futures contracts(d)
   
43
   
6
   
10
   
-
   
24
   
24
 
Call options(e)
   
4
   
4
   
-
   
-
   
-
   
-
 
(a)   CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.
(b)   Represents the mark-to-market loss for the hedged portion of electricity price exposure for periods generally less than one year. Certain contracts designated as hedges of electricity price exposure have terms up to three years.
(c)   Represents a gain associated with interest rate swaps at Genco that were a partial hedge of the interest rate on debt issued in June 2002. The swaps cover the first 10 years of debt that has a 30-year maturity and the gain in OCI is amortized over a 10-year period that began in June 2002.
(d)   Represents a gain associated with natural gas swaps and futures contracts. The swaps are a partial hedge of natural gas requirements through March 2008.
(e)   Represents the mark-to-market gain of a call option to purchase coal that is accounted for as a cash flow hedge. This option to purchase coal expires in July 2005. 

The pre-tax net gain or loss on power forward derivative instruments included in Operating Revenues - Electric at Ameren, UE and Genco, which represented the impact of discontinued cash flow hedges, the ineffective portion of cash flow hedges, as well as the reversal of amounts previously recorded in OCI due to transactions going to delivery or settlement, was a $2 million loss for Ameren, $1 million loss for UE and $1 million loss for Genco for the quarter ended September 30, 2004 (2003 - less than $1 million gain for Ameren, less than $1 million gain for UE, less than $1 million gain for Genco), and was less than $1 million loss for Ameren, UE and Genco for the nine months ended September 30, 2004 (2003 - less than $1 million loss for Ameren, UE, and Genco).

Other Derivatives

The following table represents for the three months and nine months ended September 30, 2004 and 2003, the net change in market value of option transactions, which are used to manage positions in SO2 allowances, coal, heating oil and electricity or power. Certain of these transactions are treated as non-hedge transactions under SFAS No. 133, “Accounting for Derivative Instruments and Hedging Activities.” The net change in the market value of SO2 options is

 
44

 

 recorded in Operating Revenues - Electric, while the net change in the market value of coal, heating oil and electricity or power options is recorded as Operating Expenses - Fuel and Purchased Power.
 

Gains (Losses)(a)
 
Three Months
 
Nine Months
 
   
2004
 
2003
 
2004
 
2003
 
SO2 options:
                 
Ameren(b)
 
$
4
 
$
-
 
$
2
 
$
1
 
UE
   
4
   
(1
)
 
(2
)
 
(1
)
CIPS
   
-
   
-
   
-
   
-
 
Genco
   
-
   
1
   
4
   
2
 
CILCORP(c)
   
-
   
-
   
-
   
-
 
CILCO
   
-
   
-
   
-
   
-
 
(a)   Coal, power and heating oil option gains and losses were less than $1 million for the periods shown above.
(b)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003; includes amounts for Ameren registrant and non-registrant subsidiaries and intercompany eliminations.
(c)   January 2003 predecessor amounts were zero. CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.
 
NOTE 8 - RELATED PARTY TRANSACTIONS

The Ameren Companies and IP have engaged in, and may in the future engage in, affiliate transactions in the normal course of business. These transactions primarily consist of gas and power purchases and sales, services received or rendered, borrowings and lendings. Transactions between affiliates are reported as intercompany transactions on their financial statements, but are eliminated in consolidation for Ameren’s financial statements. For a discussion of our material related party agreements, see Note 14 - Related Party Transactions under Part II, Item 8 of the Ameren Companies’ combined Form 10-K for the fiscal year ended December 31, 2003 and see Note 2 - Acquisitions under Part 1, Item 1 of th is report for futher information regarding Ameren's additional 20% ownership in EEI.  Below are updates to several related party transactions.

Electric Power Supply Agreements

Under two electric power supply agreements, Genco is obligated to supply to Marketing Company, and Marketing Company, in turn, is obligated to supply to CIPS, all of the energy and capacity needed by CIPS to offer service for resale to its native load customers at rates specified by the ICC and to fulfill CIPS’ other obligations under all applicable federal and state tariffs or contracts. The agreement between Genco and Marketing Company can be terminated by either party upon at least one year’s notice, but could not have previously been terminated prior to December 31, 2004. On October 18, 2004, the FERC issued an order accepting a July 2004 filing seeking the extension of the CIPS-Marketing Company agreement and thus allowing the agreement to extend until the end of 2006.

In October 2003, in conjunction with CILCO’s transfer to AERG of substantially all of its generating assets, AERG entered into an electric power supply agreement with CILCO to supply CILCO with sufficient power to meet its native load requirements. AERG and CILCO agreed to extend the power supply agreement through December 31, 2006. Unlike the CIPS-Marketing Company agreement described in the preceding paragraph, FERC approval was not required for such an extension to become effective.

In the event that any of the parties to these agreements is unable to satisfy its obligations thereunder, either to purchase or deliver power, the counterparties would be forced to find alternative purchasers or suppliers for the energy, as appropriate, thus exposing them to market price risk.

Interconnection Agreements

UE, CIPS and IP are parties to an interconnection agreement for the use of their respective transmission lines and other facilities for the distribution of power. In addition, CILCO and IP are parties to a similar interconnection agreement. These agreements can be terminated by either party with three years notice.

 
 
 
45

 

Joint Dispatch Agreement

UE and Genco jointly dispatch electric generation under an amended joint dispatch agreement. Under the agreement, each affiliate is required to serve its load requirements from its own generation first, and then allow access to any available generation to its affiliate. The joint dispatch agreement can be terminated by either party by giving one year’s notice. To address concerns raised before the MoPSC in the proceeding relating to the transfer of UE’s Illinois-based utility businesses to CIPS (see Note 3 - Rate and Regulatory Matters), UE offered to seek to amend the joint dispatch agreement so as to provide UE with a larger share of the margins on short term sales of power from the combined generation of UE and Genco. In particular, UE offered to use its best efforts to obtain all required regulatory approvals for such an amendment, but only if the MoPSC concluded that this was a necessary condition for its approval of the transfer of UE’s Illinois-based utility businesses. If made, such an amendment is expected to provide to UE additional annual margins ranging from approximately $7 million to $24 million for UE’s share of short term power sales. Such an amendment is expected to result in a corresponding reduction in Genco’s margins from its share of short term power sales. However, this reduction is expected to be offset by margins received from additional power sales by Genco (through Marketing Company) to CIPS to serve the transferred UE Illinois-based electric utility business. Also as part of the proceeding before the MoPSC, UE offered to study alternatives to the current use of incremental costs to price system energy transfers under the joint dispatch agreement between UE and Genco, if the MoPSC concluded that this was a necessary condition for its approval.

On October 6, 2004, the MoPSC issued an Order effective October 16, 2004, approving the transfer of UE’s Illinois-based utility businesses to CIPS subject to various conditions. Among these conditions, the MoPSC requires UE to make two amendments to the joint dispatch agreement. First, UE must amend the agreement, as offered by UE, so as to provide UE with a larger share of the margins on short term sales of power from the combined generation of UE and Genco. Second, the MoPSC requires UE to amend the agreement so as to price the system energy transfers to Genco at market prices, rather than prices based on incremental costs as the joint dispatch agreement currently provides. On October 15, 2004, UE filed an application for rehearing of the October 6 order requesting that the MoPSC rehear or in the alternative, clarify its decision to impose these and other conditions as a part of approving the transfer of UE’s Illinois utility business. See Note 3 - Rate and Regulatory Matters for further information.

As a result of the foregoing, there is uncertainty as to the terms of the joint dispatch agreement and also as to its duration. The termination of the agreement, or modifications to it, could have a material effect on UE or Genco. Modifications to, or termination of, the agreement would not have an immediate impact on Ameren due to UE’s Missouri electric rate moratorium, which ends June 30, 2006.

Support Services Agreements
 
Costs of support services provided by Ameren Services, Ameren Energy and AFS to their affiliates, including wages, employee benefits, professional services and other expenses are based on, or are an allocation of, actual costs incurred. Effective September 30, 2004, IP was added to the support services agreements with Ameren Services and AFS.

Money Pools

Through the utility money pool, the pool participants can access committed credit facilities at Ameren, which totaled $935 million at September 30, 2004. These facilities are in addition to UE’s $154 million, CIPS’ $15 million and CILCO’s $60 million in committed credit facilities which are also available to the utility money pool participants. The total amount available to the pool participants from the utility money pool at any given time is reduced by the amount of borrowings by their affiliates, but increased to the extent the pool participants have surplus funds or other external sources are used to increase the available amounts. The average interest rate for borrowing under the utility money pool for the three months ended September 30, 2004, was 1.47% (2003 - 1.02%) and for the nine months e nded September 30, 2004 and 2003, was 1.17%. On September 30, 2004, the utility money pool agreement was amended to add IP as a participant. 
 
At September 30, 2004, $935 million was available through the non state-regulated subsidiary money pool, excluding additional funds available through surplus cash balances. The average interest rate for borrowing under the non state-regulated subsidiary money pool for the three and nine months ended September 30, 2004 and 2003 was 8.84%.

CILCORP has been granted authority by the SEC under the PUHCA to borrow up to $250 million directly from Ameren in a separate arrangement unrelated to the money pools.

       
 
 
46

 
 
On September 30, 2004, in conjunction with the completion on that date of Ameren’s acquisition of IP, a unilateral borrowing agreement was entered into between Ameren, IP and Ameren Services which enables IP to make short-term borrowings directly from Ameren. The aggregate amount of borrowings outstanding at any time by IP under the unilateral borrowing agreement and the utility money pool agreement may not exceed $500 million pursuant to authorization from the ICC and the SEC under the PUHCA.  Ameren Services is responsible for operation and administration of the agreement. 

Intercompany Promissory Notes
 
As of September 30, 2004, Genco has affiliate notes payable of $324 million and $34 million to CIPS and Ameren, respectively, which, by their current terms, have final payments of principal and interest due on May 1, 2005.  In November 2004, Genco made a $75 million principal prepayment under its note payable to CIPS. The note payable to CIPS was issued in conjunction with the transfer of its electric generating assets and related liabilities to Genco.  Genco and CIPS expect to renew or modify the CIPS note to extend the principal maturity, which could include continued amortization of the principal amount. Such extension could require regulatory approval.  Genco and Ameren are currently evaluating various alternatives with respect to the note payable to Ameren. In the event the maturities of these notes are not extended or restructured, whether due to not obtaining the necessary regulatory approvals or otherwise, Genco may need to access other financing sources to meet the maturity obligation to the extent it does not have cash available from its operating cash flows.  Such sources of financing could include borrowings under the non state-regulated subsidiary money pool, or infusion of equity capital or new direct borrowings from Ameren, all subject to applicable regulatory financing authorizations and provisions in Genco’s senior note indenture.
 
UE

The following tables present the impact of related party transactions on UE’s Consolidated Statement of Income and Consolidated Balance Sheet, based primarily on the agreements discussed above and in Note 14 - Related Party Transactions under Part II, Item 8 of the Ameren Companies’ combined Form 10-K for the year ended December 31, 2003:
 

Statement of Income
 
Three Months
 
Nine Months
 
   
2004
 
2003
 
2004
 
2003
 
Operating revenues from affiliates:
                 
Power supply agreement with EEI 
 
$
5
 
$
4
 
$
7
 
$
5
 
Joint dispatch agreement with Genco
   
31
   
23
   
89
   
79
 
Agency agreement with Ameren Energy
   
46
   
44
   
141
   
155
 
Interconnection agreement with IP
   
-
   
-
   
1
   
1
 
Gas transportation agreement with Genco
   
-
   
-
   
-
   
1
 
Total operating revenues 
 
$
82
 
$
71
 
$
238
 
$
241
 
Fuel and purchased power expenses from affiliates:
                         
Power supply agreements:
                         
EEI
 
$
15
 
$
15
 
$
47
 
$
43
 
Marketing Company
   
2
   
2
   
7
   
7
 
Joint dispatch agreement with Genco
   
13
   
13
   
37
   
31
 
Agency agreement with Ameren Energy
   
22
   
19
   
59
   
55
 
Total fuel and purchased power expenses
 
$
52
 
$
49
 
$
150
 
$
136
 
Other operating expenses:
                         
Support service agreements:
                         
Ameren Services
 
$
37
 
$
40
 
$
113
 
$
126
 
Ameren Energy
   
1
   
3
   
1
   
5
 
AFS
   
1
   
1
   
3
   
5
 
Total other operating expenses
 
$
39
 
$
44
 
$
117
 
$
136
 
Interest expense:
                         
Borrowings related to money pool
 
$
1
 
$
-
 
$
2
 
$
2
 
 
 

 
47

 

Balance Sheet
 
September 30, 2004
 
December 31, 2003
 
Assets:
         
Miscellaneous accounts and notes receivable
 
$
16
 
$
28
 
Liabilities:
             
Accounts payable and wages payable
 
$
34
 
$
46
 
Borrowings from money pool
   
189
   
-
 

CIPS

The following tables present the impact of related party transactions on CIPS’ Statement of Income and Balance Sheet, based primarily on the agreements discussed above and in Note 14 - Related Party Transactions under Part II, Item 8 of the Ameren Companies’ combined Form 10-K for the year ended December 31, 2003:
 

Statement of Income
 
Three Months
 
Nine Months
 
   
2004
 
2003
 
2004
 
2003
 
Operating revenues from affiliates:
                 
Power supply agreements:
                 
Marketing Company    
 
$
8
 
$
7
 
$
24
 
$
22
 
CILCO    
   
-
   
6
   
-
   
8
 
Total operating revenues
 
$
8
 
$
13
 
$
24
 
$
30
 
Fuel and purchased power expenses from affiliates:
                         
Power supply agreements:
                         
Marketing Company
 
$
77
 
$
90
 
$
220
 
$
243
 
EEI
   
8
   
7
   
24
   
22
 
Total fuel and purchased power expenses
 
$
85
 
$
97
 
$
244
 
$
265
 
Other operating expenses:
                 
Support service agreements:
                 
Ameren Services
 
$
12
 
$
13
 
$
36
 
$
42
 
AFS
   
1
   
-
   
1
   
1
 
Total other operating expenses
 
$
13
 
$
13
 
$
37
 
$
43
 
Interest income:
                         
Note receivable from Genco
 
$
5
 
$
7
 
$
18
 
$
21
 
 

Balance Sheet
 
September 30, 2004
 
December 31, 2003
 
Assets:
         
Miscellaneous accounts and notes receivable 
 
$
9
 
$
10
 
Promissory note receivable from Genco(a)
   
324
   
373
 
Tax receivable from Genco(b)
   
152
   
162
 
Liabilities:
             
Accounts payable and wages payable
 
$
42
 
$
43
 
Borrowings from money pool
   
61
   
121
 
(a)   Amount includes current portion of $49 million as of December 31, 2003 and $324 million as of September 30, 2004.
(b)   Amount includes current portion of $12 million as of December 31, 2003 and $11 million as of September 30, 2004.
 


 
48

 

Genco

The following tables present the impact of related party transactions on Genco’s Statement of Income and Balance Sheet, based primarily on the agreements discussed above and in Note 14 - Related Party Transactions under Part II, Item 8 of the Ameren Companies’ combined Form 10-K for the year ended December 31, 2003:
 

Statement of Income
 
Three Months
 
Nine Months
 
   
2004
 
2003
 
2004
 
2003
 
Operating revenues from affiliates:
                 
Power supply agreements:
                 
Marketing Company
 
$
190
 
$
177
 
$
531
 
$
477
 
EEI
   
2
   
3
   
3
   
4
 
Joint dispatch agreement with UE
   
13
   
13
   
37
   
31
 
Agency agreement with Ameren Energy
   
23
   
19
   
72
   
73
 
Operating lease with Development Company
   
3
   
3
   
8
   
8
 
Total operating revenues
 
$
231
 
$
215
 
$
651
 
$
593
 
Fuel and purchased power expenses from affiliates:
                         
Joint dispatch agreement with UE
 
$
31
 
$
23
 
$
89
 
$
79
 
Agency agreement with Ameren Energy
   
9
   
9
   
22
   
28
 
Gas transportation agreement with UE
   
-
   
1
   
-
   
1
 
Total fuel and purchased power expenses
 
$
40
 
$
33
 
$
111
 
$
108
 
Other operating expenses:
                         
Support service agreements:
                         
Ameren Services
 
$
4
 
$
5
 
$
12
 
$
14
 
Ameren Energy
   
-
   
2
   
1
   
3
 
AFS
   
1
   
1
   
2
   
2
 
Total other operating expenses
 
$
5
 
$
8
 
$
15
 
$
19
 
Interest expense:
                         
Borrowings related to money pool    
 
$
4
 
$
4
 
$
10
 
$
12
 
Note payable to CIPS
   
5
   
7
   
18
   
21
 
Note payable to Ameren
   
1
   
1
   
2
   
2
 
 

Balance Sheet
 
September 30, 2004
 
December 31, 2003
 
Assets:
         
Miscellaneous accounts and notes receivable 
 
$
84
 
$
78
 
Liabilities:
             
Accounts payable and wages payable
   
22
   
22
 
Interest payable
   
22
   
7
 
Promissory note payable to CIPS(a)
   
324
   
373
 
Promissory note payable to Ameren(b)
   
34
   
38
 
Tax payable to CIPS(c)
   
152
   
162
 
Borrowings from money pool
   
79
   
124
 
(a)   Amount includes current portion of $49 million as of December 31, 2003 and $324 million as of September 30, 2004.
(b)   Amount includes current portion of $4 million as of December 31, 2003 and $34 million as of September 30, 2004.

 

 
49

 

CILCORP

The following tables present the impact of related party transactions on CILCORP’s Consolidated Statement of Income and Consolidated Balance Sheet, based primarily on the agreements discussed above and in Note 14 - Related Party Transactions under Part II, Item 8 of the Ameren Companies’ combined Form 10-K for the year ended December 31, 2003:
 

Statement of Income(a)(b)
 
Three Months
 
Nine Months
 
   
2004
 
2003
 
2004
 
2003
 
Operating revenues from affiliates:
                 
Gas supply and services agreement with Medina Valley
 
$
-
 
$
3
 
$
-
 
$
12
 
Total operating revenues
 
$
-
 
$
3
 
$
-
 
$
12
 
Fuel and purchased power expenses from affiliates:
                         
Executory tolling agreement with Medina Valley
 
$
6
 
$
7
 
$
23
 
$
22
 
Power purchase agreement with CIPS
   
-
   
6
   
-
   
8
 
Total fuel and purchased power expenses
 
$
6
 
$
13
 
$
23
 
$
30
 
Other operating expenses:
                         
Support services agreements:
                         
Ameren Services
 
$
12
 
$
6
 
$
37
 
$
7
 
AFS
   
-
   
-
   
1
   
1
 
Total other operating expenses
 
$
12
 
$
6
 
$
38
 
$
8
 
Interest expense:
                         
Note payable to Ameren
 
$
1
 
$
-
 
$
3
 
$
-
 
Borrowings related to money pool
   
1
   
-
   
3
   
-
 
(a)   2003 amounts include January 2003 predecessor information which included $2 million in operating revenues and $3 million in purchased power associated with the executory tolling agreement with Medina Valley.
(b)   CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.
 

Balance Sheet(a)
 
September 30, 2004
 
December 31, 2003
 
Assets:
         
Miscellaneous accounts and notes receivable 
 
$
8
 
$
8
 
Liabilities:
             
Accounts payable
 
$
19
 
$
16
 
Note payable to Ameren
   
56
   
46
 
Borrowings from money pool
   
191
   
145
 
(a)   CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.
 
CILCO

The following tables present the impact of related party transactions on CILCO’s Consolidated Statement of Income and on the Consolidated Balance Sheet, based primarily on the various agreements discussed above and in Note 14 - Related Party Transactions under Part II, Item 8 of the Ameren Companies’ combined Form 10-K for the year ended December 31, 2003:
 

Statement of Income
 
Three Months
 
Nine Months
 
   
2004
 
2003
 
2004
 
2003
 
Fuel and purchased power expenses from affiliates:
                 
Executory tolling agreement with Medina Valley    
 
$
6
 
$
7
 
$
23
 
$
22
 
Power purchase agreement with CIPS
   
-
   
6
   
-
   
8
 
Total fuel and purchased power expenses
 
$
6
 
$
13
 
$
23
 
$
30
 
Other operating expenses:
                         
Support services agreements:
                         
Ameren Services
 
$
11
 
$
6
 
$
35
 
$
7
 
AFS    
   
1
   
-
   
1
   
1
 
Total other operating expenses
 
$
12
 
$
6
 
$
36
 
$
8
 
Interest expense:
                         
Borrowings related to money pool
 
$
2
 
$
-
 
$
4
 
$
-
 

 
50

 
           
Balance Sheet
 
September 30, 2004
 
December 31, 2003
 
Assets:
         
Miscellaneous accounts and notes receivable 
 
$
8
 
$
6
 
Liabilities:
             
Accounts payable
 
$
18
 
$
23
 
Borrowings from money pool
   
193
   
149
 


NOTE 9 - COMMITMENTS AND CONTINGENCIES

Reference is made to Note 15 - Commitments and Contingencies under Part II, Item 8 of the Ameren Companies’ combined Form 10-K for the fiscal year ended December 31, 2003.

Capital Expenditures

See Note 3 - Rate and Regulatory Matters for information regarding Ameren’s capital expenditure commitment with respect to IP, which was included in the ICC order approving Ameren’s acquisition of IP.

Callaway Nuclear Plant

The following table presents insurance coverage at UE’s Callaway nuclear plant at September 30, 2004:
 

 
Type and Source of Coverage
Maximum
Coverages
Maximum Assessments
for Single Incidents
Public liability:
   
American Nuclear Insurers
                        $        300
                                $       -
Pool participation
                                   10,461
                                                            101(a)
 
                        $    10,761(b) 
                                $    101
Nuclear worker liability:
   
American Nuclear Insurers
                        $     300(c)
                                $       4
Property damage:
   
Nuclear Electric Insurance Ltd.    
                        $     2,750(d)
                                $      21
Replacement power:
   
Nuclear Electric Insurance Ltd.
                        $       490(e)
                                $       7
(a)   Retrospective premium under the Price-Anderson liability provisions of the Atomic Energy Act of 1954, as amended (Price-Anderson). This is subject to retrospective assessment with respect to loss from an incident at any U.S. reactor, payable at $10 million per year. Price-Anderson expired in August 2002 and the temporary extension expired December 31, 2003. Until Price-Anderson is renewed, its provisions continue to apply to existing nuclear plants.
(b)   Limit of liability for each incident under Price-Anderson.
(c)   Industry limit for potential liability from workers claiming exposure to the hazards of nuclear radiation.
(d)   Includes premature decommissioning costs.
(e)   Weekly indemnity of $4.5 million for 52 weeks, which commences after the first eight weeks of an outage, plus $3.6 million per week for 71.1 weeks thereafter.
 
Price-Anderson limits the liability for claims from an incident involving any licensed U.S. nuclear facility. The limit is based on the number of licensed reactors and is adjusted at least every five years based on the Consumer Price Index. Utilities owning a nuclear reactor cover this exposure through a combination of private insurance and mandatory participation in a financial protection pool, as established by Price-Anderson.

If losses from a nuclear incident at the Callaway nuclear plant exceed the limits of, or are not subject to, insurance, or if coverage is not available, we self-insure the risk. Although we have no reason to anticipate a serious nuclear incident, if one did occur, it could have a material, but indeterminable, adverse effect on our financial position, results of operations or liquidity.

  
51

 
       
Leases

The following table presents our December 31, 2003 lease obligations, which have been updated to include IP lease obligations subsequent to September 30, 2004: 
 

   
 
Total
 
 
2004
 
 
2005 - 2006
 
 
2007 - 2008
 
 
Thereafter
 
Ameren:(a)
                               
Capital leases(b)
 
$
167
 
$
70
 
$
7
 
$
8
 
$
82
 
Operating leases(c) 
   
211
   
24
   
39
   
31
   
117
 
Total lease obligations
 
$
378
 
$
94
 
$
46
 
$
39
 
$
199
 
UE:
                               
Capital leases(b)
 
$
167
 
$
70
 
$
7
 
$
8
 
$
82
 
Operating leases(c) 
   
128
   
9
   
19
   
18
   
82
 
Total lease obligations
 
$
295
 
$
79
 
$
26
 
$
26
 
$
164
 
CIPS:
                               
Operating leases(c) 
 
$
-
 
$
-
 
$
-
 
$
-
 
$
-
 
Genco:
                               
Operating leases(c) 
 
$
42
 
$
2
 
$
5
 
$
4
 
$
31
 
CILCORP:
                               
Operating leases(c) 
 
$
9
 
$
2
 
$
3
 
$
2
 
$
2
 
CILCO:
                               
Operating leases(c) 
 
$
9
 
$
2
 
$
3
 
$
2
 
$
2
 
(a)   Includes amounts for registrant and non-registrant Ameren subsidiaries, including IP, and intercompany eliminations.
(b)   See Note 6 - Long-term Debt and Equity Financings under Part II, Item 8 of the Ameren Companies’ combined Form 10-K for the fiscal year ended December 31, 2003 for further discussion.
(c)   Amounts related to certain real estate leases and railroad licenses have indefinite payment periods. The amounts for these items are included in the 2004, 2005 - 2006 and 2007 - 2008 columns. Amounts for after 5 years are not included in the total amount due to the indefinite periods. The estimated obligation for after 5 years is $2 million annually for both the real estate leases and the railroad licenses.

Other Obligations

To supply a portion of the fuel requirements of our generating plants, we have entered into various long-term commitments for the procurement of coal, natural gas and nuclear fuel. In addition, we have entered into various long-term commitments for the purchase of electricity. For a complete listing of our obligations and commitments, see Contractual Obligations under Part II, Item 7 and Note 15 - Commitments and Contingencies under Part II, Item 8 of the Ameren Companies’ combined Form 10-K for the fiscal year ended December 31, 2003.

As of September 30, 2004, the commitments for the procurement of coal have increased from what was previously disclosed as of December 31, 2003. The following table presents the total estimated coal purchase commitments at September 30, 2004:


   
2004
 
2005
 
2006
 
2007
 
2008
 
Thereafter(a)
 
Ameren(b)
 
$
754
 
$
665
 
$
553
 
$
395
 
$
353
 
$
201
 
UE
   
384
   
347
   
275
   
184
   
160
   
71
 
CIPS
   
-
   
-
   
-
   
-
   
-
   
-
 
Genco
   
189
   
176
   
163
   
130
   
124
   
99
 
CILCORP
   
93
   
61
   
46
   
33
   
28
   
12
 
CILCO
   
93
   
61
   
46
   
33
   
28
   
12
 
(a)   Commitments for coal are until 2010.
(b)   Includes amounts for registrant and non-registrant Ameren subsidiaries and intercompany eliminations.

As a result of Ameren’s acquisition of IP on September 30, 2004, the commitments and contingencies of IP are now included in Ameren’s other obligations. IP’s other obligations include IP’s contracts on six interstate pipeline companies for firm transportation and storage services for natural gas. These contracts have varying expiration dates ranging from 2004 to 2012, for a total cost of approximately $73 million. IP also enters into obligations for the reservation of natural gas supply. These obligations generally range in duration from one to twelve months and require IP to compensate the


 
52

 
provider for capacity charges. The cost of the agreements are $73 million.  As part of the terms of Ameren’s acquisition of IP, IP entered into a power purchase agreement with a Dynegy affiliate that will be effective for 2005 and 2006. As a result of this agreement and an agreement that expires on December 31, 2004, IP’s obligations for purchased power are approximately $354 million. Expected purchases by IP under the Purchase Power Agreement with AmerGen, which expires in December 2004, are approximately $71 million.

IP has decommissioning obligations of approximately $5 million, payable in the fourth quarter of 2004, associated with its former Clinton nuclear plant. Other obligations also include decontamination and decommissioning charges associated with IP’s use of a DOE facility that enriched uranium for the Clinton nuclear plant. IP was assessed an amount to be paid over fifteen years that would be used to pay for the DOE’s decontamination and decommissioning of its facility. The remaining obligation is approximately $2 million and the final payment is due in 2006. 
 
Environmental Matters

Clean Air Act

The EPA issued a rule in October 1998 requiring 22 eastern states and the District of Columbia to reduce emissions of NOx in order to reduce ozone in the eastern United States. Among other things, the EPA’s rule establishes an ozone season, which runs from May through September, and a NOx emission budget for each state, including Illinois. The EPA rule requires states to implement controls sufficient to meet their NOx budget by May 31, 2004. In the spring of 2004, the EPA issued similar rules for Missouri. The compliance date for the Missouri rules is May 1, 2007.

As a result of these requirements, impacted Ameren Companies have installed a variety of NOx control technologies on power plant boilers over the past several years. The following table presents our future estimated capital expenditures to comply with the final NOx regulations in Missouri between 2005 and 2008:
 

Ameren
$160 million to $180 million
UE
$160 million to $180 million
CIPS
-
Genco
-
CILCORP
-
CILCO
-

In mid-December 2003, the EPA issued proposed regulations with respect to SO2 and NOx emissions (the “Clean Air Interstate Rule”) and mercury emissions from coal-fired power plants. The new rules, if adopted, will require significant additional reductions in these emissions from UE, Genco and CILCO power plants in phases, beginning in 2010. The rules are currently under a public review and comment period and may change before b eing issued as final. The following table presents preliminary estimated capital costs based on current technology on the Ameren systems to comply with the Clean Air Interstate Rule and mercury rules, as proposed:
 

 
By 2010
2011 - 2015
Ameren
$1.1 billion to $1.4 billion
$375 million to $510 million
UE
$660 million to $860 million
$175 million to $230 million
CIPS
-
-
Genco
$280 million to $370 million
$160 million to $220 million
CILCORP(a)
$110 million to $150 million
$40 million to $60 million
CILCO
$110 million to $150 million
$40 million to $60 million
(a)   CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.
 
 

 
53

 

EPA Notice of Violation and Complaint Regarding Former IP Power Plant
 
IP and DMG are the subject of a Notice of Violation (NOV) from the EPA and a complaint filed in 1999 by the United States in the U.S. District Court for the Southern District of Illinois (Court) alleging violations of the Clean Air Act and certain related federal and Illinois regulations. Similar notices and complaints were filed against other owners of coal-fired power plants in what we refer to as the Utility Enforcement Initiative. Both the NOV and the complaint allege that certain equipment repairs, replacements and maintenance activities at the three Baldwin Power Station generating units formerly owned by IP constituted “major modifications” under the Prevention of Significant Deterioration (PSD) regulations, the New Source Performance Standard (NSPS) regulations and the applicable Illinois regulat ions, and that the defendants failed to obtain required operating permits under the applicable Illinois regulations. When activities which are not otherwise exempt result in an increase in annual emissions that exceed the amount deemed significant under the PSD regulations, those activities are considered “major modifications.”  When activities meeting this definition occur, the Clean Air Act and related regulations generally subject those activities to PSD review and permit requirements and require that the generating facilities where the activities occur meet more stringent emissions standards, which may entail the installation of potentially costly pollution control equipment.

DMG, the current owner of the Baldwin Power Station, acquired the generating facility as a result of Dynegy’s acquisition of IP in 2000. With Ameren’s acquisition of IP on September 30, 2004, DMG and IP are no longer affiliated. DMG has significantly reduced emissions of SO2 and NOX at the Baldwin Power Station since 1999 by converting from high to low sulfur coal, and installing selective catalytic reduction equipment. However , the EPA may seek in the litigation to require the installation of the “best available control technology,” or the equivalent, at the Baldwin Power Station which could require significant capital expenditures. The EPA also has the authority to seek civil penalties for the alleged violations at the rate of up to $27,500 per day for each violation.
 
In February 2003, the Court granted IP’s and DMG’s joint motion for partial summary judgment based on the five-year statute of limitations. As a result, the EPA is not permitted to seek any monetary civil penalties for claims related to construction without a permit under the PSD regulations. The Court’s ruling also precludes monetary civil penalties for a portion of the claims under the NSPS regulations and the applicable Illinois regulations. IP believes that it has meritorious defenses against the remaining claims. The trial to resolve claims of liability was conducted in June 2003 and closing arguments occurred in September 2003. Ameren cannot predict when a decision will be rendered by the Court on the liability phase of the litigation. If the Court finds liability, a damages trial will then be conducted.
 
Pursuant to the terms of the stock purchase agreement covering Ameren’s acquisition of IP from Dynegy, Dynegy agreed to fully indemnify Ameren and IP in the event of an adverse ruling and in any settlement arising from or out of this litigation. To secure payment of the indemnification obligations of Dynegy, Ameren, pursuant to the terms of the stock purchase agreement, has deposited $100 million of the cash portion of the purchase price into an escrow account with the funds to be released to Dynegy on the sooner of (i) December 31, 2010, (ii) the date on which the senior unsecured debt of Dynegy Holdings Inc., a Dynegy subsidiary, achieves an investment grade rating from S&P or Moody’s or (iii) the occurrence of specified events relating to contingent environmental liabilities associated with IP 6;s former generating facilities, including the Baldwin Power Station. Ameren cannot predict the ultimate outcome of this litigation or whether Dynegy will be able to satisfy its indemnification obligations under the stock purchase agreement in the event IP is found to be liable. Ameren also cannot provide any assurance that the escrow arrangement will fully secure Dynegy’s indemnification obligations if such obligations are triggered.

In August 2003 two significant decisions were handed down in other cases that are part of the Utility Enforcement Initiative. The district court in United States vs. Ohio Edison applied the EPA’s narrow interpretation of the “routine maintenance, repair and replacement” exclusion, which defines it with respect to what is routine for the specific unit where the projects occurred, while the court in United States vs. Duke Energy Company rejected the EPA’s narrow interpretation, holding that the exclusion should be defined relative to what is routine for the particular industry. The Duke court also held that the hours and conditions of a unit’s operations must be held constant when measuring emissions increases. Under this rationale, an increase in maximum hourly emissions is required before activities would be considered “major modifications.” Ameren is unable to predict the significance of these cases to the Baldwin Power Station litigation as they are pending in other jurisdictions and are not binding authority.


 
54

 

The EPA previously requested information, which has been provided, concerning activities at DMG’s Vermilion, Wood River and Hennepin plants, all formerly owned by IP. Although the EPA could eventually commence enforcement actions based on activities at these plants, we are unable to assess the likelihood of any such additional EPA enforcement actions. In the event enforcement actions are initiated against IP as a result of its prior ownership of these plants, Ameren and IP intend to rely upon the indemnification provisions of the stock purchase agreement with Dynegy and the escrow agreement if it is in effect at the time.

Clean Water Act

In July 2004, the EPA issued rules under the Clean Water Act that require that cooling water intake structures reflect the best technology available for minimizing adverse environmental impacts. These rules pertain to existing generating facilities that currently employ a cooling water intake structure whose flow exceeds 50 million gallons per day. The rules may require us to install additional intake screens or other protective measures, as well as extensive site specific study and monitoring requirements. There is also the possibility that the rules may lead to the installation of cooling towers on some of our facilities. Our compliance costs associated with conducting field studies and installing fish collection systems t o determine the aquatic impact of our intake structures will be in the range of a few million dollars over the next few years. These studies will determine what, if any, additional technology must be applied at nine of our existing power plants. At this time, we are unable to estimate the costs of complying with these rules, but they could be material. Such costs will not be incurred prior to 2008.

Remediation

We are involved in a number of remediation actions to clean up hazardous waste sites as required by federal and state law. Such statutes require that responsible parties fund remediation actions regardless of fault, legality of original disposal, or ownership of a disposal site. Each of UE and CIPS has been identified by the federal or state governments as a potentially responsible party at several contaminated sites. Several of these sites involve facilities which were transferred by CIPS to Genco in May 2000 and were transferred by CILCO to AERG in October 2003. As part of each transfer, the transferor (CIPS or CILCO) has contractually agreed to indemnify the transferee (Genco or AERG) for remediation costs associated with pre-existing environmental contamination at the transferred sites.

CIPS, CILCO, UE and IP own or are otherwise responsible for 13, four, one and 25 former MGP sites in Illinois, respectively. All of these sites are in various stages of investigation, evaluation and remediation. Under its current schedule, Ameren anticipates that remediation at these sites should be completed by 2010. The ICC permits each company to recover remediation and litigation costs associated with their former MGP sites located in Illinois from their Illinois electric and natural gas utility customers through environmental adjustment rate riders. To be recoverable, such costs must be prudently and properly incurred and are subject to annual reconciliation review by the ICC. The total costs deferred, net of recoveries from insurers and through environmental adjustment rate riders, at September 30, 2004, wer e $26 million, $2 million, $1 million and $46 million for CIPS, CILCO, UE and IP, respectively.

In addition, UE owns or is otherwise responsible for 10 MGP sites in Missouri and one in Iowa. Unlike in Illinois, UE does not have in effect in Missouri a rate rider mechanism which permits remediation costs associated with MGP sites to be recovered from utility customers, and UE does not have any retail utility operations in Iowa. Because of the unknown and unique characteristics of each site (such as amount and type of residues present, physical characteristics of the site and the environmental risk), and uncertain regulatory requirements, we are not able to determine the maximum liability for the remediation of these sites.  UE has recorded a $12 million liability as of September 30, 2004, representing its estimated minimum obligation. At this time, we are unable to determine what portion of these costs, if any, will be eligible for recovery from insurance carriers.

In October 2002, CILCO submitted a corrective action plan to the Illinois Environmental Protection Agency (Illinois EPA) in accordance with permit conditions to address ground water issues associated with the recycle pond and ash ponds at the Duck Creek power plant facility. In January 2003, the Illinois EPA accepted portions of the plan but rejected other portions. Additional discussions with the Illinois EPA will be necessary to develop an acceptable plan. CILCORP and CILCO both have a liability of $8 million at December 31, 2003, included on their Consolidated Balance Sheets for the estimated cost of the remediation effort to treat and discharge the recycle system water in order to address these ground water issues. Future CILCO capital expenditures at Duck Creek will include construction of a dry flyash
 
 
55

 

collection system, a landfill and a new pond. CILCO estimates future capital expenditures for the indicated activities could range from $19 million to $25 million by 2008.

In addition, our operations, or that of our predecessor companies, involve the use, disposal and, in appropriate circumstances, the cleanup of substances regulated under environmental protection laws. We are unable to determine the impact these actions may have on our financial position, results of operations or liquidity.

Emission Credits
 
Both federal and state laws require significant reductions in SO2 and NOx emissions that result from burning fossil fuels. The Clean Air Act and NOx Budget Trading Program created marketable commodities called allowances. Each allowance gives the ow ner the right to emit one ton of SO2 or NOx. All existing generating facilities have been allocated allowances based on past production and the statutory emission reduction goals. If additional allowances are needed for new generating facilities, they can be purchased from facilities having excess allowances or from allowance banks. Our generating facilities comply with the SO2 limits through the use and purchase of allowances, the use of low sulfur fuels or through the application of pollution control technology. The NOx Budget Trading Program limits emissions of NOx during the ozone season (May through September). The NOx Budget Trading Program applies to all electric generating units in Illinois beginning in 2004 and in the eastern third of Missouri beginning in 2007. Our generating facilities are expected to comply with the NOx limits through the use and purchase of allowances or through the application of pollution control technology, including low NOx burners, over fire air systems, combustion optimization and selective catalytic reduction (SCR) systems.

As of September 2004, UE, Genco, CILCO and EEI held 1.7 million, 0.5 million, 0.3 million and 0.3 million tons, respectively, of SO2 emission allowances for use between 2004 and 2012. Each company possesses additional allowances for use in periods beyond 2012. As of September 30, 2004, UE, Genco, CILCO and EEI Illinois facilities expect to hold 290, 26,200, 8,300 and 8,600 tons, respectively, of NOX emission allowances with vintages from 2004 to 2007.  The Illinois Environmental Protection Agency is still determining some NOx emission allowances allocations for this period and 2008. UE, Genco and CILCO expect to use a substantial portion of the SO2 and NOx allowances for ongoing operations. Allocations of NOx allowances for Missouri facilities are pending the finalization of rules by Missouri regulators. New environmental regulations, including the Clean Air Interstate Rule, the timing of the installation of pollution control equipment and level of operations will have a significant impact on the amount of allowances actually required for ongoing operations.   

Asbestos-Related Litigation

Ameren, UE, CIPS, Genco, CILCO and IP have been named, along with numerous other parties, in a number of lawsuits which have been filed by certain plaintiffs claiming varying degrees of injury from asbestos exposure. Most have been filed in the Circuit Court of Madison County, Illinois. The number of total defendants named in each case is significant with as many as 235 parties named in a case to as few as five. However, the average number of parties is 65 in the cases that were pending as of September 30, 2004.

The claims filed against Ameren, UE, CIPS, Genco, CILCO and IP allege injury from asbestos exposure during the plaintiffs’ activities at our present or former electric generating plants. In the case of CIPS, its former plants are now owned by Genco, and in the case of CILCO, most of its former plants are now owned by AERG. Most of IP’s plants were transferred to a Dynegy subsidiary prior to Ameren’s acquisition of IP. As a part of the transfer of ownership of the generating plants, the transferor (CIPS or CILCO) has contractually agreed to indemnify the transferee (Genco or AERG) for liabilities associated with asbestos-related claims arising from activities prior to the transfer. Each lawsuit seeks unspecified damages in excess of $50,000, which, if pro ved, typically would be shared among the named defendants.


 
56

 

From July 1, 2004 through September 30, 2004, 12 additional asbestos-related lawsuits were filed against UE, CIPS, CILCO and IP, mostly in the Circuit Court of Madison County, Illinois, 13 lawsuits were dismissed and six were settled. The following table presents the status as of September 30, 2004, of the asbestos-related lawsuits that have been filed against the Ameren Companies and IP:
 

   
Specifically Named as Defendant
 
Total(a)
Ameren
UE
CIPS
Genco
CILCO
IP
Filed
242
18
138
85
2
17
109
Settled
                  56
                     -
                   34
            20
               -
                      2
                  26
Dismissed
                  97
                     8
                   57
            29
               -
                      3
                  44
Pending
                  89
                   10
                   47
            36
              2
                    12
                  39
(a)   Addition of the numbers in the individual columns does not equal the total column because some of the lawsuits name multiple Ameren entities as defendants. As of September 30, 2004, four asbestos-related lawsuits were pending against EEI. The general liability insurance maintained by EEI provides coverage with respect to liabilities arising from asbestos-related claims.

  
As of September 30, 2004, four asbestos-related lawsuits were pending against EEI.  The general liability insurance maintained by EEI provides coverage with respect to liabilities arising from asbestos-related claims.
Ameren, UE, CIPS, Genco, CILCO and IP believe that the final disposition of these proceedings will not have a material adverse effect on their financial position, results of operations or liquidity. See Note 3 - Rate and Regulatory Matters - IP Acquisition for information on the ICC’s approval of a tariff rider through which asbestos-related litigation claims will be allowed to be recovered from IP’s electric customers, subject to certain terms, commencing in 2007.

Other Matters

Enron Litigation Settlement

In May 2001, CILCO and Enron Power Marketing, Inc. (EPMI), a subsidiary of Enron Corporation (Enron), entered into a master agreement for electric purchases and sales, which covered energy transactions scheduled for deliveries during the period of 2001 to 2003. In November 2001, EPMI demanded that CILCO post $28 million in collateral based on mark-to-market exposure of open transactions. Also in November 2001, CILCO notified EPMI that events of default had occurred under the master agreement and pursuant to the termination provisions of the master agreement declared the master agreement terminated effective December 20, 2001. Enron and EPMI filed Chapter 11 bankruptcy petitions in December 2001 in the U.S. Bankruptcy Court f or the Southern District of New York. In December 2002, EPMI filed a complaint against AES, Constellation New Energy, Inc., formerly known as AES New Energy Inc., and CILCO in the U.S. Bankruptcy Court seeking $31 million. As a result of court ordered mediation of this matter, a settlement agreement was reached among the parties and approved by the Bankruptcy Court on September 30, 2004. This settlement agreement and court order settles the outstanding claims by requiring CILCO to pay $20.9 million to an Enron subsidiary. This settlement payment was made during October 2004. The payment also settles an unrelated dispute between CILCO and another Enron subsidiary, Enron North America Corporation (ENA) over ENA’s failure to deliver natural gas to CILCO pursuant to transactions entered into in May and October 2001. AES, in conjunction with its sale of CILCORP to Ameren in 2003, agreed to indemnify Ameren against the after-tax cost of all liabilities, which includes the settlement payment, legal fees a nd expenses, incurred by CILCO relating to the Enron claim. Ameren assigned its indemnification rights to CILCO. The indemnification payment from AES to CILCO also took place in October 2004. As a result, this settlement will have no earnings impact on Ameren, CILCORP or CILCO.

Labor-related Matters

On June 18, 2003, 20 retirees and surviving spouses of retirees of various Ameren companies (the plaintiffs) filed a complaint in the U.S. District Court, Southern District of Illinois (the District Court), against Ameren, UE, CIPS, Genco and Ameren Services, and against our Retiree Medical Plan (the defendants). The retirees were members of various local labor unions of the IBEW and the IUOE. The complaint, referred to as Barnett, et al. vs. Ameren Corporation, et al., alleges the following:
  • the labor organizations which represented the plaintiffs have historically negotiated retiree medical benefits with the defendants and that pursuant to the negotiated collective bargaining agreements and other negotiated documents, the plaintiffs are guaranteed medical benefits at no cost or at a fixed maximum cost during their retirement;

 
57

  • Ameren has unilaterally announced that, beginning in 2004, retirees must pay a portion of their own healthcare premiums and either an increasing portion of their dependents’ premiums or newly imposed dependents’ premiums, and that surviving spouses will be paying increased amounts for their medical benefits;
  • the defendants’ actions deprive the plaintiffs of vested benefits and thus violate ERISA and the Labor Management Relations Act of 1947, and constitute a breach of the defendants’ fiduciary duties; and
  • the defendants are estopped from changing the plan benefits. (This allegation was subsequently dropped from the amended complaints referred to below).
The plaintiffs filed the complaint on behalf of themselves, other similarly situated former non-management employees and their surviving spouses who retired from January 1, 1992 through October 1, 2002, and on behalf of all subsequent non-management retirees and their surviving spouses whose medical benefits are reduced or are threatened with reduction. The plaintiffs seek to have this lawsuit certified as a class action, seek injunctive relief and declaratory relief, seek actual damages for any amounts they are made to pay as a result of the defendants’ actions, and seek payment of attorney fees and costs. In response to the District Court’s ruling on the defendants’ motions to dismiss various counts of the complaint, a second amended complaint was filed on December 15, 2003, clarifying some of the allegations, and adding the Ameren Group Medical Plan as a defendant. In April 2004, the District Court granted the defendants’ motion to dismiss one of the counts brought in connection with the amended complaint which alleges the defendants breached their fiduciary duties under ERISA. In July 2004, the District Court denied the plaintiffs’ motion to certify this lawsuit as a class action and in September 2004, the Seventh Circuit Court of Appeals denied the plaintiffs’ application to appeal the District Court’s decision. In August 2004, the defendants filed a motion for summary judgment, which is pending before the District Court. We are unable to predict the outcome of this lawsuit or the impact of the outcome on our financial position, results of operations or liquidity.

Certain employees of CILCO are represented by the IBEW. These employees comprise 4% of Ameren’s workforce. The labor agreement covering these employees expired June 30, 2004, and was automatically extended through August 29, 2004. CILCO submitted a last, best and final offer to the employees’ collective bargaining unit on August 25, 2004, at which time it was agreed that the labor agreement would extend through September 30, 2004. The principal issues of the labor negotiations include work rules and CILCO’s proposal to change the employee medical benefits program to require employees to pay for a portion of their benefit coverage. On September 29, 2004, the last, best and final offer was rejected. On October 6, 2004, CILCO informed the employees’ collective bargaining unit that CILCO would impl ement, effective October 11, 2004, the economic and noneconomic portions of CILCO’s August 25, 2004 offer. The employees are currently working without a contract and under the terms of the August 25, 2004, offer. On October 18, 2004, most of the employees participated in a one-day work stoppage regarding a work rule grievance. We cannot predict what further action, if any, the collective bargaining unit will take or the response of Ameren’s other union represented employees to any action by its employees. We are unable to determine what, if any, impact these labor matters could have on our financial condition, results of operations or liquidity. Labor agreements covering the remaining UE, CIPS, IP and Genco employees represented by the IBEW and the IUOE expire in June 2006 and June 2007, respectively.

Leveraged Leases

Ameren owns interests in assets which have been financed as leveraged leases. One of these leveraged leases is a $10 million investment at September 30, 2004, in an aircraft leased to Delta Air Lines. Delta Air Lines reported significant operating losses and disclosed in its Form 10-Q filing for the three months ended June 30, 2004, that the company would need to seek to restructure its costs under Chapter 11 of the U.S. Bankruptcy Code if the company cannot achieve a competitive cost structure, regain sustained profitability and access the capital markets under acceptable terms. Ameren could lose all or a portion of its investment in the Delta Air Lines lease in the event of a bankruptcy or default by Delta Air Lines or any voluntary restructuring of the lease. As of September 30, 2004, Delta Air Lines was curren t in its lease payments related to this lease.


 
 
 
58

 
 
NOTE 10 - CALLAWAY NUCLEAR PLANT 

Under the Nuclear Waste Policy Act of 1982, the DOE is responsible for the permanent storage and disposal of spent nuclear fuel. The DOE currently charges one mill, or 1/10 of one cent, per nuclear-generated kilowatthour sold for future disposal of spent fuel. Pursuant to this Act, UE collects one mill from its electric customers for each kilowatthour of electricity that it generates from its Callaway nuclear plant. Electric utility rate s charged to customers provide for recovery of such costs. The DOE is not expected to have its permanent storage facility for spent fuel available until at least 2015. UE has sufficient storage capacity at its Callaway nuclear plant until 2019 and has the capability for additional storage capacity through the licensed life of the plant. The delayed availability of the DOE’s disposal facility is not expected to adversely affect the continued operation of the Callaway nuclear plant through its currently licensed life.

Electric utility rates charged to customers provide for the recovery of the Callaway nuclear plant’s decommissioning costs over the life of the plant, based on an assumed 40-year life, ending with expiration of the plant’s operating license in 2024. The Callaway nuclear plant site is assumed to be decommissioned based on immediate dismantlement method and removal from service. Decommissioning costs, including decontamination, dismantling and site restoration, are estimated to be $536 million in current year dollars and are expected to escalate approximately 3.5% per year through the end of decommissioning activity in 2033. Decommissioning costs are charged to cost of services used to establish electric rates for UE’s customers and amounted to approximately $7 million in each of the years 2003, 2002 and 2001. Every three years, the MoPSC and ICC require UE to file updated cost studies for decommissioning its Callaway nuclear plant, and electric rates may be adjusted at such times to reflect changed estimates. The latest studies were filed in 2002. Costs collected from customers are deposited in an external trust fund to provide for the Callaway nuclear plant’s decommissioning. Fund earnings are expected to average a pproximately 8.6% annually through the date of decommissioning. If the assumed return on trust assets is not earned, we believe it is probable that any such earnings deficiency will be recovered in rates. The fair value of the nuclear decommissioning trust fund for UE’s Callaway nuclear plant is reported in Nuclear Decommissioning Trust Fund in Ameren’s and UE’s Consolidated Balance Sheets. This amount is legally restricted to fund the costs of nuclear decommissioning. Changes in the fair value of the trust fund are recorded as an increase or decrease to the nuclear decommissioning trust fund and to the regulatory asset recorded in connection with the adoption of SFAS No. 143. Upon the completion of UE’s transfer of its Illinois electric and gas utility businesses to CIPS, which is subject to t he receipt of regulatory approvals, the assets and liabilities related to the Illinois portion of the decommissioning trust fund will be transferred to Missouri. See Note 3 - Rate and Regulatory Matters for further information.

 
NOTE 11 - STOCKHOLDERS’ EQUITY

Outstanding Shares of Common Stock

The following table reconciles the outstanding shares of Ameren common stock for the three months and nine months ended September 30, 2004 and 2003:
 

 
Three Months Ended
Nine Months Ended
 
2004
2003
2004
2003
Shares outstanding at beginning of period
             183.3
              161.7
          162.9
            154.1
Shares issued
               11.5
                  0.6
            31.9
                8.2
Shares outstanding at end of period
                 194.8
                  162.3
              194.8
                162.3

Paid-In Capital

Ameren received net proceeds of $1.3 billion from the issuance of shares of its common stock in February and July 2004. In addition, during the nine months ended September 30, 2004, Ameren, pursuant to registration statements filed with the SEC, issued a total of 1.8 million new shares of common stock valued at $84 million under its DRPlus and 401(k) plans. Ameren’s paid-in capital decreased $9 million due to the cashless exercise of stock options by its employees in the first nine months of 2004. See Note 5 - Long-term Debt and Equity Financings for further information.
 
 

 
59

 

UE's paid-in capital increased by $13 million as of September 30, 2004, to reflect a contribution received from Ameren as a result of the parent holding company's allocation of its income tax benefit.
Genco’s paid-in capital increased by $75 million as of September 30, 2004 as compared to December 31, 2003, as a result of a capital contribution from its parent that was used in Noovember 2004 to prepay a portion of the note due to CIPS.

CILCO’s paid-in capital increased by $75 million as of September 30, 2004, as compared to December 31, 2003, as a result of a capital contribution from its parent that was used to reduce short-term borrowings.

Other Comprehensive Income

Comprehensive income includes net income as reported on the statements of income and all other changes in common stockholders’ equity, except those resulting from transactions with common shareholders. A reconciliation of net income to comprehensive income for the three months and nine months ended September 30, 2004 and 2003 is shown below for the Ameren Companies:


   
Three Months Ended
 
Nine Months Ended
 
   
2004    
 
2003    
 
2004    
 
2003    
 
Ameren:(a)
                 
Net income
 
$
232
 
$
275
 
$
447
 
$
486
 
Unrealized gain (loss) on derivative hedging instruments,
     net of taxes (benefit) of $3, $(1), $15, $(3)
   
10
   
(3
)
 
16
   
(8
)
Reclassification adjustments for (gains) losses included in
     net income, net of taxes (benefit) of $(2), $-, $(1), $1
   
5
   
-
   
1
   
(2
)
Total comprehensive income, net of taxes
 
$
247
 
$
272
 
$
464
 
$
476
 
UE:
                         
Net income    
 
$
182
 
$
225
 
$
349
 
$
400
 
Unrealized gain (loss) on derivative hedging instruments,
     net of taxes (benefit) of $1, $(1), $3, $(2)
   
2
   
-
   
5
   
(2
)
Reclassification adjustments for (gains) losses included in
     net income, net of taxes (benefit) of $-, $-, $-, $-
   
-
   
-
   
-
   
(1
)
Total comprehensive income, net of taxes
 
$
184
 
$
225
 
$
354
 
$
397
 
CIPS:
                         
Net income    
 
$
23
 
$
26
 
$
41
 
$
31
 
Unrealized gain (loss) on derivative hedging instruments,
     net of taxes (benefit) of $2, $-, $4, $(1)
   
2
   
(1
)
 
6
   
(3
)
Reclassification adjustments for (gains) losses included in
     net income, net of taxes (benefit) of $-, $-, $-, $-
   
1
   
-
   
-
   
-
 
Total comprehensive income, net of taxes
 
$
26
 
$
25
 
$
47
 
$
28
 
 
Genco:
                         
Net income    
 
$
29
 
$
17
 
$
75
 
$
65
 
Unrealized gain (loss) on derivative hedging instruments,
     net of taxes (benefit) of $(1), $-, $(1), $-
   
-
   
(1
)
 
(1
)
 
(1
)
Reclassification adjustments for (gains) losses included in
     net income, net of taxes (benefit) of $-, $-, $-, $-
   
-
   
-
   
(1
)
 
-
 
Total comprehensive income, net of taxes
 
$
29
 
$
16
 
$
73
 
$
64
 
CILCORP: (b)
                         
Net income (loss)    
 
$
2
 
$
11
 
$
2
 
$
23
 
Unrealized gain (loss) on derivative hedging instruments,
      net of taxes (benefit) of $6, $-, $7, $(1)
   
7
   
(3
)
 
12
   
(4
)
Reclassification adjustments for (gains) losses included in
     net income, net of taxes (benefit) of $(1), $-, $-, $-
   
2
   
-
   
-
   
-
 
Total comprehensive income, net of taxes
 
$
11
 
$
8
 
$
14
 
$
19
 
 
 

 
60

 

 
Three Months Ended
 
Nine Months Ended
 
   
2004    
 
2003    
 
2004    
 
2003    
 
CILCO:
                         
Net income    
 
$
9
 
$
15
 
$
18
 
$
55
 
Unrealized gain (loss) on derivative hedging instruments,
     net of taxes (benefit) of $6 $-, $8, $(1)
   
7
   
(3
)
 
13
   
(4
)
Reclassification adjustments for (gains) losses included in
     net income, net of taxes (benefit) of $-, $-, $-, $-
   
1
   
-
   
(1
)
 
-
 
Total comprehensive income, net of taxes
   
17
 
$
12
   
30
 
$
51
 
(a)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003; includes amounts for Ameren registrant and non-registrant subsidiaries and intercompany eliminations.
(b)   2003 amounts include January 2003 predecessor information, which was zero. CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.


NOTE 12 - PENSION AND OTHER POSTRETIREMENT BENEFITS

Ameren’s pension plans are funded in compliance with income tax regulations and federal funding requirements. Based on our assumptions at December 31, 2003, in order to maintain minimum funding levels for Ameren’s pension plans, we expected to be required under ERISA to fund an average of approximately $115 million annually from 2005 through 2008, assuming the passage of a law which would be retroactive to January 1, 2004, to extend the temporary interest rate relief. In the third quarter of 2004, we used available cash to make a contribution of $295 million, with available cash, to our defined benefit retirement plans. This contribution will, among other things, provide cost savings to us by eliminating the need to pay insurance premiums to the Pension Benefit Guarantee Corporation. In light of this con tribution and the acquisition of IP, future required contributions are now expected to aggregate $400 million to be paid in 2008 and 2009. These amounts are estimates and may change based on actual stock market performance, changes in interest rates, and any changes in government regulations.

The following table presents the cash contributions made to our defined benefit retirement plan qualified trusts in the first nine months of 2004 and 2003:
 

   
2004
 
2003
 
Ameren(a)
 
$
295
 
$
25
 
UE
   
186
   
18
 
CIPS
   
33
   
4
 
Genco
   
29
   
3
 
CILCORP(b)
   
41
   
-
 
CILCO
   
41
   
-
 
(a)   Includes amounts for Ameren registrant and non-registrant subsidiaries
(b)   CILCORP consolidates CILCO and therefore included CILCO amounts in its balances.
 
The following table presents Ameren’s net periodic benefit costs (and the components of those costs) for pension and other postretirement benefits for the three months and nine months ended September 30, 2004 and 2003:
 

   
Pension Benefits
 
Postretirement Benefits
 
   
Three Months
 
Nine Months
 
Three Months
 
Nine Months
 
   
2004
 
2003
 
2004
 
2003
 
2004
 
2003
 
2004
 
2003
 
Service cost    
 
$
10
 
$
9
 
$
31
 
$
28
 
$
3
 
$
3
 
$
10
 
$
9
 
Interest cost    
   
33
   
32
   
96
   
98
   
13
   
15
   
41
   
45
 
Expected return on plan assets    
   
(30
)
 
(31
)
 
(89
)
 
(95
)
 
(7
)
 
(8
)
 
(23
)
 
(24
)
Amortization cost:
                                                 
Transition obligation    
   
-
   
-
   
-
   
-
   
1
   
1
   
3
   
3
 
Prior service cost    
   
3
   
2
   
9
   
6
   
(1
)
 
(1
)
 
(3
)
 
(3
)
Losses    
   
6
   
2
   
18
   
6
   
7
   
8
   
24
   
25
 
Net periodic benefit cost    
 
$
22
 
$
14
 
$
65
 
$
43
 
$
16
 
$
18
 
$
52
 
$
55
 
 

 

 
61

 

Ameren adopted FSP SFAS 106-2 during the second quarter of 2004, retroactive to January 1, 2004, which resulted in the recognition of a federal subsidy for postretirement benefit costs related to prescription drug benefits. See Note 1 - Summary of Significant Accounting Policies. The effect of this subsidy was a reduction of various components of Ameren’s, and principally UE’s, net periodic postretirement benefit costs for the second and third quarters of 2004. Interest costs and amortization losses were each reduced by $1 million and $5 million for the three and nine months ended September 30, 2004, respectively. Partially offsetting the nine-month amounts was a reduction in the expected return on plan assets of $2 million. The impact of the subsidy on the expected return on plan assets for the third qu arter of 2004 was minimal. The subsidy-related reduction in Ameren’s, and principally UE’s, accumulated postretirement benefit obligation was $71 million.

UE, CIPS, Genco, CILCORP and CILCO are participants in Ameren’s plans and are responsible for their proportional share of the pension benefit costs. The following table presents the pension costs incurred for the three months and nine months ended September 30, 2004 and 2003:


   
Three Months
 
Nine Months
 
   
2004
 
2003
 
2004
 
2003
 
Ameren(a)    
 
$
22
 
$
14
 
$
65
 
$
43
 
UE
   
15
   
9
   
40
   
27
 
CIPS    
   
3
   
2
   
9
   
5
 
Genco
   
2
   
1
   
6
   
4
 
CILCORP(b)
   
2
   
2
   
8
   
5
 
CILCO    
   
4
   
5
   
13
   
12
 
(a)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003; includes amounts for Ameren registrant and non-registrant subsidiaries.
(b)   CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.

UE, CIPS, Genco, CILCORP and CILCO are participants in Ameren’s plans and are responsible for their proportional share of the postretirement benefit costs. The following table presents the postretirement costs incurred for the three months and nine months ended September 30, 2004 and 2003:
 

   
Three Months
 
Nine Months
 
   
2004
 
2003
 
2004
 
2003
 
Ameren(a)    
 
$
16
 
$
18
 
$
52
 
$
55
 
UE
   
10
   
13
   
31
   
39
 
CIPS    
   
2
   
2
   
7
   
6
 
Genco
   
1
   
-
   
3
   
2
 
CILCORP(b)
   
3
   
3
   
8
   
7
 
CILCO    
   
5
   
5
   
14
   
12
 
(a)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003; includes amounts for Ameren registrant and non-registrant subsidiaries.
(b)   Includes predecessor information for January 2003. CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.

In conjunction with our acquisition of IP, employees of IP have transferred into the Ameren defined benefit and postretirement benefit plans. As such, we have assumed obligations for pension and postretirement benefits, adjusted to fair value, and net of assets transferred to Ameren plans, of approximately $137 million and $102 million, respectively, as of September 30, 2004.

 
 
62

 

NOTE 13 - SEGMENT INFORMATION 

As discussed in the Ameren Companies combined Form 10-K for the fiscal year ended December 31, 2003, Ameren’s two reportable segments are: (1) Utility Operations, which generates electricity and transmits and distributes gas and electricity and (2) Other, which is comprised of the parent holding company, Ameren Corporation. The operations of IP and the additional 20% ownership interest in EEI will be included in Ameren’s Utility Operations segment.

The table below presents segment information about the reported revenues and net income of Ameren for the three months and nine months ended September 30, 2004 and 2003: 
   

   
Utility Operations
 
Other
 
Reconciling Items(a)
 
Total
 
Three months 2004:
                 
Operating revenues
 
$
1,615
 
$
-
 
$
(298
)
$
1,317
 
Net income
   
247
   
(15
)
 
-
   
232
 
Three months 2003:
                         
Operating revenues
 
$
1,648
 
$
-
 
$
(295
)
$
1,353
 
Net income
   
275
   
-
   
-
   
275
 
Nine months 2004:
                         
Operating revenues
 
$
4,563
 
$
-
 
$
(878
)
$
3,685
 
Net income
   
459
   
(12
)
 
-
   
447
 
Nine months 2003: (b) 
                         
Operating revenues
 
$
4,383
 
$
-
 
$
(826
)
$
3,557
 
Net income
   
496
   
(10
)
 
-
   
486
 
(a)   Elimination of intercompany revenues. 
(b)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003; includes amounts for Ameren registrant and non-registrant subsidiaries and intercompany eliminations.


 
 
63

 

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.

OVERVIEW

Executive Summary

Ameren had solid operational performance during the third quarter and first nine months of 2004 and benefited from weather-adjusted demand growth in our service territory and solid margins on excess power sales.  However, Ameren earnings per share were down from the prior year periods.  This decrease was principally due to unusual gains related to an accounting change and settlement of a dispute with a supplier in the prior year, extremely mild summer weather in 2004, a refueling and maintenance outage at UE’s Callaway nuclear plant in the second quarter of 2004 and greater common shares outstanding as a result of prefunding the acquisition of IP and an additional 20% interest in EEI with approximately $1.3 billion of equity.

The IP acquisition was completed on September 30, 2004, and was a major milestone for Ameren.  Completing this acquisition, valued at $2.3 billion, in just eights months permits us to turn our attention to integrating IP’s operations with Ameren’s, realizing the expected synergies and related earnings from the acquisition, and improving IP’s financial condition.  Immediately following the announcement of the completion of the transaction, the three major credit rating agencies increased IP’s credit ratings to investment grade, recognizing the actions we had already taken, and plans we have, to strengthen IP’s financial condition.  Ameren and IP have already begun this process by calling for redemption, in October 2004, $193 million of IP’s high-cost 11.5% mortgage bonds pursuant to the bonds’ equity clawback provisions.  In addition, IP is tendering for the remaining $357 million of IP’s 11.5% mortgage bonds and called $147.8 million in additional debt.

General

Ameren, headquartered in St. Louis, Missouri, is a public utility holding company registered with the SEC under the PUHCA. Ameren’s primary asset is the common stock of its subsidiaries. Ameren’s subsidiaries operate rate-regulated electric generation, transmission and distribution businesses, rate-regulated natural gas distribution businesses and non rate-regulated electric generation businesses in Missouri and Illinois. Dividends on Ameren’s common stock are dependent on distributions made to it by its subsidiaries. See Note 1 - Summary of Significant Accounting Policies to our financial statements under Part I, Item 1 of this report for a detailed description of our principal operating subsidiaries. Also, see the Glossary of Terms and Abbreviations.
  • UE, also known as Union Electric Company, operates a rate-regulated electric generation, transmission and distribution business and a rate-regulated natural gas distribution business in Missouri and Illinois.
  • CIPS, also known as Central Illinois Public Service Company, operates a rate-regulated electric and natural gas transmission and distribution business in Illinois.
  • Genco, also known as Ameren Energy Generating Company, operates a non rate-regulated electric generation business in Illinois and Missouri.
  • CILCO, also known as Central Illinois Light Company, is a subsidiary of CILCORP (a holding company) and was acquired on January 31, 2003. It operates a rate-regulated electric transmission and distribution business, a primarily non rate-regulated electric generation business and a rate-regulated natural gas distribution business in Illinois.
  • IP, also known as Illinois Power Company, was acquired on September 30, 2004. It operates a rate-regulated electric and natural gas transmission and distribution business in Illinois. See Note 2 - Acquisitions to our financial statements under Part 1, Item 1 of this report for further information. 
The financial statements of Ameren are prepared on a consolidated basis and therefore include the accounts of its majority-owned subsidiaries. As the acquisition of IP occurred on September 30, 2004, Ameren’s Consolidated Statements of Income and Cash Flows for the periods ended September 30, 2004 do not reflect IP’s results. However,
 
 
64

 

IP’s financial position at September 30, 2004, and the acquisition-related activity were included in Ameren’s Consolidated Balance Sheet at September 30, 2004, and Consolidated Statement of Cash Flows for the nine months ended September 30, 2004. Results of CILCORP and CILCO reflected in Ameren’s consolidated financial statements include the period from January 31, 2003, when these companies were acquired. See Note 2 - Acquisitions for further information. All significant intercompany transactions have been eliminated. All tabular dollar amounts are in millions, unless otherwise indicated.

In addition to presenting results of operations and earnings amounts in total, certain information is expressed in cents per share. These amounts reflect factors that directly impact Ameren’s earnings. We believe this per share information is useful because it enables readers to better understand the impact of these factors on Ameren’s earnings. All references in this report of earnings per share are on the basis of diluted shares.

IP Acquisition

On September 30, 2004, Ameren completed the acquisition of all the common stock and 662,924 shares of preferred stock of Decatur, Illinois-based IP and a 20% ownership interest in EEI from Dynegy and its subsidiaries. Ameren acquired IP to complement its existing Illinois gas and electric operations.  The purchase included IP's rate-regulated electric and natural gas transmission and distribution business serving approximately 600,000 electric and 415,000 gas customers in areas contiguous to our existing Illinois utility service territories. With the acquisition, IP became an Ameren subsidiary operating as AmerenIP. See Note 1 - Summary of Significant Accounting Policies to our financial statements under Part I, Item 1 of this report for further information on the presentation of the results of IP in Ameren’s consolidated financial statements. For a discussion of the regulatory agency approvals granted in connection with this acquisition, see Note 3 - Rate and Regulatory Matters to our financial statements under Part I, Item 1 of this report. 

The total transaction value was approximately $2.3 billion, including the assumption of approximately $1.8 billion of IP debt and preferred stock and consideration, including transaction costs, of $451 million in cash, net of $51 million cash acquired, which, under the terms of the stock purchase agreement, is subject to a final working capital adjustment. Ameren placed $100 million of the cash portion of the purchase price in a six-year escrow pending resolution of certain contingent environmental obligations of IP and other Dynegy affiliates for which Ameren has been provided indemnification by Dynegy. See Note 9 - Commitments and Contingencies to our financial statements under Part I, Item 1 of this report for information on a pending IP environmental matter to which the indemnification and escrow applies. In a ddition, this transaction included a fixed price capacity power supply agreement for IP’s annual purchase in 2005 and 2006 of 2,800 megawatts of electricity from a subsidiary of Dynegy. The contract was marked to fair value at closing. This agreement is expected to supply about 70% of IP’s electric customer requirements during those two years. IP is currently in the final stages of soliciting bids to supply the remaining 30% of its power needs in 2005 and 2006. This solicitation is expected to be completed by the end of 2004. In the event that any of these suppliers are unable to supply the electricity required by these agreements, IP would be forced to find alternative suppliers to meet is load requirements thus exposing IP to market price risk, which could have a material impact on Ameren's results of operation.. Existing power supply agreements expire on December 31, 2004.
 
Ameren’s financing plan for funding this acquisition included the issuance of new Ameren common stock. Ameren issued an aggregate of approximately 30 million common shares in February 2004 and July 2004, which generated net proceeds of about $1.3 billion. Proceeds from these issuances were used to finance the cash portion of the purchase price and are expected to be used to reduce IP debt assumed as part of this transaction and to pay any related premiums. See Note 5 - Long-term Debt and Equity Financings to our financial statements under Part I, Item 1 of this report for information on redemptions and a tender offer instituted with respect to certain IP bonds after the acquisition.
 
Ameren expects the acquisition of IP to be accretive to earnings in the first two years of ownership based on a variety of assumptions related to power prices, interest rates and synergies, among other things. In November, Ameren and IP announced that they were offering a voluntary separation opportunity to certain groups of IP employees, or approximately 950 of Ameren’s total 9,300 employees.  The program is voluntary and offers an enhanced separation benefit and extended medical and dental benefits.  Employees must make a decision by December 20, 2004 and will leave the company throughout 2005 based on business needs.  The offering of this voluntary separation opportunity is consistent w ith Ameren’s plan for the integration of IP and conditions in the ICC order for the realization of administrative synergies from the acquisition.  Costs of the separation are expected to be deferred as a regulatory asset, which is also consistent with the ICC order.

 
 
65

 

RESULTS OF OPERATIONS

Earnings Summary

Our results of operations and financial position are affected by many factors. Weather, economic conditions and the actions of key customers or competitors can significantly impact the demand for our services. Our results are also affected by seasonal fluctuations caused by winter heating and summer cooling demand. With approximately 85% of Ameren’s revenues directly subject to regulation by various state and federal agencies, decisions by regulators can have a material impact on the price we charge for our services. Our non rate-regulated sales are subject to market conditions for power. We principally utilize coal, nuclear fuel, natural gas and oil in our operations. The prices for these commodities can fluctuate significantly due to the world economic and political environment, weather, supply and demand l evels and many other factors. We do not have fuel or purchased power cost recovery mechanisms in Missouri or Illinois for our electric utility businesses, but we do have gas cost recovery mechanisms in each state for our gas delivery businesses. The electric rates for UE are set through June 2006, and are set for CIPS, CILCO and IP through the end of 2006 such that cost decreases or increases will not be immediately reflected in rates. In addition, the gas delivery rates for UE in Missouri are set through June 2006. Fluctuations in interest rates impact our cost of borrowing and pension and postretirement benefits. We employ various risk management strategies in order to try to reduce our exposure to commodity risks and other risks inherent in our business. The reliability of our power plants and transmission and distribution systems and the level of purchased power cost, operating and administrative costs and capital investment are key factors that we seek to control in order to optimize our results of operations, cash flows and financial position.

Ameren’s net income decreased $43 million to $232 million, or $1.20 per share, in the third quarter of 2004 from $275 million, or $1.70 per share, in the third quarter of 2003. Net income in the third quarter of 2003 included an after-tax gain of $31 million or 19 cents per share related to the settlement of a dispute over coal mine reclamation issues with a coal supplier. This gain primarily represented a return of coal costs accumulated by a coal supplier for reclamation of a coal mine that principally supplied a UE power plant.

Excluding this after-tax gain, Ameren’s third quarter 2004 net income decreased $12 million, or 31 cents per share, from the third quarter of 2003. The decrease in net income was primarily due to abnormally mild summer weather in our service territory in 2004, as compared to 2003, and increased employee benefit costs. Ameren’s earnings per share were additionally reduced due to increased shares outstanding in 2004 as compared to the prior year. The higher shares outstanding were primarily due to common stock offerings in February 2004 and July 2004 to prefund the IP acquisition. Partially offsetting these reductions to income were organic growth in our service territory due to a recovering economy and increased margins on interchange sales due to greater availability of low-cost generation as a result of weather-reduced demand and higher prices.

Ameren’s net income decreased to $447 million, or $2.44 per share for the nine months ended September 30, 2004 compared to year-ago earnings of $486 million, or $3.02 per share. In the first nine months of 2003, net income included the after-tax gain from the settlement of the coal mine reclamation issues of $31 million or 19 cents per share as referenced above and a net cumulative effect gain of $18 million or 11 cents per share associated with the adoption of SFAS No. 143, “Accounting for Asset Retirement Obligations.” The net SFAS No. 143 gain resulted principally from the elimination of non-legal obli gation costs of removal for non rate-regulated assets from accumulated depreciation.

The following table presents the net cumulative effect after-tax gain recorded at each of the Ameren Companies upon adoption of SFAS No. 143:
 

Net Cumulative Effect After-Tax Gain
 
Ameren(a)
$
18
 
UE
 
-
 
CIPS
 
-
 
Genco
 
18
 
CILCORP(b)
 
4
 
CILCO
 
24
 
(a)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003; includes amounts for Ameren registrant and non-registrant subsidiaries and intercompany eliminations.
(b)   Represents predecessor information recorded in January 2003 prior to the acquisition date of January 31, 2003. CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.


 
 
66

 

Excluding the gains on the adoption of SFAS No. 143 and the settlement of the coal mine reclamation dispute in the prior year, Ameren’s net income increased $10 million for the first nine months of 2004 as compared to the same period in 2003. The change in net income was primarily due to organic growth in revenues, increased interchange margins, increased revenues from sales of emission credits, lower labor costs, the Midwest ISO refund of previously paid exit fees upon UE’s and CIPS’ re-entry into the Midwest ISO in the second quarter of 2004 and results of CILCORP being included for an additional month in 2004. Partially offsetting these increases to income were extremely mild 2004 summer weather conditions, increased fuel and purchased power and other operations and maintenance costs as a result of UE’s Callaway nuclear plant refueling and maintenance outage in the second quarter of 2004 and higher employee benefit costs. Increased common shares outstanding reduced Ameren’s earnings per share for the first nine months of 2004, as compared to the same period in 2003.

As a holding company, Ameren’s net income and cash flows are primarily generated by its principal subsidiaries, UE, CIPS, Genco, CILCORP and IP. The following table presents the contribution by Ameren’s principal subsidiaries to Ameren’s consolidated net income for the three months and nine months ended September 30, 2004 and 2003. IP was acquired on September 30, 2004, and did not make any contribution to net income or cash flows for the three and nine months ended September 30, 2004 and 2003.
 

   
Three Months
 
Nine Months
 
   
2004
 
2003
 
2004
 
2003
 
Net income:
                 
  UE(a)
 
$
181
 
$
224
 
$
345
 
$
396
 
  CIPS
   
22
   
25
   
39
   
29
 
  Genco(a)
   
29
   
17
   
75
   
65
 
  CILCORP(b)
   
2
   
11
   
2
   
14
 
  Other(c)
   
(2
)
 
(2
)
 
(14
)
 
(18
)
Ameren net income
 
$
232
 
$
275
 
$
447
 
$
486
 
(a)   Includes earnings from interchange sales by Ameren Energy that provided approximately $14 million and $46 million of UE’s net income in the three and nine months ended September 30, 2004, respectively, (2003 - three months - $11 million; nine months - $44 million) and approximately $6 million and $23 million of Genco’s net income in the three and nine months ended September 30, 2004, respectively (2003 - three months - $5 million; nine months - $23 million).
(b)   Excludes net income prior to the acquisition date of January 31, 2003. January 2003 predecessor amount was $9 million. CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.
(c)   Includes corporate general and administrative expenses, transition costs associated with the CILCORP acquisition, and other non rate-regulated operations.

Electric Operations

The following table presents the favorable (unfavorable) variations in electric margins, defined as electric revenues less fuel and purchased power, for the three months and nine months ended September 30, 2004, from the comparable periods in 2003. We consider electric margin to be a useful measure to analyze the change in profitability of our electric operations between periods and have included the below analysis as a complement to our financial information provided in accordance with GAAP. However, electric margin may not be a presentation defined under GAAP and may not be comparable to other companies or more useful than the GAAP information we are providing.

The variation for Ameren reflects the contribution from CILCORP for the January 2004 period as a separate line item, which allows other margin components to be comparable year over year as we owned CILCORP for only eight months in the first nine months of 2003. The variations in CILCORP and CILCO electric margins are for the three months and nine months ended September 30, 2004, as compared to the same periods in 2003.
 

 
 
Ameren(a)
 
UE
 
CIPS
 
Genco
 
CILCORP(b)
 
CILCO
 
Three Months
                         
Electric revenue change:
                         
Effect of weather (estimate)
 
$
(58
)
$
(40
)
$
(12
)
$
-
 
$
(5
)
$
(5
)
Growth and other (estimate)
   
30
   
14
   
4
   
12
   
(60
)
 
(60
)
Rate reductions
   
(10
)
 
(10
)
 
-
   
-
   
-
   
-
 
Interchange revenues
   
17
   
11
   
(2
)
 
4
   
2
   
2
 
EEI
   
(11
)
 
-
   
-
   
-
   
-
   
-
 
Total
 
$
(32
)
$
(25
)
$
(10
)
$
16
 
$
(63
)
$
(63
)
 
 

 
67

 

 
 
Ameren(a)
 
UE
 
CIPS
 
Genco
 
CILCORP(b)
 
CILCO
 
Fuel and purchased power change:
                                     
Fuel:
                                     
  Generation and other
 
$
6
 
$
2
 
$
-
 
$
2
 
$
(2
)
$
4
 
  Price
   
9
   
7
   
-
   
2
   
-
   
-
 
Purchased power
   
(19
)
 
(7
)
 
11
   
(7
)
 
51
   
51
 
EEI
   
10
   
-
   
-
   
-
   
-
   
-
 
Total
 
$
6
 
$
2
 
$
11
 
$
(3
)
$
49
 
$
55
 
Net change in electric margins
 
$
(26
)
$
(23
)
$
1
 
$
13
 
$
(14
)
$
(8
)
Nine Months
                         
Electric revenue change:
                         
CILCORP - January 2004
 
$
49
 
$
-
 
$
-
 
$
-
 
$
-
 
$
-
 
Effect of weather (estimate)
   
(39
)
 
(26
)
 
(11
)
 
-
   
(2
)
 
(2
)
Growth and other (estimate)
   
107
   
64
   
(1
)
 
55
   
(151
)
 
(151
)
Rate reductions
   
(27
)
 
(27
)
 
-
   
-
   
-
   
-
 
Interchange revenues
   
15
   
(1
)
 
(1
)
 
6
   
15
   
15
 
EEI
   
(24
)
 
-
   
-
   
-
   
-
   
-
 
Total
 
$
81
 
$
10
 
$
(13
)
$
61
 
$
(138
)
$
(138
)
Fuel and purchased power change:
                                     
  CILCORP - January 2004
 
$
(26
)
$
-
 
$
-
 
$
-
 
$
-
 
$
-
 
 Fuel:
                                     
     Generation and other    
   
(13
)
 
9
   
-
   
(17
)
 
(13
)
 
(4
)
    Price    
   
(7
)
 
(6
)
 
-
   
(1
)
 
7
   
7
 
  Purchased power    
   
(34
)
 
(17
)
 
20
   
(5
)
 
118
   
115
 
  EEI
   
4
   
-
   
-
   
-
   
-
   
-
 
Total
 
$
(76
)
$
(14
)
$
20
 
$
(23
)
$
112
 
$
118
 
Net change in electric margins
 
$
5
 
$
(4
)
$
7
 
$
38
 
$
(26
)
$
(20
)
(a)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003; includes amounts for Ameren registrant and non-registrant subsidiaries and intercompany eliminations.
(b)   Includes predecessor information for January 2003. CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.
 
Ameren
    
        Ameren’s electric margin decreased $26 million for the three months ended September 30, 2004, but increased $5 million for the nine months ended September 30, 2004, compared to the same periods in 2003. Excluding the additional month of CILCORP results in the current year, electric margin decreased $18 million for the nine months ended September 30, 2004. The decrease in electric margin for the three months ended September 30, 2004, was primarily attributable to extremely mild summer weather in 2004, as compared to 2003, and rate reductions. Weather, rate reductions, increased fuel and purchased power due to the Callaway refueling outage in the second quarter of 2004 and higher fuel costs contributed to the decrease in electric margins in the first nine months of 2004 as compared to the year-ago period. These reductions were partially offset by organic growth due to improved economic conditions in the three and nine months ended September 30, 2004, and increased interchange margins in the third quarter of 2004. Sales of emission credits increased $3 million in the third quarter and $9 million for the first nine months of 2004, as compared to 2003.

According to the National Weather Service, summer weather in Ameren’s service territory was the seventh mildest in the past 109 years. Cooling degree days in 2004 in our service territory were approximately 20% below both normal conditions and the prior year quarter, resulting in a decrease in weather-sensitive residential sales of 9% and slightly lower commercial sales in the current year quarter. For the nine months ended September 30, 2004, warmer winter weather in the first quarter of 2004 also resulted in unfavorable weather conditions. Heating degree days were approximately 9% less in the first three months of 2004 in our service territory, compared to the same period in 2003, and approximately 6% less than normal conditions. Industrial sales decreased 4% in the third quarter of 2004 primarily due to th e expiration of low margin power supply contracts to customers outside of our core service territory. Absent the loss of these contracts, industrial sales grew approximately 2% in the third quarter of 2004. Industrial sales were up slightly for the nine months ended September 30, 2004, as compared to 2003, but were up 4%, excluding the expiring customer contracts.


 
 
68

 

Rate reductions resulting from the 2002 UE electric rate case settlement in Missouri negatively impacted electric revenues during the current year periods. Annual reductions of $50 million, $30 million and $30 million were effective April 1, 2002, April 1, 2003 and April 1, 2004, respectively.
 
Interchange margins increased $5 million for the three months ended September 30, 2004, compared to the same period in 2003, due to increased availability of low-cost generation resulting from reduced demand from native load customers due to the mild summer weather. Despite the weather, the current year quarter also benefited from higher power prices as natural gas prices contributed to increased power prices. Average realized power prices on interchange sales increased to approximately $31 per megawatthour in the third quarter of 2004 from approximately $29 per megawatthour in the third quarter of 2003.  The third quarter of 2004, Ameren’s base load coal-fired electric generating plants’ average capacity factors were approximately 81%, despite the extremely mild weather, and equivalent avail ability factors were approximately 95%, which were comparable to the prior year period.  Interchange margins were comparable for the nine months ended September 30, 2004, compared to the same period in the prior year, as there was little variance in average power prices for the nine-month periods.

Ameren’s fuel and purchased power decreased $6 million in the quarter ended September 30, 2004, but increased $50 million, excluding the additional month of CILCORP, in the nine months ended September 30, 2004, compared to the same periods in 2003. The decrease in the third quarter of 2004 was due primarily to lower fuel costs as a result of increased availability of lower cost generation due to milder weather. The increase in the nine-month period was primarily due to increased power purchases necessitated by the Callaway refueling outage and increased fuel prices.

UE

UE’s electric margin decreased $23 million for the three months ended September 30, 2004, as compared to the same period in 2003. Electric margin decreased $4 million for the first nine months of 2004 compared to the same period in 2003. Residential sales decreased 10% during the third quarter of 2004 due to the extremely mild summer weather, partially offset by organic growth. Rate reductions from the 2002 rate case settlement negatively impacted electric revenues during the current year periods. Interchange margins increased $3 million for the three months ended September 30, 2004, compared to the same period in 2003, and were comparable for the nine-month periods. Sales of emission credits increased $3 million in the current quarter and $18 million for the firs t nine months of 2004, as compared to 2003.
 
Third quarter 2004 fuel and purchased power were comparable to the prior year in the third quarter, but increased $14 million for the first nine months of 2004 primarily due to increased purchased power (approximately $24 million) resulting from the Callaway refueling outage during the second quarter of 2004, as well as an unplanned outage at the Callaway plant during the first quarter of 2004, partially offset by decreased demand due to mild summer weather conditions in the third quarter of 2004.

CIPS

CIPS’ electric margin was comparable for the third quarter periods of 2004 and 2003. Electric margin increased $7 million for the nine months ended September 30, 2004, as compared to the same period in 2003. The increase in electric margin for the nine month period in 2004 was primarily attributable to reduced purchased power costs as a result of customers switching to Marketing Company and the eliminating of the negative margin associated with one of these customers. Revenues decreased also due to customers switching, as well as unfavorable weather conditions, partially offset by organic growth.

Genco

Genco’s electric margin increased $13 million for the three months and $38 million for the nine months ended September 30, 2004, as compared to the same periods in 2003. Increases in electric margin were primarily attributable to an increase in wholesale margins due to sales to new customers coupled with increased use of lower cost generation that was available as a result of fewer power plant outages in 2004. The increase in wholesale margin was in addition to an increase in interchange margins due to higher power prices and more lower cost power available for sale in the third quarter of 2004 due to the mild weather. Interchange margins were comparable for the three and nine months ended September 30, 2004, as compared to the same periods in 2003.

.

 
 
69

 
 
CILCORP and CILCO

Electric margin decreased $14 million at CILCORP and $8 million at CILCO for the three months ended September 30, 2004, and decreased $26 million at CILCORP and $20 million at CILCO for the nine months ended September 30, 2004, as compared to the same periods in 2003. Decreases in electric margin versus 2003 were primarily attributable to reduced revenues due to two large CILCO industrial customers switching to Marketing Company in July and October 2003 and transfers of other non rate-regulated customers to Marketing Company (three months - $50 million; nine months - $135 million), along with the extremely mild summer weather conditions. Fuel and purchased power also decreased for the three months and nine months ended September 30, 2004, as compared to the same periods in 2003 due to customers switching within th e Ameren Companies.
 
Gas Operations            

The following table presents the favorable (unfavorable) variations in gas margins, defined as gas revenues less gas purchased for resale, for the three months and nine months ended September 30, 2004, from the comparable periods in 2003. We consider gas margin to be a useful measure to analyze the change in profitability of our gas operations between periods and have included the table below as a complement to our financial information provided in accordance with GAAP. However, gas margin may not be a presentation defined under GAAP and may not be comparable to other companies or more useful than the GAAP information we are providing.
 

   
Three Months
 
Nine Months
 
Ameren(a)
 
$
-
 
$
29
 
UE
   
1
   
7
 
CIPS
   
-
   
5
 
Genco
   
-
   
-
 
CILCORP(b)
   
(1
)
 
3
 
CILCO
   
(1
)
 
1
 
(a)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003; includes amounts for Ameren registrant and non-registrant subsidiaries and intercompany eliminations.
(b)   Includes predecessor information for January 2003. CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.

Gas margins at Ameren, UE, CIPS, CILCORP and CILCO increased during the nine months ended September 30, 2004, primarily due to delivery rate increases, partially offset by milder winter weather conditions. Ameren’s margin also increased $13 million due to the additional month of CILCORP results in the current year. Excluding the additional month of CILCORP in the current year, Ameren’s sales were down 5% for the nine months ended September 30, 2004, as a result of the mild winter weather conditions.

The following table presents the effect of gas delivery rate increases on revenues for the three months and nine months ended September 30, 2004, from the comparable periods in 2003:
 

   
Three Months
 
Nine Months
 
Ameren
 
$
6
 
$
21
 
UE
   
2
   
8
 
CIPS
   
1
   
6
 
Genco
   
-
   
-
 
CILCORP
   
3
   
7
 
CILCO
   
3
   
7
 

 

 
70

 

Operating Expenses and Other Statement of Income Items

The following table presents the favorable (unfavorable) variations in operating and other expenses for the three months and nine months ended September 30, 2004, from the comparable period in 2003:
 

   
Ameren(a)
 
UE
 
CIPS
 
Genco
 
CILCORP(b)
 
CILCO
 
Three Months
                         
Other operations and maintenance
 
$
(12
)
$
1
 
$
4
 
$
4
 
$
(15
)
$
(12
)
Coal contract settlement
   
(51
)
 
(51
)
 
-
   
-
   
-
   
-
 
Depreciation and amortization
   
(4
)
 
(2
)
 
-
   
-
   
-
   
-
 
Taxes other than income taxes
   
6
   
-
   
-
   
-
   
5
   
5
 
Other income and deductions
   
6
   
1
   
(1
)
 
1
   
-
   
1
 
Interest
   
7
   
-
   
-
   
-
   
2
   
(2
)
Income taxes
   
31
   
30
   
(7
)
 
(6
)
 
14
   
11
 
 
Nine Months
                         
Other operations and maintenance
 
$
(55
)
$
(28
)
$
12
 
$
(3
)
$
(34
)
$
(27
)
Coal contract settlement
   
(51
)
 
(51
)
 
-
   
-
   
-
   
-
 
Depreciation and amortization
   
(10
)
 
(7
)
 
-
   
(1
)
 
9
   
5
 
Taxes other than income taxes
   
7
   
(4
)
 
2
   
2
   
12
   
12
 
Other income and deductions
   
12
   
(1
)
 
(1
)
 
-
   
(1
)
 
(1
)
Interest
   
12
   
-
   
2
   
4
   
1
   
1
 
Income taxes
   
31
   
37
   
(17
)
 
(12
)
 
19
   
16
 
(a)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003. Includes amounts for Ameren registrant and non-registrant subsidiaries and intercompany eliminations.
(b)   Includes predecessor information for January 2003.  CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.
 
Other Operations and Maintenance

Ameren’s other operations and maintenance expenses increased $12 million for the three months and $55 million for the nine months ended September 30, 2004, as compared to the same periods in 2003. The additional month of CILCORP results included in the nine months ended September 30, 2004, accounted for $15 million of other operations and maintenance expense compared to the same period in 2003, which included only eight months of CILCORP results.

Expenses at Ameren and UE increased during the nine-month period of 2004 primarily due to increased power plant maintenance expenses as a result of the outage at UE’s Callaway nuclear plant during the second quarter of 2004. The outage lasted 64 days and resulted in incremental maintenance costs of approximately $40 million. Refueling outages occur approximately every 18 months and typically include the replacement of fuel and the performance of maintenance and inspections. The last refueling outage occurred in the fall of 2002. In addition to the Callaway nuclear plant outage expenses, employee benefit costs were higher at Ameren and UE during both the quarter and the nine months ended September 30, 2004, primarily due to increased pension costs. The adoption in the second quarter of 2004, retroactive to January 1, 2004, of FASB Staff Position SFAS No. 106-2 resulted in the recognition of nontaxable federal subsidies expected to be provided under the Medicare Prescription Drug, Improvement and Modernization Act, which partially offset employee benefit cost increases in the third quarter and first nine months of 2004. See Note 1 - Summary of Significant Accounting Policies and Note 12 - Pension and Other Postretirement Benefits to our financial statements under Part I, Item 1 of this report for further information. Expenses at Ameren, UE and CIPS were reduced during the nine-month period of 2004 from the refund to UE and CIPS of previously paid exit fees upon our re-entry into the Midwest ISO. Lower labor costs in the current year at Ameren and UE also partially offset the above increases to other operations and maintenance expenses for the three and nine months ended September 30, 2004.

CIPS’ other operations and maintenance expenses decreased in the nine months ended September 30, 2004, as compared to the same periods in 2003, primarily due to CIPS’ portion of the Midwest ISO exit fee refund referenced above and lower labor costs. Other operations and maintenance expenses at CIPS decreased for the third quarter of 2004, as compared to the same period in the prior year, due to decreased labor costs.


 
 
71

 
 
Other operations and maintenance expenses at Genco increased in the nine months ended September 30, 2004, as compared to the same period in 2003, primarily due to increased employee benefit costs, partially offset by lower labor costs. Other operations and maintenance expenses at Genco decreased for the third quarter of 2004, as compared to the same period in the prior year, due to decreased power plant maintenance expenses as a result of fewer plant outages and lower labor costs.

CILCORP’s and CILCO’s other operations and maintenance expenses increased in the three months and nine months ended September 30, 2004, as compared to the same periods in 2003, primarily due to higher employee benefit costs and the settlement of its litigation claim with Enron Power Marketing, Inc. which resulted in a net increase to other operations and maintenance expenses of approximately $8 million. AES indemnified Ameren, and Ameren assigned the indemnification to CILCORP and CILCO for the $13 million after-tax cost of the $21 million claim settlement. As a result, other operations and maintenance expenses in the third quarter of 2004 reflects the net cost of $8 million while income taxes reflect a tax benefit of $8 million, resulting in no net income statement effect. See Note 9 - Commitments and Contingencies to our financial statements under Part I, Item 1of this report for further information. Partially offsetting these increases to other operations and maintenance expenses were reduced labor costs in the current year.
 
Coal Contract Settlement

Ameren and UE recorded a coal contract settlement gain of $51 million ($31 million after taxes) in the third quarter of 2003. This gain primarily represented a return of coal costs plus accrued interest accumulated by a coal supplier for reclamation of a coal mine that principally supplied a UE power plant. This mine reclamation is substantially complete. In August 2003, UE entered into a settlement agreement with the coal supplier to return the accumulated reclamation funds, which are being paid to UE ratably through December 2004.

Depreciation and Amortization

Ameren’s and UE’s depreciation and amortization expenses increased for the three months and nine months ended September 30, 2004, due to capital additions. Depreciation and amortization expenses at Ameren also increased for the first nine months of 2004 due to inclusion of the additional month of CILCORP expenses of $6 million.

Depreciation and amortization expenses at CIPS and Genco in the third quarter and first nine months of 2004 were comparable to the same periods in 2003.
 
Depreciation and amortization expenses at CILCORP and CILCO decreased in the nine months ended September 30, 2004, as compared to the same periods in 2003, primarily due to a lower balance of depreciable property resulting from property retirements exceeding capital additions. Depreciation and amortization expenses at CILCORP and CILCO were comparable in the third quarter of 2004 to the same period in 2003.

Taxes Other Than Income Taxes

Taxes other than income taxes decreased at Ameren in the three and nine months ended September 30, 2004, as compared to the same periods in 2003, primarily due to decreased gross receipts taxes.

UE’s taxes other than income taxes increased in the nine months ended September 30, 2004, as compared to the same period in 2003, primarily due to higher gross receipts and property taxes in 2004. Taxes other than income taxes were comparable in the third quarter of 2004 to the same period in 2003.

Taxes other than income taxes decreased at CIPS and Genco in the nine months ended September 30, 2004, as compared to the same period in 2003, primarily due to reduced property taxes in 2004. Taxes other than income taxes were comparable at CIPS and Genco in the third quarter of 2004 to the same period in 2003.

Taxes other than income taxes decreased at CILCORP and CILCO in the third quarter and nine months ended September 30, 2004, as compared to 2003, primarily due to reduced gross receipts taxes as a result of customers switching to Marketing Company.

 
 
 
72

 
Other Income and Deductions

Ameren’s other income and deductions increased in the third quarter and first nine months of 2004, as compared to the same periods in 2003, primarily due to increased interest income as a result of investing the proceeds from Ameren’s February and July 2004 equity offerings.

Other income and deductions at UE, CIPS, Genco, CILCORP and CILCO were comparable in the third quarter and first nine months of 2004 to the same periods in 2003.

See Note 6 - Other Income and Deductions to our financial statements under Part I, Item 1of this report for further information.

Interest

Interest expense decreased at Ameren in the third quarter and first nine months of 2004, as compared to the same periods in 2003, primarily due to the redemption of Ameren floating rate notes at the end of 2003, as well as redemptions of long-term debt during 2003 at its subsidiaries as noted below.

UE’s interest expense was comparable in the third quarter and first nine months of 2004 to the same periods in 2003.
 
Interest expense decreased at CIPS in the first nine months of 2004, as compared to the same periods of 2003, primarily due to the maturity or redemption of an aggregate of $90 million principal amount of first mortgage bonds in the second quarter of 2003. Interest expense at CIPS was comparable in the third quarter of 2004 to the same period in 2003.

Genco’s interest expense was reduced in the third quarter and first nine months of 2004, as compared to the same periods of 2003, primarily due to a reduction in principal amounts outstanding on intercompany promissory notes to CIPS and Ameren along with decreased borrowings from Ameren’s non state-regulated subsidiary money pool. The balance of intercompany notes to CIPS and Ameren was $358 million at September 30, 2004, as compared to $411 million at both September 30, 2003, and December 31, 2003, and $462 million at December 31, 2002.

Interest expense decreased at CILCO in the first nine months of 2004, as compared to the same periods of 2003, primarily due to the redemption of an aggregate of $175 million principal amount of long-term debt primarily in the second quarter of 2003 and the first quarter of 2004. Interest expense increased at CILCO in the third quarter of 2004, as compared to the same periods of 2003, primarily due to increased borrowings from Ameren’s non state-regulated subsidiary money pool.

Interest expense decreased at CILCORP in the three and nine months ended September 30, 2004, due to redemptions of debt at CILCO as mentioned above and repurchases of an aggregate of $71 million principal amount of CILCORP debt.
 
Income Taxes

Income tax expense was lower at Ameren for the first nine months and third quarter of 2004, as compared to the same periods in 2003, due to lower pre-tax income combined with a lower effective tax rate. The effective tax rate was reduced primarily due to the recording of the expected nontaxable federal Medicare subsidy in the third quarter and first nine months of 2004, the exercising of stock options by our employees in the current year, and a tax benefit of approximately $8 million related to CILCO’s settlement of its litigation claim with Enron Power Marketing, Inc.
 
Income tax expense increased at CIPS in the third quarter and first nine months of 2004, as compared to the same periods in 2003, primarily due to higher pre-tax income in the current year periods and an Illinois tax settlement in the third quarter of 2003, which resulted in reduced income taxes in the prior year periods. Income tax expense increased at Genco in the third quarter and first nine months of 2004, as compared to the same periods in 2003, primarily due to higher pre-tax income in the current year periods. Income tax expense decreased at UE primarily due to lower pre-tax income in 2004 and the recording of the expected nontaxable federal Medicare subsidy. Income tax expense decreased at CILCORP and CILCO primarily due to a tax benefit of approximately $8 million as a result of CILCO’s settlement of its litigation claim with Enron Power Marketing, Inc. and otherwise lower pre-tax income in 2004.

 
 
73

 

LIQUIDITY AND CAPITAL RESOURCES

The tariff-based gross margins of Ameren’s rate-regulated utility operating companies continue to be the principal source of cash from operating activities for Ameren and its rate-regulated subsidiaries. A diversified retail customer mix of primarily rate-regulated residential, commercial and industrial classes and a commodity mix of gas and electric service provide a reasonably predictable source of cash flows. In addition, we plan to utilize short-term debt to support normal operations and other capital requirements.

The following table presents net cash provided by (used in) operating, investing and financing activities for the nine months ended September 30, 2004 and 2003:
 

   
Net Cash Provided By
(Used In)
Operating Activities
 
Net Cash Provided By
(Used In)
Investing Activities
 
Net Cash Provided By
(Used In)
Financing Activities
 
   
2004
 
2003
 
Variance
 
2004
 
2003
 
Variance
 
2004
 
2003
 
Variance
 
Ameren(a)
 
$
736
 
$
852
 
$
(116
)
$
(977
)
$
(938
)
$
(39
)
$
777
 
$
(442
)
$
1,219
 
UE
   
529
   
486
   
43
   
(381
)
 
(308
)
 
(73
)
 
(150
)
 
(172
)
 
22
 
CIPS
   
79
   
102
   
(23
)
 
17
   
26
   
(9
)
 
(108
)
 
(128
)
 
20
 
Genco
   
115
   
125
   
(10
)
 
(37
)
 
(39
)
 
2
   
(80
)
 
(87
)
 
7
 
CILCORP(b)
   
100
   
75
   
25
   
(91
)
 
(64
)
 
(27
)
 
(11
)
 
(34
)
 
23
 
CILCO
   
84
   
100
   
(16
)
 
(94
)
 
(67
)
 
(27
)
 
7
   
(52
)
 
59
 
(a)   Excludes amounts for CILCORP and CILCO prior to the acquisition date of January 31, 2003; includes amounts for Ameren registrant and non-registrant subsidiaries and intercompany eliminations.
(b)   2003 amounts include January 2003 predecessor information. CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.

Cash Flows from Operating Activities

Cash flows provided by operating activities decreased for Ameren, CIPS, Genco and CILCO and increased for UE and CILCORP for the nine months ended September 30, 2004 compared to the same period in 2003. Cash flows provided by operating activities for all Ameren Companies were negatively impacted by the incremental cash contributions made to Ameren’s pension plan, as discussed below, during the first nine months of 2004, compared to the same period in 2003. In September 2004, all Ameren Companies received a partial tax refund totaling $55 million (UE - $22 million, CIPS - $6 million, Genco - $4 million, CILCORP - $14 million, CILCO - $9 million) for the cash pension contributions made in 2004 that were applied retroactively to the 2003 tax return. In addition, the pension contribution resulted in a lower third quarter 2004 tax payment.

Decreased earnings for the nine months ended September 30, 2004, compared to the same period in 2003, negatively impacted cash flows provided by operating activities for Ameren, UE, Genco, CILCORP and CILCO. The decrease in earnings resulted principally from the extremely mild summer weather in 2004 compared to the same period in 2003. Higher fuel prices, rate reductions and increased costs due to the Callaway refueling outage also led to the decrease in earnings at Ameren and UE. Cash flows provided by operating activities benefited from cash received by Ameren and UE of $28 million, related to UE’s settlement in 2003 of a dispute over mine reclamation issues with a coal supplier. Increased revenues from the sale of emission credits, primarily att ributed to UE a refund of exit fees for costs incurred related to entering a RTO totaling $8 million (UE - $7 million, CIPS - $1 million) and $26 million (UE - $13 million, CIPS - $5 million) received for an exit fee previously paid to the Midwest ISO, positively impacted the cash flows from operations for Ameren, UE and CIPS.

Pension Funding

Based on our assumptions at December 31, 2003, and in order to maintain minimum funding levels for Ameren’s pension plan, we expected to be required under ERISA to fund an average of approximately $115 million annually from 2005 through 2008 assuming the passage of a law which would be retroactive to January 1, 2004, to extend the temporary interest rate relief.  In September 2004, we used available cash to make a contribution of $295 million to our defined benefit retirement plans. This contribution will, among other things, provide cost savings to us from eliminating the need to pay insurance premiums to the Pension Guarantee Trust Corporation and will mitigate future benefit cost increases. In light of this contribution and the acquisition of IP, future required contributions are now expected to
 
 

 

aggregate $400 million to be paid in 2008 and 2009. These amounts are estimates and may change based on actual stock market performance, changes in interest rates, and any changes in government regulations. See Note 12 - Pension and Other Postretirement Benefits to our financial statements under Part 1, Item 1of this report for further detail.

Cash Flows from Investing Activities

Cash flows used in investing activities increased for all Ameren Companies with the exception of Genco for the nine months ended September 30, 2004 as compared to the same period in 2003. Ameren’s increase in cash used in investing activities was primarily due to $451 million in cash paid for the acquisition of IP and the 20% interest in EEI in 2004 compared to $489 million for the cash paid for the acquisitions of CILCORP and Medina Valley in early 2003. Excluding the acquisition costs described above, Ameren’s cash flows used in investing activities increased for the nine months ended September 30, 2004 comp ared to the same period in 2003 due to higher construction expenditures at UE, CILCORP and CILCO.

UE’s construction expenditures for the nine months ended September 30, 2004 primarily included replacement of condenser bundles and low pressure rotor equipment, and other upgrades, completed during the refueling and maintenance outage at UE’s Callaway nuclear plant. In addition, UE’s construction expenditures included upgrades at other UE power plants and expenditures for new transmission and distribution lines. CILCORP’s and CILCO’s construction expenditures were also primarily related to power plant upgrades that were made in order for CILCO’s non rate-regulated subsidiary, AERG, to have more flexibility in future fuel supply for power generation. Cash flows provided by investing activities for CIPS decreased for the nine months ended September 30, 2004, compared to the same period in 2003, primarily due to lower cash receipts related to CIPS’ intercompany note receivable with Genco in the first nine months of 2004, which totaled $49 million compared to $62 million in the first nine months of 2003. Genco’s decrease in cash flows used in investing activities primarily resulted from reduced construction expenditures in the first nine months of 2004 as compared to the same period in 2003. Genco’s construction expenditures in 2004 included costs primarily associated with the replacement of a turbine generator at one of its power plants.

In conjunction with the acquisition of IP on September 30, 2004, we committed to make $275 million to $325 million in energy infrastructure expenditures for IP over the next two years through 2006.

We continually review our generation portfolio and expected electrical needs, and as a result, we could modify our plan for generation capacity, which could include the timing of when certain assets will be added to, or removed from, our portfolio, the type of generation asset technology that will be employed, or whether capacity may be purchased, among other things. Any changes that we plan to make for future generating needs could result in significant capital expenditures or losses being incurred, which could be material.

Cash Flows from Financing Activities

Ameren

Ameren’s cash flows from financing activities increased for the nine months ended September 30, 2004, as compared to the same period in 2003. In February 2004, Ameren received net proceeds of $853 million from the issuance of 19.1 million common shares. This issuance substantially depleted all of the capacity under Ameren’s August 2002 SEC Form S-3 shelf registration statement. In June 2004, the SEC declared effective a Form S-3 shelf registration statement filed by Ameren covering the offering from time to time of up to $2 billion of various forms of securities including long-term debt, trust preferred securities and equity securities. In July 2004, Ameren issued, pursuant to the June 2004 Form S-3 shelf registration statement, 10.9 million shares of its common stock that generated net proceeds of $445 million. The proceeds from these common share issuances were used to pay the cash portion of the purchase price for Ameren’s acquisition of IP and Dynegy’s 20% interest in EEI. During the first nine months of 2004, these proceeds were temporarily used to repay a $100 million bank term loan at CILCO, repay short term debt of approximately $181 million, and invested in short-term investments. Following the acquisition, Ameren intends to contribute at least $750 million to IP in the form of an equity contribution, $250 million of which was contributed in October 2004. These proceeds will be used by IP to retire debt through the end of 2006, which is discussed below. The proceeds from Ameren’s common stock issuances in the first quarter of 2003 were used to fund a portion of the acquisitions of CILCORP in January 2003 and Medina Valley in February 2003. See Note 2 - Acquisitions and Note 5 - Long-term Debt and Equity Financings to our financial statements under Part I, Item 1 of this rep ort for further information. In
 
 

 
addition, Ameren’s increase in cash flows from financing activities was due to a decrease in redemptions, repurchases and maturities of short-term debt, long-term debt and preferred stock totaling $582 million in the first nine months of 2004 compared to $917 million in the same period in 2003.
 
The increase in cash flows from financing activities at Ameren described above was partially offset by the redemption and termination of UE’s nuclear fuel lease, totaling $67 million in the first nine months of 2004, compared to $38 million in the same period in 2003. Due to the increase in the number of common shares outstanding, Ameren’s dividend payments on common stock increased during the nine months ended September 30, 2004, compared to the same period in 2003, which also caused a decrease in Ameren’s cash flows provided by financing activities.

UE

UE’s cash flows used in financing activities decreased for the nine months ended September 30, 2004, as compared to the same period in 2003. In 2004, cash provided by borrowings from the utility money pool arrangement of $189 million and long-term debt issuances of $404 million were used for repurchases of short-term and long-term debt and the nuclear fuel lease termination payment. The lease agreement, which was scheduled to expire on August 31, 2031, provided for the financing of a portion of UE’s nuclear fuel that was processed for use or was consumed at UE’s Callaway nuclear plant. UE’s decrease in cash flows used in financing activities was partially offset by an increase in dividend payments made to Ameren.

CIPS

CIPS’ cash flows used in financing activities decreased for the nine months ended September 30, 2004, principally due to $60 million of repayments to the utility money pool arrangement in 2004 compared to $23 million of borrowings from the money pool arrangement in 2003. The net decrease in cash provided by the money pool arrangement in 2004 was partially offset by a decrease in redemptions of long-term debt in the first nine months of 2004, compared to the same period in 2003, and reduced dividend contributions to Ameren, which totaled $46 million in the first nine months of 2004, compared to $54 million in the same period of 2003.

Genco

Genco’s cash flows used in financing activities decreased for the nine months ended September 30, 2004, as compared to the same period in 2003, primarily due to increased repayments to the money pool arrangement and increased dividend payments to Ameren totaling $102 million in 2004 compared to $36 million in 2003. The increase in repayments to the money pool arrangement was primarily offset by a capital contribution totaling $75 million received indirectly from Ameren in the third quarter of 2004. The capital contribution received by Genco in the third quarter of 2004 will be for Genco’s prepayment of $75 million of the principal amount outstanding under its intercompany note payable to CIPS.

As of September 30, 2004, Genco had affiliate notes payables of $324 million and $34 million to CIPS and Ameren, respectively, which, by their current terms, have final payments of principal and interest due on May 1, 2005. In November 2004, Genco made a $75 million principal prepayment under its note payable to CIPS. The note payable to CIPS was issued in conjunction with the transfer of its electric generating assets and related liabilities to Genco. Genco and CIPS expect to renew or modify the CIPS note to extend the principal maturity, which could include continued amortization of the principal amount. However, such extension could require regulatory approval. Genco and Ameren are currently evaluating various alternatives with respect to the note payable to Ameren. In the event the maturities of these notes ar e not extended or restructured, whether due to not obtaining the necessary regulatory approvals or otherwise, Genco may need to access other financing sources to meet the maturity obligation to the extent it does not have cash available from its operating cash flows. Such sources of financing could include borrowings under the non state-regulated subsidiary money pool, or infusion of equity capital or new direct borrowings from Ameren, all subject to applicable regulatory financing authorizations and provisions in Genco’s senior note indenture.


 
 

 
CILCORP

CILCORP’s cash flows used in financing activities decreased for the nine months ended September 30, 2004, as compared to the same period in 2003. The decrease was primarily due to a $75 million capital contribution from Ameren and a decrease in repurchases of long-term debt. Borrowings from the utility money pool arrangement, temporarily funded by Ameren’s issuance of common stock in February 2004, were the primary source of funds for the repayment of CILCO’s $100 million secured bank term loan. Dividends were $18 million in 2004 compared to $10 million in 2003.

CILCO

CILCO’s cash flows from financing activities increased for the nine months ended September 30, 2004, as compared to the same period in 2003, primarily due to reduced dividend contributions made to CILCORP in 2004, compared to 2003, and a $75 million capital contribution received indirectly from Ameren in the third quarter of 2004 . CILCO’s increase in cash flows from financing activities was offset by reduced borrowings from the utility money pool arrangement in 2004, compared to the same period in 2003. The proceeds borrowed by CILCO under the utility money pool arrangement, along with available cash in the first quarter of 2004 were used to repay CILCO’s $100 million bank term loan facility.

Short-term Borrowings and Liquidity
 
Short-term borrowings typically consist of commercial paper issuances and drawings under committed bank credit facilities with maturities generally within 1 to 45 days. As of September 30, 2004, certain Ameren subsidiaries had short-term borrowings totaling $30 million, $28 million of which were borrowed by EEI. The average short-term borrowings for Ameren and its subsidiaries were $16 million for the nine months ended September 30, 2004, with a weighted-average interest rate of 1.8%. Peak short-term borrowings for Ameren and its subsidiaries were $44 million for the nine months ended September 30, 2004, with an interest rate of 1.7%. UE, CIPS, Genco, CILCORP and CILCO had no external short-term borrowings as of September 30, 2004 and CIPS, Genco, CILCORP and CILCO had no external short-term borrowings at December 31, 2003. At December 31, 2003, Ameren on a consolidated basis and UE had short-term borrowings outstanding, which totaled $161 million and $150 million, respectively. At the completion of the acquisition of IP on September 30, 2004, IP had no external short-term borrowings outstanding.
 
In July 2004, Ameren entered into two new credit agreements for a total of $700 million in revolving credit facilities to be used for general corporate purposes, including support of Ameren and UE commercial paper programs. The $700 million in new facilities includes a $350 million three-year revolving credit facility and a $350 million five-year revolving credit facility. These new credit facilities replaced Ameren’s existing $235 million 364-day revolving credit facility, which matured on July 14, 2004, and a $130 million multi-year revolving credit facility, which would have matured in July 2005. In September 2004, an existing Ameren $235 million multi-year revolving credit facility, which matures in July 2006, was amended and restated to accommodate Ameren’s acquisition of IP and to conform with its two credit agreements entered into in July 2004.

At September 30, 2004, certain of the Ameren Companies had committed bank credit facilities totaling $1,164 million, all of which were available for use, subject to applicable regulatory short-term borrowing authorizations, by UE, CIPS, CILCO, IP and Ameren Services through a utility money pool arrangement. In addition, $935 million of the $1,164 million was available for use, subject to applicable regulatory short-term borrowing authorizations, by Ameren directly, and by most of the non rate-regulated affiliates including, but not limited to, Resources Company, Genco, Marketing Company, AFS, AERG and Ameren Energy, through a non state-regulated subsidiary money pool agreement. We have money pool agreements with and among our subsidiaries to coordinate and provide for certain short-term cash and working capital re quirements. Separate money pools are maintained between rate-regulated and non rate-regulated entities. On September 30, 2004, our utility money pool agreement was amended to add IP as a party. Also, on September 30, 2004, a unilateral borrowing agreement was entered into between Ameren, IP and Ameren Services, which enables IP to make short-term borrowings directly from Ameren. The aggregate amount of borrowings outstanding at any time by IP under the unilateral borrowing agreement and the utility money pool agreement may not exceed $500 million pursuant to authorizations from the ICC and the SEC, under the PUHCA. Ameren Services is responsible for operation and administration of the agreement. See Note 8 - Related Party Transactions to our financial statements under Part 1, Item 1, of this report for further discussion of the money pool arrangements and the unilateral borrowing agreement. The committed bank credit facilities are used to support our commercial paper programs under
 
 

 
which no amounts were outstanding at September 30, 2004 (December 31, 2003 - $150 million). Access to our credit facilities for any of Ameren’s subsidiaries is subject to reduction based on use by affiliates.
 
The following table presents the various committed credit facilities of the Ameren Companies and EEI as of September 30, 2004:
 

Credit Facility
Expiration
Amount Committed
Amount Available
Ameren:(a)
     
Multi-year revolving
July 2006
           $        235
             $          235
Multi-year revolving
July 2007
                     350
                         350
Multi-year revolving
July 2009
                     350
                         350
UE:
     
Various 364-day revolving
through July 2005
                     154
                         154
CIPS:
     
Two 364-day revolving
through July 2005
                       15
                           15
CILCO:
     
Three 364-day revolving
through August 2005
                        60
                           60
EEI:
     
Two bank credit facilities
through June 2005
                    45
                           17
Total
 
          $       1,209
             $       1,181
(a)   CILCORP and Genco may access the credit facilities through intercompany borrowing arrangements.

In addition to committed credit facilities, a further source of liquidity for the Ameren Companies is available cash and cash equivalents.

Ameren and UE are authorized by the SEC under the PUHCA to have up to an aggregate of $1.5 billion and $1 billion, respectively, of short-term unsecured debt outstanding at any time. In addition, CIPS, CILCORP and CILCO each have PUHCA authority to have up to an aggregate of $250 million each of short-term unsecured debt outstanding at any time. IP has PUHCA authority to have up to an aggregate of $500 million of short-term unsecured debt outstanding at any time. Genco is authorized by the FERC to have up to $300 million of short-term debt outstanding at any time.

Long-term Debt, Preferred Stock and Equity

The following table presents the issuances of common stock and the issuances, redemptions, repurchases and maturities of long-term debt and preferred stock for the nine months ended September 30, 2004 and 2003. For additional information related to the terms and uses of these issuances and the sources of funds and terms for the redemptions, see Note 5 - Long-term Debt and Equity Financings to our financial statements under Part I, Item 1 of this report.


 
Nine Months
Ended  September 30,
 
  Month Issued, Redeemed, Repurchased or Matured
2004
 
2003
 
Issuances
         
Long-term debt
         
UE:
           
5.10% Senior secured notes due 2019

 September

  $
300
 
$
-
 
5.50% Senior secured notes due 2014

 May

   
104
   
-
 
4.75% Senior secured notes due 2015

 April

   
-
   
114
 
5.50% Senior secured notes due 2034

 March

   
-
   
184
 
5.10% Senior secured notes due 2018

 July

   
-
   
200
 
Total Ameren and subsidiary long-term debt issuances
   
$
404
 
$
498
 
Common stock, gross proceeds
               
Ameren:
               
6,325,000 Shares at $40.50

 January

 
$
-
 
$
256
 
19,063,181 Shares at $45.90

 February

   
875
   
-
 
10,925,000 Shares at $42.00

 July

   
459
       
DRPlus and 401(k)(a)

 Various

   
84
   
80
 
Total Ameren common stock issuances
   
$
1,418
 
$
36
 
Total Ameren and subsidiary long-term debt and common stock issuances
   
$
1,822
 
$
834
 


  

 


     
Nine Months
Ended  September 30,
 
 
Month Issued, Redeemed,
Repurchased or Matured
 
2004
 
2003
 
Redemptions, Repurchases and Maturities
           
Long-term debt
           
UE:
           
6.87% First mortgage bonds due 2004
August
 
$
188
 
$
-
 
7.00% First mortgage bonds due 2024
June
   
100
   
-
 
8 ¼% First mortgage bonds due 2022
April
   
-
   
104
 
8.00% First mortgage bonds due 2022
May
   
-
   
85
 
7.65% First mortgage bonds due 2003
July
   
-
   
100
 
7.15% First mortgage bonds due 2023
August
   
-
   
75
 
CIPS:
               
6.99% Series 97-1 first mortgage bonds due 2003
March
 
$
-
 
$
5
 
6 3/8% Series Z first mortgage bonds due 2003
April
   
-
   
40
 
7 1/2% Series X first mortgage bonds due 2007
April
   
-
   
50
 
CILCORP:
               
9.375% Senior bonds due 2029
Various
   
23
   
-
 
8.70% Senior notes due 2009
September
             
CILCO:
               
Secured bank term loan
February
 
$
100
 
$
-
 
6.82% First mortgage bonds due 2003
February
   
-
   
25
 
8.20% First mortgage bonds due 2022
April
   
-
   
65
 
7.80% Two series of first mortgage bonds due 2023
April
   
-
   
10
 
Hallock bank loan due through 2004
August
         
3
 
Kickapoo bank loan due through 2004
August
         
2
 
EEI:
               
2000 bank term loan due 2004
June
 
$
40
 
$
-
 
Medina Valley:
               
Secured term loan due 2019
June
 
$
-
 
$
36
 
                 
Preferred Stock
               
CILCO:
               
5.85% Series
July
 
$
1
 
$
1
 
Total Ameren and subsidiary long-term debt and preferred stock redemptions, repurchases and maturities
   
$
452
 
$
649
 
(a)   Includes issuances of common stock of 1.8 million shares in the first nine months of 2004 and 1.9 million shares in the first nine months of 2003 under our DRPlus and in connection with our 401(k) plans.
 
Ameren

In February 2004, Ameren issued, pursuant to an August 2002 SEC Form S-3 shelf registration statement, 19.1 million shares of its common stock at $45.90 per share for net proceeds of $853 million. This issuance substantially depleted all of the capacity under the August 2002 shelf registration statement. In June 2004, the SEC declared effective a Form S-3 shelf registration statement filed by Ameren covering the offering from time to time of up to $2 billion of various types of securities including long-term debt, trust preferred securities and equity securities. In July 2004, Ameren issued, pursuant to the June 2004 Form S-3 shelf registration statement, 10.9 million shares of its common stock at $42.00 per share for net proceeds of $445 million. The proceeds from bot h these offerings were used to pay the cash portion of the purchase price for our acquisition of IP and Dynegy's 20% interest in EEI and, as described below, are expected to be used to reduce IP debt assumed as part of the acquisition and to pay any related premiums. See Note 2 - Acquisitions to our financial statements under Part I, Item 1 of this report for further information.

Ameren may sell all, or a portion of the remaining securities registered under the June 2004 shelf registration statement if warranted by market conditions and capital requirements. Any offer and sale will be made only by means of
 
 

 
prospectus meeting the requirements of the Securities Act of 1933 and the rules and regulations thereunder. At October 31, 2004, the amount remaining under the June 2004 shelf registration statement was $1.5 billion.
 
In March 2004, the SEC declared effective a Form S-3 registration statement filed by Ameren in February 2004, authorizing the offering of six million additional shares of its common stock under DRPlus. Shares of common stock sold under DRPlus are, at Ameren’s option, newly issued shares or treasury shares, or shares purchased in the open market or in privately negotiated transactions. Ameren is currently selling newly issued shares of its common stock under DRPlus. For the nine months ended September 30, 2004, Ameren issued 1.8 million new common shares valued at approximately $84 million under its DRPlus and its 401(k) plans to be used for general corporate purposes.

The purchase of IP on September 30, 2004, included the assumption of IP debt and preferred stock at closing of approximately $1.8 billion. The assumed debt and preferred stock included $936 million of first mortgage bonds, $509 million of pollution control indebtedness supported by mortgage bonds, $352 million of TFNs issued by IP SPT and $13 million of preferred stock. Upon acquisition, total IP debt was increased to fair value by approximately $191 million, which included early debt redemption premiums. The adjustment to the fair value of each debt series is being amortized over its remaining life or to the expected redemption date, to interest expense.

In October 2004, pursuant to an equity clawback provision of the related bond indenture, IP unconditionally called for redemption on November 15, 2004, $192.5 million in principal amount of its mortgage bonds 11.50% Series due 2010 at a price equal to $1,115 per $1,000 principal amount of bonds, together with accrued and unpaid interest to the redemption date. Ameren made an equity contribution of $250 million into IP to provide funds for this purpose and to satisfy indenture provisions related to the equity clawback. Also in October 2004, IP made a cash tender offer for the remaining mortgage bonds 11.50% Series due 2010 ($357.5 million in aggregate principal amount). The purchase price will be determined, as described in the offer to purchase, in accordance with standard market practice by reference to a yield of 50 basis points over the yield on the 2.625% U.S. Treasury Note due November 15, 2006, on the price determination date, scheduled for November 18, 2004. The tender offer is scheduled to expire on November 22, 2004. This tender offer is also intended to satisfy IP’s indenture obligation to offer to purchase the bonds resulting from the change of control of IP with its acquisition by Ameren.  Any such bonds tendered will be purchased with cash contributed as equity to IP by Ameren.

In addition, in October 2004, IP called for redemption on December 1, 2004, the following indebtedness: (i) all $65.6 million principal amount of its outstanding 7.50% Series due 2025  mortgage bonds at a redemption price of 103.105% of the principal amount plus accrued interest and (ii) all $84.2 million principal amount of the Illinois Development Finance Authority’s Pollution Control Refunding Revenue Bonds, 1994 7.40% Series B due 2024 at a redemption price of 102% of the principal amount plus accrued interest. This indebtedness will be redeemed with cash contributed as equity contributed to IP by Ameren.

UE

UE issued securities totaling $404 million in 2004, pursuant to its September 2003 SEC Form S-3 shelf registration statement with the amount of securities remaining available for issuance at September 30, 2004, under such registration statement, totaling $396 million.

Indebtedness Provisions, Other Covenants and Off-Balance Sheet Arrangements

See Note 4 - Short-term Borrowings and Liquidity to our financial statements under Part I, Item 1 of this report for a discussion of the indebtedness provisions contained in certain of the Ameren Companies’ bank credit facilities. Also see Note 5 - Long-term Debt and Equity Financings to our financial statements under Part I, Item 1 of this report for a discussion of off-balance sheet arrangements and of the covenants and provisions contained in certain of the Ameren Companies’ and IP’s indenture agreements and articles of incorporation.
 
At September 30, 2004, the Ameren Companies, IP and EEI were in compliance with the provisions and covenants of their credit agreements, indentures and articles of incorporation.

We rely on the short-term and long-term capital markets as a significant source of funding for capital requirements not satisfied by our operating cash flows. Our inability to raise capital on favorable terms, particularly during times of uncertainty in the capital markets, could negatively impact our ability to maintain or grow our businesses. Based on our current credit ratings, we believe that we will continue to have access to the capital markets. However, events beyond
 
 

 
our control may create uncertainty in the capital markets such that our cost of capital would increase and/or our ability to access the capital markets would be adversely affected. All of the Ameren Companies and IP expect to fund maturities of long-term debt and contractual obligations through a combination of cash flow from operations and external financing.
 
Dividends

The amount and timing of dividends payable on Ameren’s common stock are within the sole discretion of Ameren’s Board of Directors. Ameren’s Board of Directors has not set specific targets or payout parameters when declaring common stock dividends. However, the Board considers various issues including Ameren’s historic earnings and cash flow, projected earnings, cash flow and potential cash flow requirements, dividend payout rates at other utilities, return on investments with similar risk characteristics and overall business considerations. Dividends paid by Ameren to stockholders during the first nine months of 2004 totaled $356 million, or $1.905 per share (2003 - $308 million or $1.905 per share). On October 8, 2004, Ameren declared a quarterly d ividend of 63.5 cents, payable December 31, 2004, to shareholders of record on December 8, 2004.

IP’s Board of Directors declared quarterly preferred stock dividends totaling $1 million payable November 1, 2004, to shareholders of record on October 11, 2004.

Certain of our financial agreements and corporate organizational documents contain covenants and conditions that, among other things, provide restrictions on the Ameren Companies’ and IP’s payment of dividends. Ameren would experience restrictions on dividend payments if it were to defer contract adjustment payments on its equity security units. UE would experience restrictions on dividend payments if it were to extend or defer interest payments on its subordinated debentures. CIPS has provisions restricting dividend payments based on ratios of common stock to total capitalization along with provisions related to certain operating expenses and accumulations of earned surplus. Genco’s indenture includes restrictions which prohibit making any dividend paym ents if debt service coverage ratios are below a defined threshold. CILCORP has restrictions in the event leverage ratio and interest coverage ratio thresholds are not met or if CILCORP’s senior long-term debt does not have specified ratings as described in its indenture. CILCO has restrictions on dividend payments relative to the ratio of its balance of retained earnings to the annual dividend requirement on its preferred stock and amounts to be set aside for any sinking fund retirement of its 5.85% Series preferred stock. In its approval of the acquisition of IP by Ameren, the ICC issued an order which restricts the payment of dividends on its common stock to $80 million in 2005 and $160 million cumulatively through 2006, provided IP has achieved an investment grade credit rating from S&P or Moody’s. If IP’s mortgage bonds 11.50% Series due 2010 are not eliminated by December 31, 2006, IP may not thereafter declare or pay common dividends without seeking authority from the ICC. In additi on, in accordance with the order issued by the ICC, IP will establish a dividend policy comparable to the dividend policy of Ameren’s other Illinois utilities consistent with achieving and maintaining a common equity to total capitalization ratio between 50% and 60%.

The following table presents dividends paid directly or indirectly to Ameren by its subsidiaries for the nine months ended September 30, 2004 and 2003:
 

   
Nine Months Ended September 30,
 
   
2004
 
2003
 
UE
 
$
230
 
$
224
 
CIPS
   
46
   
54
 
Genco
   
57
   
22
 
CILCORP (parent company only)(a)
   
   
(34
)
CILCO
   
10
   
44
 
Non-registrants
   
13
   
-
 
Dividends paid to Ameren
 
$
356
 
$
310
 
(a)   Indicates funds retained from CILCO dividend.
 
Contractual Obligations

The following table presents our December 31, 2003 contractual obligations, which have been updated to include IP contractual obligations subsequent to September 30, 2004. In addition, our other obligations were only updated for any material changes since December 31, 2003. For a complete listing of our obligations and commitments, see Contractual Obligations under Part II, Item 7 and Note 15 - Commitments and Contingencies under Part II, Item 8 of the Ameren Companies’ combined Form 10-K for the fiscal year ended December 31, 2003. See Note 12 - Pension and
 

 

 

 
Other Postretirement Benefits to our financial statements under Part I, Item 1 of this report for information regarding expected minimum funding levels for our pension plan.

   
 
Total
 
2004
 
2005 - 2006
 
2007 - 2008
 
Thereafter
 
Ameren(a):
                               
Long-term debt and capital lease obligations(b)
 
$
6,449
 
$
263
 
$
466
 
$
783
 
$
4,937
 
Short-term debt
   
31
   
31
   
-
   
-
   
-
 
Interest payments(c)
   
4,624
   
316
   
762
   
645
   
2,901
 
Operating leases(d)
   
211
   
24
   
39
   
31
   
117
 
Other obligations(e)
   
4,266
   
1,279
   
1,914
   
842
   
231
 
Total cash contractual obligations(f)    
 
$
15,581
 
$
1,913
 
$
3,181
 
$
2,301
 
$
8,186
 
UE:
                               
Long-term debt and capital lease obligations
 
$
2,154
 
$
88
 
$
6
 
$
156
 
$
1,904
 
Short-term debt
   
-
   
-
   
-
   
-
   
-
 
Interest payments(c)
   
1,496
   
99
   
182
   
175
   
1,040
 
Operating leases(d)
   
128
   
9
   
19
   
18
   
82
 
Other obligations(e)
   
1,736
   
501
   
751
   
403
   
81
 
Total cash contractual obligations(f)    
 
$
5,514
 
$
697
 
$
958
 
$
752
 
$
3,107
 
CIPS:
                               
Long-term debt
 
$
486
 
$
20
 
$
20
 
$
15
 
$
431
 
Short-term debt
   
-
   
-
   
-
   
-
   
-
 
Interest payments
   
425
   
31
   
59
   
56
   
279
 
Operating leases(d)
   
-
   
-
   
-
   
-
   
-
 
Other obligations(e)
   
174
   
79
   
89
   
6
   
-
 
Total cash contractual obligations(f)    
 
$
1,085
 
$
130
 
$
168
 
$
77
 
$
710
 
Genco:
                               
Long-term debt
 
$
700
 
$
-
 
$
225
 
$
-
 
$
475
 
Short-term debt
   
-
   
-
   
-
   
-
   
-
 
Interest payments
   
769
   
56
   
92
   
78
   
543
 
Operating leases(d)
   
42
   
2
   
5
   
4
   
31
 
Other obligations(e)
   
936
   
205
   
365
   
262
   
104
 
Total cash contractual obligations(f)    
 
$
2,447
 
$
263
 
$
687
 
$
344
 
$
1,153
 
CILCORP:
                               
Long-term debt(b)
 
$
641
 
$
-
 
$
16
 
$
50
 
$
575
 
Short-term debt
   
-
   
-
   
-
   
-
   
-
 
Interest payments
   
730
   
47
   
93
   
86
   
504
 
Operating leases(d)
   
9
   
2
   
3
   
2
   
2
 
Other obligations(e)
   
494
   
209
   
200
   
71
   
14
 
Total cash contractual obligations(f)    
 
$
1,874
 
$
258
 
$
312
 
$
209
 
$
1,095
 
CILCO:
                               
Long-term debt
 
$
138
 
$
-
 
$
16
 
$
50
 
$
72
 
Short-term debt
   
-
   
-
   
-
   
-
   
-
 
Interest payments
   
98
   
9
   
17
   
10
   
62
 
Operating leases(d)
   
9
   
2
   
3
   
2
   
2
 
Other obligations(e)
   
494
   
209
   
200
   
71
   
14
 
Total cash contractual obligations(f)    
 
$
739
 
$
220
 
$
236
 
$
133
 
$
150
 
(a)   Includes amounts for registrant and non-registrant Ameren subsidiaries, including IP, and intercompany eliminations.
(b)   Includes fair market value adjustments of long-term debt for IP and CILCORP totaling $191 million and $85 million, respectively.
(c)   The variable rate debt has been calculated using the interest rate as of September 30, 2004.
(d)   Amounts related to certain real estate leases and railroad licenses have indefinite payment periods. The $2 million annual obligation for these items is included in the 2004, 2005 - 2006 and 2007 - 2008 columns. Amounts for more than 5 years are not included in the total amount due to the indefinite periods.
(e)   Represents purchase contracts for coal, gas, nuclear fuel and electric capacity for the Ameren Companies. Also includes power purchase agreements, contracts for firm transportation and storage services for natural gas, gas purchase commitments and decommissioning obligations at IP.
(f)   Routine short-term purchase order commitments are not included.
        

 

 

Credit Ratings

On July 30, 2004, S&P affirmed its A- long-term corporate credit ratings on Ameren, UE, CIPS, Genco, CILCORP and CILCO and removed the ratings from CreditWatch with negative implications. The A-2 short-term credit for Ameren and UE were not on CreditWatch. The outlook is negative for the long-term ratings.

On July 8, 2004, Moody’s confirmed Ameren’s A3 senior unsecured debt and bank loan ratings along with its A3 issuer rating. Moody’s outlook for these ratings is stable. This rating action concluded the review of Ameren's long-term ratings that was initiated on February 4, 2004 in connection with Ameren's agreement to purchase IP from Dynegy. Ameren's Prime-2 rating for short term debt, including commercial paper, was not under review, and was affirmed. 

On October 1, 2004, S&P raised it corporate credit rating on IP from B to A- as a result of the completed acquisition of IP by Ameren. At the same time, S&P removed the rating from CreditWatch with positive implications and assigned a negative outlook to the rating. Also on this date, Moody’s upgraded the senior secured debt rating of IP from Ba3 to Baa3 also as a result of the closing of the acquisition. Moody’s has a stable outlook assigned to this rating. The new ratings assigned to IP by S&P and Moody’s are investment grade.

Any adverse change in the Ameren Companies’ or IP’s credit ratings may reduce their access to capital and/or increase the costs of borrowings resulting in a negative impact on earnings. At September 30, 2004, if the Ameren Companies were to receive a sub-investment grade rating (less than BBB- or Baa3), Ameren, UE, CIPS, Genco, CILCORP and CILCO could have been required to post collateral for certain trade obligations amounting to $57 million, $21 million, $-, $4 million, $1 million and $1 million, respectively. In addition, the cost of borrowing under our credit facilities would increase or decrease based on credit ratings. A credit rating is not a recommendation to buy, sell or hold securities and should be evaluated independently of any other rating. Ratin gs are subject to revision or withdrawal at any time by the assigning rating organization.


OUTLOOK

We expect the following industry-wide trends and company-specific issues to impact earnings in 2004 and beyond:
  • Economic conditions, which principally impact native load demand, particularly from our industrial customers, were weak for the past few years, but have improved in 2003 and 2004.
  • Ameren, UE, CIPS and IP have historically achieved weather-adjusted growth in their native electric residential and commercial load of approximately 2% per year and expect this trend to continue for at least the next few years.
  • Electric rates in UE’s, CIPS’, CILCO’s and IP’s Illinois service territories are legislatively fixed through January 1, 2007. An electric rate case settlement in UE’s Missouri service territory has resulted in annual reductions of $50 million, $30 million and $30 million on April 1, 2002, April 1, 2003, and April 1, 2004, respectively. In addition, electric rates in Missouri cannot change prior to July 1, 2006, subject to certain exclusions outlined in UE’s rate settlement.
  • The ICC conducted workshops in 2004 seeking input from interested parties on the framework for retail rate determination and the framework for generation procurement by customers after the current Illinois rate freeze ends in 2006. We actively participated in these workshops and supported a framework that would have all regulated Illinois electric transmission and distribution companies bid out their native load requirements for generation through an auction process.  We have also supported a structure that provides for recovery from customers of the generation costs resulting from that auction.  We expect the ICC to issue a report on the workshop process later this year, but we do not believe the ICC will make decisions on the final regulatory structure until sometime in 2005, after Ameren and other comp anies submit filings detailing their post-2006 plans.
  • Power prices in the Midwest impact the amount of revenues UE, Genco and CILCO can generate by marketing any excess power into the interchange markets. Power prices in the Midwest also impact the cost of power we purchase in the interchange markets. There continues to be overcapacity in peaking generation in the Midwest. However, power prices increased in 2004 and 2003 relative to 2002, due in part to higher prices for natural gas.
  • We expect to see increases in both the commodity cost of coal and transportation costs based on current market trends.  In 2005 and 2006, we expect these increases to approximate two to three percent per year based on the fixed prices embedded in our contracts.
  

 
  • Increased expenses associated with rising employee benefit costs and higher insurance and security costs associated with additional measures UE has taken, or may have to take, at its Callaway nuclear plant and other operating plants related to world events.
  • UE’s Callaway nuclear plant will have a refueling outage in the fall of 2005. Refueling outages occur approximately every 18 months and typically include the replacement of fuel and the performance of maintenance and inspections. Routine refueling outages have historically lasted 30 - 35 days. If inspections discover items requiring additional maintenance, the outage period could be longer, and cost significantly more, than expected. UE’s fall 2005 refueling outage is expected to last 70 - 75 days and is expected to be higher in cost due to the installation of new steam generator units and turbine rotors.
  • In January 2004, the MoPSC approved a settlement with UE authorizing an annual gas delivery rate increase of approximately $13 million, which went into effect on February 15, 2004. The settlement provides that gas delivery rates cannot change prior to July 1, 2006, subject to certain exclusions. In October 2003, the ICC issued orders awarding CILCO an increase in annual gas delivery rates of $9 million and awarding CIPS and UE increases in annual gas delivery rates of $7 million and $2 million, respectively which went into effect in November 2003. IP has filed with the ICC for a $36 million gas rate increase. The ICC must make a decision by May 2005.  In the order approving Ameren's acquisition of IP, the ICC prohibits IP from filing for any proposed increase in gas delivery rates to be effective prior to January 1, 2007, beyond IP's pending request for a gas delivery rate increase.
  • Ameren, UE, CIPS and IP will incur higher ongoing operational costs and may lose some revenue as a result of participating in the Midwest ISO. See Note 3 - Rate and Regulatory Matters to our financial statements under Part I, Item 1 of this report for additional information.
  • Ameren, CILCORP and CILCO expect to realize further CILCORP integration synergies associated with reduced overhead expenses and lower fuel costs.
  • Ameren expects the acquisition of IP to be accretive to earnings in the first two years of ownership based on a variety of assumptions related to power prices, interest rates and expected synergies, among other things.
In the ordinary course of business, we evaluate strategies to enhance our financial position, results of operations and liquidity. These strategies may include potential acquisitions, divestitures, and opportunities to reduce costs or increase revenues, and other strategic initiatives in order to increase Ameren’s shareholder value. We are unable to predict which, if any, of these initiatives will be executed, as well as the impact these initiatives may have on our future financial position, results of operations or liquidity; however, the impact could be material.


RISK FACTORS

Ameren may not be able to successfully integrate IP into its other businesses or achieve the benefits it anticipates.

Ameren cannot assure you that it will be able to successfully integrate IP with its other businesses. The integration of IP with its other businesses will present significant challenges and, as a result, Ameren may not be able to operate the combined company as effectively as expected. Ameren may also fail to achieve the anticipated benefits of the acquisition as quickly or as cost effectively as anticipated or may not be able to achieve those benefits at all. Ameren expects that this acquisition will be accretive to earnings per share. This expectation is based on important assumptions, including assumptions related to expected financing arrangements, interest rates, market prices for power and synergies, which may ultimately be incorrect. As a result, if Ameren is unable to integrate its businesses effectively o r achieve the benefits anticipated, our financial position, results of operations and liquidity may be materially adversely affected.

The electric and gas rates that certain of the Ameren Companies and IP are allowed to charge in Missouri and Illinois are largely set through 2006. This “rate freeze,” along with other actions of regulators, can significantly affect our earnings, liquidity and business activities and are largely outside our control.

The rates that certain of the Ameren Companies and IP are allowed to charge for their services are the single most important item influencing the financial position, results of operations and liquidity of the Ameren Companies and IP. We are highly regulated and the regulation of the rates that we charge our customers is determined, in large part, outside of our control by governmental organizations, including the MoPSC, the ICC and the FERC. We are also subject to regulation by the SEC under the PUHCA. Decisions made by these regulators could have a material impact on our financial position, results of operations and liquidity.
 
 

 
 

As a part of the settlement of UE’s Missouri electric rate case in 2002, UE is subject to a rate moratorium providing for no changes in its electric rates in Missouri before July 1, 2006, subject to limited statutory and other exceptions. A rate reduction of $30 million went into effect on April 1, 2004, which is the last portion of the $110 million rate reduction included in the stipulation entered into as part of the settlement of the Missouri electric rate case. In addition, as a provision of the Illinois legislation related to the restructuring of the Illinois electric industry, a rate freeze is in effect in Illinois until January 1, 2007. This Illinois legislation also contains a provision requiring that earnings from the Illinois jurisdiction in excess of certain levels be shared equally with UE’s, CIPS’, CILCO’s and IP’s Illinois customers through 2006. Furthermore, as part of the settlement of UE’s Missouri gas rate case, which was approved by the MoPSC on January 13, 2004, UE agreed to a rate moratorium providing for no changes in its gas delivery rates prior to July 1, 2006, subject to certain exceptions (the increased rates approved as part of the settlement became effective on February 15, 2004). Also, in the order approving Ameren’s acquisition of IP, the ICC prohibits IP from filing for any proposed increase in gas delivery rates to be effective prior to January 1, 2007, beyond IP’s pending request for a gas delivery rate increase. The ICC conducted workshops seeking input from interested parties on the framework for retail rate determination and the framework for generation procurement by customers after the current Illinois rate freeze ends in 2006. We believe the ICC will make a decision on these matters in 2005.

As a part of the settlement of UE’s Missouri electric rate case in 2002, UE also undertook to use commercially reasonable efforts to make critical energy infrastructure investments of $2.25 billion to $2.75 billion from January 1, 2002 through June 30, 2006, including, among other things, the addition of more than 700 megawatts of new generation capacity (240 megawatts of which was added in 2002) and the replacement of steam generators at UE’s Callaway nuclear plant. The amount of energy infrastructure investment through June 2006, described in the settlement is consistent with UE’s previously disclosed estimate of construction expenditures UE expects to make over the same time period. Ameren also committed IP to make between $275 million and $325 million in energy infrastructure inve stments over its first two years of ownership in conjunction with the ICC’s approval of Ameren’s acquisition of IP. UE’s agreement to a rate moratorium and IP’s rate freeze will result in these capital expenditures not becoming recoverable in rates, or earning a return, before July 1, 2006 for UE, and January 1, 2007, for IP. Therefore, UE’s and IP’s undertakings with respect to making energy infrastructure investments and funding new programs, coupled with the rate reductions and rate moratoriums described above, could result in increased financing requirements for UE or IP and thus have a material impact on our liquidity.

The Ameren Companies and IP do not have the benefit of a fuel adjustment clause in either Missouri or Illinois for their electric operations that would allow them to recover increased fuel and power costs from customers. Therefore, to the extent that we have not hedged our fuel and power costs, we are exposed to changes in fuel and power prices to the extent fuel for our electric generating facilities and power must be purchased on the open market in order for us to serve our customers.

Steps taken and being considered at the federal and state levels continue to change the structure of the electric industry and utility regulation. At the federal level, the FERC has been mandating changes in the regulatory framework in which transmission-owning public utilities, such as UE, CIPS, CILCO and IP operate. In Missouri, restructuring bills have been introduced in the past, but no legislation has been passed. In Illinois, where with the completion of the acquisition of IP, over 50% of Ameren’s electric revenues are derived, the Illinois Customer Choice Law provides for electric utility restructuring and retail direct access. Retail direct access, which allows customers to choose their electric generation supplier, was first offered to Illinois residential customers on May 1, 2002. Although reta il direct access in Illinois has not had a negative effect on Ameren’s revenues or liquidity, we expect competitive forces in the electric supply segment of our business to continue to increase.

The potential negative consequences associated with further electric industry restructuring in our service territories, if it occurs, could be significant and could include the impairment and writedown of certain assets, including generation related plant and net regulatory assets, lower revenues, reduced profit margins and increased costs of capital and operations expenses.

We are not able to predict what rate treatment certain of the Ameren Companies and IP will receive following the expiration of the rate moratorium in each of Missouri and Illinois. Some of the factors which influence rates are largely outside our control. In response to competitive, economic, political, legislative and /or regulatory pressures we may have to agree to further rate moratoriums, rate refunds or rate reductions, any and all of which could have a significant adverse affect on our earnings, liquidity and business activities.
 

 
 

 
 
 
Increased federal and state environmental regulation could require UE, Genco and CILCO to incur large capital expenditures and increase operating costs.

Approximately 65% of Ameren’s generating capacity is coal-fired. The balance is nuclear, gas-fired, hydro and oil-fired. The EPA has recently issued proposed regulations with respect to SO2, NOx and mercury emissions from coal-fired power plants. These new rules, if adopted, would require significant additional reductions in these emissions from our power plants in phases, beginning in 2010. The rules are currently under a public re view and comment period, and may change before being issued as final late in 2004 or early 2005. Preliminary estimates of capital costs based on current technology on the Ameren systems to comply with the SO2, NOx and mercury rules, as proposed, range from $1.1 billion to $1.4 billion by 2010, with an additional $375 million to $510 million by 2015.

In addition, Illinois has developed a NOx control regulation for utility generating plant boilers consistent with an EPA program aimed at reducing ozone levels in the eastern United States. In the spring of 2004, the EPA issued similar rules for Missouri. Ameren and UE currently estimate that the remaining capital expenditures could range from $160 million to $180 million between 2005 and 2008 in order to comply with the final NOx regulations in Missouri. This estimate includes the assumption that these rules will require the installation of selective catalytic reduction technology on some units, as well as additional controls.

We are unable to predict the ultimate effect of any new environmental regulations, guidelines, enforcement initiatives or legislation on our financial position, results of operations or liquidity. Any of these factors would add significant pollution control costs to UE’s, Genco’s and CILCO’s generating assets and, therefore, could also increase financing requirements for some of the Ameren Companies. While costs incurred by UE would be eligible for recovery in rates, subject to MoPSC or ICC approval, as applicable, there is no similar mechanism for recovery of costs by Genco or CILCO in Illinois.

UE’s, CIPS’, CILCO’s and IP’s participation in a RTO could increase costs, reduce revenues and reduce UE’s, CIPS’, CILCO’s and IP’s control over their transmission assets.

In December 1999, the FERC issued Order 2000 requiring all utilities subject to FERC jurisdiction to state their intentions for joining a RTO. The MoPSC issued an order in early 2004 authorizing UE to participate in the Midwest ISO for a five year period, with participation after that period subject to further approvals by the MoPSC. Subsequently, the FERC issued a final order allowing UE’s and CIPS’ participation in the Midwest ISO. Under these orders, the MoPSC continues to set the transmission component of UE’s rates to serve its bundled retail load. CILCO is already a member of the Midwest ISO and transferred functional control of its transmission system to the Midwest ISO prior to our acquisition of CILCO.

On May 1, 2004, functional control of the UE and CIPS transmission systems was transferred to the Midwest ISO through GridAmerica LLC.  On September 30, 2004, prior to the completion of Ameren’s acquisition of IP as required by the FERC order approving the acquisition, IP transferred functional control of its transmission system to the Midwest ISO. The participation by UE, CIPS and IP in the Midwest ISO is expected to increase annual costs by $10 million to $25 million in the aggregate and could result in a decrease in annual revenues of between $5 million and $15 million in the aggregate. UE, CIPS, CILCO and IP may also be required to expand their transmission systems according to decisions made by a RTO rather than their internal planning process. In addition, we are unable to determine the full impact of the Midwest ISO’s Energy Markets Tariff accepted by the FERC in August 2004 (discussed in Note 3 - Rate and Regulatory Matters to our financial statements under Part I, Item 1 of this report) until further information is available regarding the implementation of the Energy Markets Tariff.

Until UE, CIPS, CILCO and IP achieve some degree of operational experience participating in the Midwest ISO, we are unable to predict the ultimate impact that such participation or ongoing RTO developments at the FERC or other regulatory authorities will have on our financial position, results of operations or liquidity.


 
 

 

The inability of UE, CIPS, CILCO and IP to recover “through and out” transmission revenues could result in a material net revenue reduction.
 
Through orders issued during late 2003 and early 2004, the FERC had ordered the elimination of regional through-and-out rates assessed by the Midwest ISO that involved transmission service between the Midwest ISO and PJM regions to be effective May 1, 2004. However, on March 19, 2004, the FERC accepted an agreement among affected transmission owners that retains the regional through-and-out rates until December 1, 2004, and provides for continued negotiations aimed at developing a long-term transmission pricing structure to eliminate seams between the PJM and Midwest ISO regions based on specified pricing principles. Until the long-term transmission pricing structure has been established, UE, CIPS, CILCO and IP cannot predict the ultimate impact that such structure will have on their costs and revenues.
 
The substance and implementation of standard market design rules by the FERC is uncertain and may adversely affect the way in which UE, CIPS, CILCO and IP operate their transmission assets.

On July 31, 2002, the FERC issued its standard market design NOPR. The NOPR proposes a number of changes to the way the current wholesale transmission service and energy markets are operated. Specifically, the NOPR proposes that all jurisdictional transmission facilities be placed under the control of an independent transmission provider (similar to a RTO), proposes a new transmission service tariff that provides a single form of transmission service for all users of the transmission system including bundled retail load, and proposes a new energy market and congestion management system that uses locational marginal pricing as its basis. In our initial comments on the NOPR, which were filed at the FERC on November 15, 2002, we expressed our concern with the potential impact of the proposed rules in their current form on the cost and reliability of service to retail customers. We also proposed that certain modifications be made to the proposed rules in order to protect transmission owners from the possibility of trapped transmission costs that might not be recoverable from ratepayers as a result of inconsistent regulatory policies. We filed additional comments on the remaining sections of the NOPR during the first quarter of 2003.

In April 2003, the FERC issued a “white paper” reflecting comments received in response to the NOPR. More specifically, the white paper indicated that the FERC will not assert jurisdiction over the transmission rate component of bundled retail service and will insure that existing bundled retail customers retain their existing transmission rights and retain rights for future load growth in its final rule. Moreover, the white paper acknowledged that the final rule will provide the states with input on resource adequacy requirements, allocation of firm transmission rights, and transmission planning. The FERC also requested input on the flexibility and timing of the final rule’s implementation.

Although issuance of the final rule is uncertain and its implementation schedule is still unknown, the Midwest ISO is in the process of implementing a separate market design similar to the proposed market design in the NOPR. In July 2003, the Midwest ISO filed with the FERC a revised OATT codifying the terms and conditions under which it will implement the new market design. Thereafter, on October 17, 2003, the Midwest ISO filed a motion to withdraw its revised OATT. On October 29, 2003, the FERC issued a series of orders granting the motion for withdrawal of the revised OATT and providing guidance to be followed by the Midwest ISO in developing a new energy market design in the future. In March 2004, the Midwest ISO tendered for filing at the FERC a proposed Energy Markets Tariff, which is intended to supercede its existing OATT (see Note 3 - Rate and Regulatory Matters to our financial statements under Item I, Part 1 of this report). In August 2004, the FERC accepted the Midwest ISO’s Energy Market Tariff subject to further compliance filings. On November 8, 2004, the FERC issued an order denying the requests for rehearing that were filed by a number of Midwest ISO stakeholders including Ameren.  However, a final order from the FERC on the compliance filings made by the Midwest ISO in response to the FERC's August 6 order is still pending.  Until the FERC issues a final rule and the Midwest ISO finalizes its new market design, we are unable to predict the ultimate impact of the NOPR or the Midwest ISO new market design on our future financial position, results of operations or liquidity.

The market-based rate authority currently held by UE, CIPS, Genco, CILCO, AERG, Development Company, Marketing Company and Medina Valley could be partially revoked as a result of FERC’s new market power analysis screen order.  
 
In an order issued in April 2004, the FERC replaced the Supply Margin Assessment Screen previously used to review applications by sellers of electricity at wholesale for authorization to sell power at market-based rates with two alternative measures of market power:  (a) an uncommitted pivotal supplier analysis and (b) an uncommitted market share analysis which is to be prepared on a seasonal basis.  If an applicant passes both screens, a rebuttable presumption will exist that it lacks generation market power.  If the applicant fails either screen, a rebuttable presumption will exist
 
 

 
 
that it has market power.  Under such circumstances, the applicant may either seek to rebut the presumption by preparing a delivered price test (identifying the amount of economic capacity from neighboring areas that can be delivered to the control area) or propose mitigation measures.  Unless some other mitigation measure is adopted, the applicant’s authority to sell power at market-based rates in areas in which it has market power will be revoked, and the applicant will be required to sell at cost-based rates in those areas.
 
UE, Genco, CIPS, CILCO, AERG, Development Company, Marketing Company and Medina Valley currently have authorization from the FERC to continue to sell power at market-based rates.  However, the FERC indicated in its April order that it would apply the new market analysis screens to pending and future market-based rate applications, including three-year market-based rate reviews.  All of the aforementioned Ameren entities currently have three-year market-based rate reviews pending at the FERC. 

As required, these Ameren companies will file an updated market power analysis with FERC in December 2004.  This updated analysis will include the results of FERC’s new screens.  These companies will apply the new screens both on the basis of individual control area markets and also on the basis of the entire Midwest ISO footprint.  We understands that the individual control area analyses will be applicable for a limited time until Midwest ISO implements its "Day 2" markets, now scheduled for March 1, 2005, and that the Midwest ISO footprint analyses will be applicable after that time.  We expects that UE and AERG will fail one of the new screens, the wholesale market share screen, in the UE/CIPS and CILCO control areas, respectively, but pass it in all other control areas and, as wel l, pass the other new screen measure, the pivotal supplier screen, in all of the individual control areas that we are required to study.  We further anticipates that we will pass both screen measures for the larger market consisting of the entire Midwest ISO footprint.  We are unable to anticipate how or when FERC will respond to any screen failure by an Ameren company for the interim period before the start of Midwest ISO Day 2 markets.  Further, until we have finalized our updated analysis, we are unable to predict how the FERC will resolve a number of related issues, including resolution of evidence available to rebut any screen results indicating a failure, and resolution of any proposed mitigation measures.  Finally, we are unable to predict the ultimate impact the new screens will have on our ability to sell power at market-based rates.

Increasing costs associated with our defined benefit retirement plans, healthcare plans and other employee related benefits may adversely affect our results of operations, liquidity and financial position.

The Ameren Companies made cash contributions totaling $25 million and $31 million to defined benefit retirement plans during 2003 and 2002, respectively. In addition, a minimum pension liability was recorded at December 31, 2002, which resulted in an after-tax charge to OCI and a reduction in stockholders’ equity for Ameren of $102 million. At December 31, 2003, the minimum pension liability was reduced, resulting in OCI of $46 million and an increase in stockholders’ equity. In the third quarter of 2004, we made a contribution of $295 million to our pension plans. In light of this contribution and the acquisition of IP, future required contributions over the period from 1005 to 2008 are now expected to aggregate $400 million to be paid in 2008 and 2009. This amount is an estimate and may change based on actual stock market performance, changes in interest rates, and any pertinent changes in government regulations, each of which could also result in a requirement to record an additional minimum pension liability.

In addition to the costs of our retirement plans, the costs to us of providing healthcare benefits to our employees and retirees have increased substantially in recent years. We believe that our employee benefit costs, including costs related to healthcare plans for our employees and former employees, will continue to rise. The increasing costs and funding requirements associated with our defined benefit retirement plans, healthcare plans and other employee benefits may adversely affect our results of operations, liquidity or financial position.

UE’s, Genco’s and CILCO’s electric generating facilities are subject to operational risks that could result in unscheduled plant outages, unanticipated operation and maintenance expenses and increased power purchase costs.

UE, CILCO, Genco, AERG, Medina Valley and EEI own and operate coal, nuclear, gas-fired, hydro and oil-fired generating facilities constituting approximately 14,800 megawatts (net) of installed capability. Operation of electric generating facilities involves certain risks which can adversely affect energy output and efficiency levels. Included among these risks are:

  • increased prices for fuel and fuel transportation as existing contracts expire,
  • facility shutdowns due to a breakdown or failure of equipment or processes,
  • longer than anticipated maintenance outages,

 

 
  • disruptions in the delivery of fuel and lack of adequate inventories,
  • labor disputes,
  • inability to comply with regulatory or permit requirements,
  • disruptions in the delivery of electricity,
  • increased capital expenditures requirements, including those due to environmental regulation,
  • operator error, and
  • unusual or adverse weather conditions, including catastrophic events such as fires, explosions, floods or other similar occurrences affecting electric generating facilities.
A substantial portion of Genco’s and AERG’s generating capacity is committed under affiliate contracts which expire over the next several years.

Genco and AERG have several electric power supply agreements under which Genco and AERG directly or indirectly supply the full requirements of  CIPS and CILCO, including the following:
  • Under two electric power supply agreements, Genco is obligated to supply to Marketing Company, and Marketing Company, in turn, is obligated to supply to CIPS, all of the energy and capacity needed by CIPS to offer service for resale to its native load customers and to fulfill CIPS’ other obligations under all applicable federal and state tariffs or contracts. Any power not used by CIPS is sold by Marketing Company under various long-term wholesale and retail contracts. The agreement between CIPS and Marketing Company will expire on December 31, 2006. The agreement between Genco and Marketing Company can be terminated by either party upon at least one year’s notice, but may not be terminated prior to December 31, 2004
  • AERG has an electric power supply agreement with CILCO to supply it sufficient power to meet its native load requirements. This agreement expires on December 31, 2006.
Midwest power markets have experienced high levels of new capacity development over the last several years, which, in part, contributed to soft long-term power prices in this region. Owners of generating capacity in the Midwest are actively seeking markets for their energy and capacity and have asked our regulators to closely scrutinize power supply arrangements among our subsidiaries when we have sought approval to enter into them. It cannot be predicted whether obtaining extensions on other long-term replacement power sale contracts for the energy and capacity currently committed under these agreements when they expire will be successful. To the extent Genco or AERG cannot secure extensions or other long-term replacement power sale contracts for the energy and capacity currently committed under these agreements, our generating subsidiaries and Marketing Company will face competition from other power suppliers in the Midwest and will be exposed to price risk.

Genco participates with UE in an agreement to jointly dispatch its generating facilities with those of UE, which thereby produces benefits and efficiencies for both generating parties. Pending or future federal and state regulatory proceedings and policies may evolve in ways that could impact Genco’s ability to continue to participate in these affiliate transactions on current terms. For example, as a result of the MoPSC conditional order approving the transfer of UE’s Illinois-based utility business, rehearing or clarification of which is currently being sought by UE, there is uncertainty as to the terms of the joint dispatch agreement and also as to its duration. The termination of the agreement, or modifications to it, could have a material adverse effect on UE or Genco.

Genco’s and CILCO’s electric generating facilities must compete for the sale of energy and capacity, which exposes them to price risk.

As owners of non rate-regulated electric generating facilities, Genco (4,800 megawatts) and CILCO through AERG (1,100 megawatts), its subsidiary, will not have any recovery of their costs or any specified rate of return set by a regulatory body. Of these non rate-regulated electric generating facilities, approximately 3,300 megawatts are currently under full requirements contracts with our affiliates, including the contracts referred to in the immediately preceding risk factor. The remainder of the generating capacity must compete for the sale of energy and capacity. UE is currently seeking regulatory approval of the transfer by Genco to it of approximately 550 megawatts of CTs at Pinckneyville and Kinmundy, Illinois, with the result that those CTs will no longer be non rate-regulated.


 

 

To the extent electric capacity generated by these facilities is not under contract to be sold, either now or in the future, the revenues and results of operations of these non rate-regulated subsidiaries will generally depend on the prices that they can obtain for energy and capacity in Illinois and adjacent markets. Among the factors that could influence such prices (all of which are beyond our control to a significant degree) are:

  • the current and future market prices for natural gas, fuel oil and coal,
  • current and forward prices for the sale of electricity,
  • the extent of additional supplies of electric energy from current competitors or new market entrants,
  • the pace of deregulation in our market area and the slowing expansion of deregulated markets,
  • the regulatory and pricing structures developed for Midwest energy markets as they continue to evolve and the pace of development of regional markets for energy and capacity outside of bilateral contracts,
  • future pricing for, and availability of, transmission services on transmission systems, the effect of RTOs, development and export energy transmission constraints, which could limit the ability to sell energy in markets adjacent to Illinois,
  • the rate of growth in electricity usage as a result of population changes, regional economic conditions and the implementation of conservation programs, and
  • climate conditions prevailing in the Midwest market from time to tim
UE’s ownership and operation of a nuclear generating facility creates business, financial and waste disposal risks.

UE owns the Callaway nuclear plant, which represents approximately 14% of UE’s generation capability. Therefore, UE is subject to the risks of nuclear generation, which include the following:
  • the potential harmful effects on the environment and human health resulting from the operation of nuclear facilities and the storage, handling and disposal of radioactive materials,
  • limitations on the amounts and types of insurance commercially available to cover losses that might arise in connection with UE’s nuclear operations or those of others in the United States,
  • uncertainties with respect to contingencies and assessment amounts if insurance coverage is inadequate,
  • increased public and governmental concerns over the adequacy of security at nuclear power plants,
  • uncertainties with respect to the technological and financial aspects of decommissioning nuclear plants at the end of their licensed lives (UE’s facility operating license for the Callaway nuclear plant expires in 2024), and
  • costly and extended outages from scheduled or unscheduled maintenance.
The NRC has broad authority under federal law to impose licensing and safety related requirements for the operation of nuclear generation facilities. In the event of non-compliance, the NRC has the authority to impose fines or shut down a unit, or both, depending upon its assessment of the severity of the situation, until compliance is achieved. Revised safety requirements promulgated by the NRC could necessitate substantial capital expenditures at nuclear plants such as UE’s. In addition, although UE has no reason to anticipate a serious nuclear incident at its plant, if an incident did occur, it could harm UE’s results of operations or financial position. A major incident at a nuclear facility anywhere in the world could cause the NRC to limit or prohibit the operation or licensing of any domestic nucl ear unit.

Operating performance at UE’s Callaway nuclear plant has recently resulted in unscheduled plant outages and the extension of Callaway’s scheduled refueling and maintenance outage in 2004. In addition, Ameren and UE have incurred significant unanticipated replacement power and maintenance costs. As a result, the operating performance at UE’s Callaway nuclear plant has declined as compared to its past operating performance and the operating performance of other nuclear plants in the United States. Ameren and UE are actively working to address factors leading to the decline in Callaway’s operating performance, including management and supervision of operating personnel, equipment reliability, maintenance worker practices, engineering performance and overall organizational effectiveness. However, A meren and UE cannot predict whether such efforts will result in an overall improvement of operations at Callaway. Efforts taken are expected to result in incremental operating costs at Callaway. Further, additional unscheduled or extended outages at Callaway could have a material effect on the financial position, results of operations and cash flows of Ameren and UE.


 

 

Our energy risk management strategies may not be effective in managing fuel and electricity pricing risks, which could result in unanticipated liabilities to us or increased volatility of our earnings.

We are exposed to changes in market prices for natural gas, fuel, electricity and emission credits. Prices for natural gas, fuel, electricity and emission credits may fluctuate substantially over relatively short periods of time and expose us to commodity price risk. We utilize derivatives such as forward contracts, futures contracts, options and swaps to manage these risks. We attempt to manage our exposure from these activities through enforcement of established risk limits and risk management procedures. We cannot assure you that these strategies will be successful in managing our pricing risk, or that they will not result in net liabilities to us as a result of future volatility in these markets.

In addition, although we routinely enter into contracts to offset our positions (i.e., to hedge our exposure to the risks of demand, market effects of weather and changes in commodity prices), we do not always hedge the entire exposure of our operations from commodity price volatility. Furthermore, our ability to hedge our exposure to commodity price volatility depends on liquid commodity markets. As a result, to the extent the commodity markets are illiquid, we may not be able to execute our risk management strategies, which could result in greater open positions than we would prefer at a given time. To the extent that open positions exist, fluctuating commodity prices can improve or diminish our financial results and financial position.

We are exposed to risk that counterparties which owe us money, energy or other commodities or services will not be able to perform their obligations. The possibility that certain counterparties may fail to perform their obligations has increased due to financial difficulties, in some cases brought on by improper or illegal accounting and business practices, affecting some participants in the industry. Should the counterparties to these arrangements (which include an agreement pursuant to which a subsidiary of Dynegy is obligated to supply electricity to IP during 2005 and 2006) fail to perform, we might be forced to honor the underlying commitment at then-current market prices. In such event we might incur losses in addition to amounts, if any, already paid to the counterparties.

Our businesses are dependent on our ability to successfully access the capital markets. We may not have access to sufficient capital in the amounts and at the times needed.

We rely on access to short-term and long-term capital markets as a significant source of liquidity and funding for capital requirements not satisfied by our operating cash flows. The inability to raise capital on favorable terms, particularly during times of uncertainty in the capital markets, could negatively impact our ability to maintain and grow our businesses. Based on our current credit ratings, we believe that we will continue to have access to the capital markets. However, events beyond our control may create uncertainty in the capital markets such that our cost of capital would increase or our ability to access the capital markets would be adversely affected.

REGULATORY MATTERS

See Note 3 - Rate and Regulatory Matters, Note 8 - Related Party Transactions and Note 9 - Commitments and Contingencies to our financial statements under Part I, Item 1 of this report.


ITEM 3.         QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.

Market risk represents the risk of changes in value of a physical contract or a financial instrument, derivative or non-derivative, caused by fluctuations in market variables such as interest rates. The following discussion of our risk management activities includes “forward-looking” statements that involve risks and uncertainties. Actual results could differ materially from those projected in the “forward-looking” statements. We handle market risks in accordance with established policies, which may include entering into various derivative transactions. In the normal course of business, we also face risks that are either non-financial or non-quantifiable. Such risks principally include business, legal and operational risks and are not represented in the following discussion.

Our risk management objective is to optimize our physical generating assets within prudent risk parameters. Our risk management policies are set by a Risk Management Steering Committee, which is comprised of senior-level Ameren officers.


 

 

Interest Rate Risk

We are exposed to market risk through changes in interest rates associated with:

·   long-term and short-term variable-rate debt;
·   fixed-rate debt;
·   commercial paper; and
·   auction-rate long-term debt.

We manage our interest rate exposure by controlling the amount of these instruments we hold within our total capitalization portfolio and by monitoring the effects of market changes in interest rates.

The following table presents the estimated increase or decrease in our annual interest expense and net income if interest rates were to change by 1% on variable rate debt outstanding at September 30, 2004:
 

   
Interest Expense
 
Net Income(a)
 
Ameren(b)
 
$
6
 
$
(4
)
UE
   
6
   
(4
)
CIPS
   
1
   
-
 
Genco
   
1
   
(1
)
CILCORP(c)
   
3
   
(2
)
CILCO
   
2
   
(1
)
(a)   Calculations are based on an effective tax rate of 36%.
(b)   Includes amounts for Ameren registrant and non-registrant subsidiaries and intercompany eliminations.
(c)   CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.
 
The model does not consider the effects of the reduced level of potential overall economic activity that would exist in such an environment. In the event of a significant change in interest rates, management would likely take actions to further mitigate our exposure to this market risk. However, due to the uncertainty of the specific actions that would be taken and their possible effects, the sensitivity analysis assumes no change in our financial structure.

Credit Risk

Credit risk represents the loss that would be recognized if counterparties fail to perform as contracted. NYMEX-traded futures contracts are supported by the financial and credit quality of the clearing members of the NYMEX and have nominal credit risk. On all other transactions, we are exposed to credit risk in the event of nonperformance by the counterparties to the transaction.

Our physical and financial instruments are subject to credit risk consisting of trade accounts receivables, executory contracts with market risk exposures and leveraged lease investments. The risk associated with trade receivables is mitigated by the large number of customers in a broad range of industry groups comprising our customer base. No non-affiliated customer represents greater than 10%, in the aggregate, of our accounts receivable. Ameren’s revenues are primarily derived from sales of electricity and natural gas to customers in Missouri and Illinois. UE and Genco have credit exposure associated with accounts receivables from nonaffiliated companies for interchange sales. At September 30, 2004, UE’s, Genco’s and Marketing Company’s combined credit exposure to non-investment grade counte rparties related to interchange sales was $4 million, net of collateral. We establish credit limits for these counterparties and monitor the appropriateness of these limits on an ongoing basis through a credit risk management program, which involves daily exposure reporting to senior management, master trading and netting agreements, and credit support such as letters of credit and parental guarantees. We also analyze each counterparty’s financial condition prior to entering into sales, forwards, swaps, futures or option contracts and monitor counterparty exposure associated with our leveraged leases.

Equity Price Risk

Our costs of providing non-contributory defined benefit retirement and postretirement benefit plans are dependent upon a number of factors, such as the rate of return on plan assets, discount rate, the rate of increase in healthcare costs and contributions made to the plans. The market value of our plan assets was affected by declines in the equity market for 2000 through 2002 for the pension and postretirement plans. As a result, a minimum pension liability was recorded
 
 

 

at December 31, 2002, which resulted in a charge to OCI and a reduction in stockholders’ equity. At December 31, 2003, the minimum pension liability was reduced resulting in OCI of $46 million and an increase in stockholders’ equity. The minimum pension liability has not changed as of September 30, 2004.

The amount of the pension liability as of September 30, 2004, was the result of asset returns, interest rates and our contributions to the plans during 2003. In future years, the liability recorded, the costs reflected in net income or OCI, or cash contributions to the plans could increase materially without a recovery in equity markets in excess of our assumed return on plan assets of 8.5%. If the fair value of the plan assets were to grow and exceed the accumulated benefit obligations in the future, the recorded liability would then be reduced and a corresponding amount of equity would be restored, net of taxes.

Commodity Price Risk

The Ameren Companies and IP are exposed to changes in market prices for natural gas, fuel and electricity to the extent they cannot be recovered through rates. For a more detailed discussion of our commodity price risk, see Commodity Price Risk under Part II, Item 7A of the Ameren Companies’ combined Form 10-K for the fiscal year ended December 31, 2003.  In addition, see Risk Factors under Part 1, Item 2 of this report for further information on commodity price risks.  Below are details relating to IP’s power purchase agreements and tables presenting the percentage of fuel that is price-hedged and the effects a material change in price will have on our coal costs not currently covered under fixed-price contracts as of September 30, 2004.

IP has contracts with AmerGen and DMG to supply power via purchase power agreements that expire at the end of 2004. Should power acquired under these agreements be insufficient to meet IP’s load requirements, it will have to buy power at current market prices. The purchased power agreement with DMG obligates DMG to provide power up to the reservation amount, and at the same prices, even if DMG has individual units unavailable at various times. The purchased power agreement with AmerGen does not obligate AmerGen to acquire replacement power for us in the event of a curtailment or shutdown at the Clinton Power Station. Under a Clinton shutdown scenario, to the extent IP exceeds its capacity reservation with DMG, it will have to buy power at current market prices. Such purchases would expose IP  to commodity price risk. As discussed in Ameren Companies combined Form 10-K, the retail electric rates are frozen in Illinois until January 1, 2007.

As part of the sale transaction with Ameren, DMG and IP entered into a fixed price power capacity supply agreement for our annual purchase in 2005 and 2006 of 2,800 megawatts of electricity. This agreement is expected to supply 70% of our electric customer requirements during those two years. Additionally, IP is in the final stages of soliciting bids to supply the remaining 30% of its power needs for 2005 and 2006. This solicitation is expected to be completed by the end of 2004. If IP is unable to sufficiently contract for all of its power and energy needs, or if any of the parties to these agreements are unable to satisfy their oblig ations thereunder for any reason, either to purchase or deliver power, IP or Ameren could be required to satisfy IP’s needs through open market purchases thus exposing IP or Ameren to commodity price risk. Any additional costs could not be passed on to ratepayers until at least the end of the rate freeze in Illinois.

The following table presents the percentages of the required supply of coal for our coal-fired power plants, nuclear fuel and natural gas for our CTs and distribution, as appropriate, which are price-hedged for the remainder of 2004 through 2008:


 
2004
2005
2006 - 2008
Ameren:
     
Coal
 100%
                            92%
60%
Nuclear fuel
                   100
100
                    32
Natural gas for generation
                     65
                            25
                      5
Natural gas for distribution
                     33
                            19
                      5
UE:
     
Coal 
100%
     92%
                    57%
Nuclear fuel
                   100
100
                    32
Natural gas for generation
                     63
                              8
                     4
Natural gas for distribution
                     26
                            15
                     5
 
 

 

 

2004
2005
2006 - 2008
CIPS:
     
Natural gas for distribution
                     25%
                            21%
                   10%
Genco:
     
Coal 
100%
                           96%
                   70%
Natural gas for generation
                   100
                           18
                   24
CILCORP:(a)
     
Coal 
100%
                          85%
                   58%
Natural gas for distribution
                     45
                          28
                     9
CILCO:
     
Coal 
100%
                         85%
                  58%
Natural gas for distribution
                     45
                         28
                    9
(a)   CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.

The following table presents the estimated increase or decrease in our total fuel expense and net income if coal costs were to change by 1% on any requirements currently not covered by fixed-price contracts for the remainder of 2004 through 2008:
 

   
Fuel Expense
 
Net Income(a)
 
Ameren(b)
 
$
5
 
$
3
 
UE
   
3
   
2
 
CIPS
   
-
   
-
 
Genco
   
1
   
1
 
CILCORP(c)
   
1
   
-
 
CILCO
   
1
   
-
 
(a)   Calculations are based on an effective tax rate of 36%.
(b)   Includes amounts for Ameren registrant and non-registrant subsidiaries.
(c)   CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.

Fair Value of Contracts

Most of our commodity contracts qualify for treatment as normal purchases and normal sales. However, we utilize derivatives principally to manage the risk of changes in market prices for natural gas, fuel, electricity and emission credits. Price fluctuations in natural gas, fuel and electricity cause:

·
an unrealized appreciation or depreciation of our firm commitments to purchase or sell when purchase or sales prices under the firm commitment are compared with current commodity prices;
·
market values of fuel and natural gas inventories or purchased power to differ from the cost of those commodities in inventory under firm commitment; and
·
actual cash outlays for the purchase of these commodities to differ from anticipated cash outlays.

The derivatives that we use to hedge these risks are dictated by risk management policies and include forward contracts, futures contracts, options and swaps. We continually assess our supply and delivery commitment positions against forward market prices and internally-forecasted forward prices and modify our exposure to market, credit and operational risk by entering into various offsetting transactions. In general, we believe these transactions serve to reduce our price risk. See Note 7 - Derivative Financial Instruments to our financial statements under Part I, Item 1 of this report for further information.



 

 
The following table presents the favorable (unfavorable) changes in the fair value of all contracts marked-to-market during the three months and nine months ended September 30, 2004:
 

   
Ameren(a)
 
UE
 
CIPS
 
CILCORP(b)
 
CILCO
 
Three Months
                     
Fair value of contracts at beginning of period, net
 
$
24
 
$
(2
)
$
6
 
$
12
 
$
12
 
Contracts realized or otherwise settled during the period
   
-
   
-
   
-
   
-
   
-
 
Changes in fair values attributable to changes in valuation
 technique and assumptions     
   
-
   
-
   
-
   
-
   
-
 
Fair value of new contracts entered into during the period
   
-
   
-
   
-
   
-
   
-
 
Other changes in fair value
   
25
   
5
   
5
   
13
   
13
 
Fair value of contracts outstanding at end
of period, net
 
$
49
 
$
3
 
$
11
 
$
25
 
$
25
 
Nine Months
                               
Fair value of contracts at beginning of period, net
 
$
12
 
$
(1
)
$
1
 
$
6
 
$
6
 
Contracts realized or otherwise settled during the period
   
(5
)
 
1
   
(1
)
 
(3
)
 
(2
)
Changes in fair values attributable to changes in valuation
 technique and assumptions 
   
-
   
-
   
-
   
-
   
-
 
Fair value of new contracts entered into during the period
   
-
   
-
   
-
   
-
   
-
 
Other changes in fair value
   
42
   
3
   
11
   
22
   
21
 
Fair value of contracts outstanding at end
of period, net
 
$
49
 
$
3
 
$
11
 
$
25
 
$
25
 
(a)   Includes amounts for Ameren registrant and non-registrant subsidiaries and intercompany eliminations.
(b)   CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.
 
              The following table presents maturities of contracts as of September 30, 2004:
 

Sources
of
Fair Value
 
Maturity Less than
1 Year
 
Maturity
1-3
Years
 
Maturity
4-5
Years
 
Maturity in Excess of
5 Years
 
Total
Fair
Value(a)
 
Ameren:
     
 
             
Prices actively quoted
 
$
29
 
$
16
 
$
-
 
$
-
 
$
45
 
Prices provided by other external
sources(b)
   
(1
)
 
-
   
-
   
-
   
(1
)
Prices based on models and other
 valuation methods(c)
   
10
   
(3
)
 
(2
)
 
-
   
5
 
Total
 
$
38
 
$
13
 
$
(2
)
$
-
 
$
49
 
UE:
                               
Prices actively quoted
 
$
3
 
$
3
 
$
-
 
$
-
 
$
6
 
Prices provided by other external
 sources(b)
   
(1
)
 
-
   
-
   
-
   
(1
)
Prices based on models and other
valuation methods(c)
   
4
   
(3
)
 
(3
)
 
-
   
(2
)
Total
 
$
6
 
$
-
 
$
(3
)
$
-
 
$
3
 
CIPS:
                               
Prices actively quoted
 
$
7
 
$
4
 
$
-
 
$
-
 
$
11
 
Prices provided by other
external sources(b)
   
-
   
-
   
-
   
-
   
-
 
Prices based on models and other 
valuation methods(c)
   
-
   
-
   
-
   
-
   
-
 
Total
 
$
7
 
$
4
 
$
-
 
$
-
 
$
11
 
 
 


Sources
of
Fair Value
 
Maturity Less than
1 Year
 
Maturity
1-3
Years
 
Maturity
4-5
Years
 
Maturity in Excess of
5 Years
 
Total
Fair
Value(a)
 
CILCORP:(d)
                               
Prices actively quoted
 
$
15
 
$
9
 
$
1
 
$
-
 
$
25
 
Prices provided by other
external sources(b)
   
-
   
-
   
-
   
-
   
-
 
Prices based on models and other
valuation methods(c)
   
-
   
-
   
-
   
-
   
-
 
Total
 
$
15
 
$
9
 
$
1
 
$
-
 
$
25
 
CILCO:
                               
Prices actively quoted
 
$
15
 
$
9
 
$
1
 
$
-
 
$
25
 
Prices provided by other
external sources(b)
   
-
   
-
   
-
   
-
   
-
 
Prices based on models and other
valuation methods(c)
   
-
   
-
   
-
   
-
   
-
 
Total
 
$
15
 
$
9
 
$
1
 
$
-
 
$
25
 
(a)   Contracts of less than $11 million were with non-investment-grade rated counterparties.
(b)   Principally power forwards based on a published survey of settled forward pricing and natural gas swap valuations based on NYMEX prices for over-the-counter contracts.
(c)   Principally coal and SO2 option values based on a Black-Scholes model that includes information from external sources and our estimates. Also includes power forward contract values based on our estimates.
(d)   CILCORP consolidates CILCO and therefore includes CILCO amounts in its balances.


ITEM 4.     CONTROLS AND PROCEDURES.

(a) Evaluation of Disclosure Controls and Procedures

As of September 30, 2004, the principal executive officer and principal financial officer of each Registrant have evaluated the effectiveness of the design and operation of such Registrant’s disclosure controls and procedures (as defined in Rules 13a - 15(e) and 15d - 15(e) of the Exchange Act). Based upon that evaluation, the principal executive officer and principal financial officer of each such Registrant have concluded that such disclosure controls and procedures are effective in timely alerting them to any material information relating to such Registrant, which is required to be included in such Registrant’s reports filed or submitted with the SEC under the Exchange Act.

(b) Change in Internal Controls

There has been no change in the Registrants’ internal control over financial reporting that occurred during their most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, their internal control over financial reporting.

 
 

 
PART II. OTHER INFORMATION
 
ITEM 1.   LEGAL PROCEEDINGS.

Note 3 - Rate and Regulatory Matters, Note 8 - Related Party Transactions and Note 9 - Commitments and Contingencies to our financial statements under Part I, Item 1 of this report contain information on legal and administrative proceedings which are incorporated by reference under this item.


ITEM 2.   UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS.
 
Ameren’s purchases of equity securities reportable under Item 703 of Regulation S-K:
 

 
Period
(a) Total Number of Shares
(or Units) Purchased(a)
(b) Average Price
Paid per Share
(or Unit)
(c) Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs
(d) Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs
July 1 -
July 31, 2004
                             -
$              -
-
-
August 1 -
August 31, 2004
55,462
         45.81
-
-
September 1 -
September 30, 2004
                      4,342
        46.34
-
-
Total
59,804
$      45.85
-
-
(a)  These shares of Ameren common stock were purchased by Ameren in open-market transactioins in satisfaction of Ameren’s obligations upon the exercise by employees of options issued under
                   Ameren’s  Long-term Incentive Plan of 1998. Ameren does not have any publicly announced equity securities repurchase plans or programs.
 
CILCO’s purchases of equity securities reportable under Item 703 of Regulation S-K:
 

 
Period
(a) Total Number of Shares
(or Units) Purchased(a)
(b) Average Price
Paid per Share
(or Unit)
(c) Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs
(d) Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs
July 1 -
July 31, 2004
11,000
$     100.00
-
-
August 1 -
August 31, 2004
         -
                -
-
-
September 1 -
September 30, 2004
                             -
                -
-
-
Total
11,000
$     100.00
-
-
(a)   CILCO redeemed these shares of its 5.85% Class A preferred stock to satisfy the mandatory sinking fund redemption requirement for this series of preferred stock for 2004. CILCO does not have any publicly announced equity securities repurchase plans or programs.

None of the other Registrants purchased equity securities reportable under Item 703 of Regulation S-K during the July 1 to September 30, 2004, period.


 

 

ITEM 6.   EXHIBITS.
 
(a)   Exhibits. The documents listed below are being filed on behalf of Ameren, UE, CIPS, Genco, CILCORP and CILCO (collectively the “Ameren Companies”).
 

Exhibit Designation
Registrant(s)
Nature of Exhibit
Plan of Acquisition, Reorganization, Arrangement, Liquidation or Succession
2.1
Ameren
Amendment No. 4, dated as of September 24, 2004, to Stock Purchase Agreement, dated as of February 2, 2004, by and between Dynegy and certain of its subsidiaries and Ameren
Bylaws
3.1
Genco
Bylaws of Genco as amended October 8, 2004
3.2
CILCORP
Bylaws of CILCORP as amended October 8, 2004
Material Contracts
10.1
Ameren
Escrow Agreement among Illinova Corporation, Ameren and JPMorgan Chase Bank, as escrow agent, dated September 30, 2004
10.2
Ameren
CIPS
Genco
Power Supply Agreement between CIPS and Marketing Company, as amended November 5, 2004
Rule 13a-14(a) / 15d-14(a) Certifications
31.1
Ameren
Rule13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Ameren
31.2
Ameren
Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Ameren
31.3
UE
Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of UE
31.4
UE
Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of UE
31.5
CIPS
Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of CIPS
31.6
CIPS
Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of CIPS
31.7
Genco
Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of Genco
31.8
Genco
Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of Genco
31.9
CILCORP
Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of CILCORP
31.10
CILCORP
Rule13a-14(a)/15d-14(a) Certification of Principal Financial Officer of CILCORP
31.11
CILCO
Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer of CILCO
31.12
CILCO
Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer of CILCO
Section 1350 Certifications
32.1
Ameren
Section 1350 Certification of Principal Executive Officer of Ameren
32.2
Ameren
Section 1350 Certification of Principal Financial Officer of Ameren
32.3
UE
Section 1350 Certification of Principal Executive Officer of UE
32.4
UE
Section 1350 Certification of Principal Financial Officer of UE
32.5
CIPS
Section 1350 Certification of Principal Executive Officer of CIPS
32.6
CIPS
Section1350 Certification of Principal Financial Officer of CIPS
32.7
Genco
Section 1350 Certification of Principal Executive Officer of Genco
32.8
Genco
Section 1350 Certification of Principal Financial Officer of Genco
32.9
CILCORP
Section 1350 Certification of Principal Executive Officer of CILCORP
32.10
CILCORP
Section 1350 Certification of Principal Financial Officer of CILCORP
32.11
CILCO
Section 1350 Certification of Principal Executive Officer of CILCO
32.12
CILCO
Section 1350 Certification of Principal Financial Officer of CILCO
 


 
 

 

SIGNATURES

Pursuant to the requirements of the Exchange Act, each Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature for each undersigned company shall be deemed to relate only to matters having reference to such company or its subsidiaries.



 
AMEREN CORPORATION
 
(Registrant)
   
 
/s/ Martin J. Lyons                                                             
 
Martin J. Lyons
 
Vice President and Controller
 
(Principal Accounting Officer)
   
   
   
   
 
UNION ELECTRIC COMPANY
 
(Registrant)
   
 
/s/ Martin J. Lyons                                                            
 
Martin J. Lyons
 
Vice President and Controller
 
(Principal Accounting Officer)
   
   
   
   
 
CENTRAL ILLINOIS PUBLIC SERVICE COMPANY
 
(Registrant)
   
 
/s/ Martin J. Lyons                                                             
 
Martin J. Lyons
 
Vice President and Controller
 
(Principal Accounting Officer)
   
   
   
   
 
AMEREN ENERGY GENERATING COMPANY
 
(Registrant)
   
 
/s/ Martin J. Lyons                                                             
 
Martin J. Lyons
 
Vice President and Controller
 
(Principal Accounting Officer)
   

 
 

 


 
CILCORP INC.
 
(Registrant)
   
 
/s/ Martin J. Lyons                                                            
 
Martin J. Lyons
 
Vice President and Controller
 
(Principal Accounting Officer)
   
   
   
   
 
CENTRAL ILLINOIS LIGHT COMPANY
 
(Registrant)
   
 
/s/ Martin J. Lyons                                                             
 
Martin J. Lyons
 
Vice President and Controller
 
(Principal Accounting Officer)
   
   
Date: November 9, 2004
 
 

 


EX-2.1 2 ex2_1.htm EXHIBIT 2.1 AMEND TO SPA Exhibit 2.1 Amendment to SPA

                                                                     Exhibit 2.1
AMENDMENT NO. 4 TO
 
STOCK PURCHASE AGREEMENT
 
THIS AMENDMENT NO. 4, dated as of September 24, 2004, to the STOCK PURCHASE AGREEMENT, dated as of February 2, 2004, is entered into by and among Ameren Corporation, a Missouri corporation (“Purchaser”), Illinova Corporation, an Illinois corporation (“Seller”), Illinova Generating Company, an Illinois corporation (“IGC”), and Dynegy Inc., an Illinois corporation (“Dynegy”). Dynegy, IGC and Seller are referred to herein as the “Dynegy Parties”.
 
W I T N E S S E T H:
 
WHEREAS, Purchaser and the Dynegy Parties entered into a Stock Purchase Agreement, dated February 2, 2004, as amended by Amendment No. 1 dated as of March 23, 2004, Amendment No. 2 dated as of April 30, 2004 and Amendment No. 3 dated as of May 31, 2004 (the “Amended Agreement”), providing for the sale to Purchaser of all of the capital stock of Illinois Power Company, an Illinois corporation, held by Seller, and IGC’s 20% share of Electric Energy, Inc., an Illinois corporation; and
 
WHEREAS, Purchaser and the Dynegy Parties wish to amend the Amended Agreement as set forth herein;
 
NOW, THEREFORE, in consideration of the premises and the mutual terms, conditions and agreements set forth herein, the parties hereto hereby agree as follows:
 
Section 1 Defined Terms. All capitalized terms used and not defined herein have the meanings set forth in the Amended Agreement.
 
Section 2 Amendment to Section 5.3(d). Section 5.3(d) of the Amended Agreement is amended by relabeling it as Section 5.3(d)(i) and adding the following paragraph as Section 5.3(d)(ii): “Purchaser acknowledges that IPC filed, on or about August 2, 2004, in Docket No. ER04-1091-000, an application with FERC for the recovery of the MISO exit fee and Alliance development costs previously incurred by IPC (in each case with interest) (such amounts, collectively, the “MISO Amounts”), and that FERC on September 20, 2004 issued an order granting IPC’s request for a return of all such MISO Amounts. From and after the Closing, at Dynegy’s direction and expense, Purchaser shall cause IPC diligently to pursue the maximum recovery of the MISO Amounts from MISO for the benefit of Dynegy. Purchaser further acknowledges that IPC may at any time direct MISO to pay after the Closing any such MISO Amounts directly to Dynegy, rather than to IPC. In the event that (i) any MISO Amounts are recovered and received by IPC after the Closing, Purchaser will pay, or will cause IPC to pay, all such amounts to Dynegy, by wire transfer to Bank One Chicago, ABA Number 071000013, Account Name: Dynegy Inc. New, Account Number 654204452, no later than the third business day after any such receipt by IPC, and (ii) any MISO Amounts are set-off or reduced by MISO (x) to the extent applicable to the business conducted by or
 
 

 
     

 

the operations of IPC or its Subsidiaries after the Closing, including, without limitation, the participation of IPC or its Subsidiaries in MISO (such as credits or prepaid amounts applicable to periods after the Closing), or (y) to the extent applicable to the business conducted by or the operations of Purchaser or its Subsidiaries (other than IPC), whether before or after the Closing, Purchaser will pay, or will cause IPC to pay, to Dynegy, by wire transfer to Bank One Chicago, ABA Number 071000013, Account Name: Dynegy Inc. New, Account Number 654204452, the amount of such set-off or reduction no later than the third business day after MISO advises IPC or Purchaser of such set-off or reduction.”
 
Section 3 Amendments to Exhibit A.
 
(a) Exhibit A to the Amended Agreement is amended by adding new items 12 and 13 to Section A thereof, immediately following item 11 of such Section A, to read in their entirety as follows:
 
“12. MISO Exit Fee and Alliance Development Costs: In the event that any MISO Amounts have not been repaid, returned or reimbursed to IPC prior to the Closing, such unpaid, unreturned and unreimbursed MISO Amounts will not be included in the calculation of Proposed Final Adjusted Working Capital or Final Adjusted Working Capital as an increase to current assets. For the avoidance of doubt, neither the Adjusted Working Capital nor the Target Adjusted Working Capital shall be increased or decreased by any such MISO Amounts.
 
13. Effect of Asbestos Trust. The establishment and funding of the trust referred to in Section 5.21(i) shall have no effect on the calculation of Adjusted Working Capital.”
 
(b) The second paragraph of Section C of Exhibit A to the Amended Agreement is hereby amended by deleting the reference to “$25,000,000” and replacing it with “$26,000,000.”
 
Section 4 Amendment to Section 5.21. Section 5.21 of the Amended Agreement is amended by adding thereto the following as a new Section 5.21(i):
 
“(i) At the Closing, each of Purchaser and Dynegy will contribute $10 million in cash to the trust to be established by Purchaser as contemplated on page 1 of Exhibit B to the Final Order of the ICC in ICC Docket No. 04-0294.”
 
Section 5 No Other Amendments. Except as set forth herein, the Amended Agreement remains in full force and effect.
 
Section 6 Counterparts. This Agreement may be executed in one or more counterparts, and by the parties in separate counterparts, each of which when executed shall be deemed to be an original but all of which taken together shall constitute one and the same agreement.
 
 

 
     

 

 


IN WITNESS WHEREOF, Seller, IGC, Dynegy and Purchaser have caused this Amendment No. 4 to the Original Agreement to be executed as of the date first written above by their respective officers thereunto duly authorized.
 

      ILLINOVA CORPORATION
 
      By /s/ R. Blake Young_____________________                
           Name: R. Blake Young
           Title:    Executive Vice President-Administration
                        and Technology
 
 
      ILLINOVA GENERATING COMPANY
 
 
      By /s/ R. Blake Young_____________________                
           Name: R. Blake Young
           Title:    Executive Vice President-Administration
            and Technology
 
      DYNEGY INC.
 
      By /s/ R. Blake Young_____________________                
           Name: R. Blake Young
           Title:    Executive Vice President-Administration
             and Technology
 
      AMEREN CORPORATION
 
      By /s/ Steven R. Sullivan___________________                
           Name:  Steven R. Sullivan
           Title:     Senior Vice President
           Regulatory Policy, General Counsel
             and Secretary
 



 


 


 
EX-3.1 3 ex3_1.htm EXHIBIT 3.1 GENCO BYLAWS Exhibit 3.1 Genco Bylaws
                                                                    Exhibit 3.1

AMEREN ENERGY GENERATING COMPANY

BYLAWS

As Amended to October 8, 2004

ARTICLE I
SHARES AND TRANSFERS

 Section 1. Each holder of duly paid shares of the Company shall be entitled to a certificate or certificates stating the number and class of shares owned by such holder. Such certificates shall be signed by the appropriate officers of the Company (which, in the absence of contrary action by the Board, shall be the President or any Vice President and the Secretary or any Assistant Secretary of the Company); shall be sealed with the corporate seal of the Company, which seal may be facsimile; and shall be countersigned by a Transfer Agent, and countersigned and registered by a Registrar, appointed by the Board. If a certificate is countersigned by a Transfer Agent and countersigned and registered by a Registrar, other (in each case) than the Company itself or its employee, the signature of either or both of such officers of the Company, and the countersignature of any such Transfer Agent or its officer or employee, may be facsimiles. In case any officer of the Company, or any officer or employee of a Transfer Agent, who has signed or whose facsimile signature has been placed upon any such certificate shall cease to be an officer of the Company or an officer or an employee of the Transfer Agent, as the case may be, before such certificate is issued, the certificate may be issued by the Company with the same effect as if such officer of the Company or such officer or employee of the Transfer Agent had not ceased to be such at the date of issue of such certificate.

 Section 2. Shares shall be transferable only on the books of the Company and upon proper endorsement and surrender of the outstanding certificate or certificates representing such shares. If an outstanding certificate shall be lost, destroyed or stolen, the holder thereof may have a new certificate upon producing evidence satisfactory to the Company of such loss, destruction or theft and upon furnishing to the Company, the Transfer Agent and the Registrar indemnity deemed sufficient by the Company.

 Section 3. Notwithstanding the foregoing provisions of this Article I, the Board of Directors may also provide by resolution that some or all of any or all classes and series of its shares shall be uncertificated shares, provided that such resolution shall not apply to shares represented by a certificate until such certificate is surrendered to the Company. Except as otherwise provided by statute, the rights and obligations of the holders of uncertificated shares and the rights and obligations of the holders of certificates representing shares of the same class and series shall be identical.

 
ARTICLE II
MEETINGS OF SHAREHOLDERS

 Section 1. The annual meeting of the shareholders shall be held on the fourth Tuesday in May of each year (or if such day shall be a legal holiday, then upon the next succeeding day not a legal holiday) or upon such other day determined by resolution of the Board of Directors. Each such regular annual meeting shall be held at such time and at such location, within or without the State of Illinois, as the Board of Directors shall order. At such annual meeting, a board of directors shall be elected and such other business shall be transacted as may properly come before such meeting.

 Section 2. Special meetings of the shareholders may be called by the President, by the Board of Directors, by the holders of not less than one-fifth of all the outstanding shares entitled to vote on the matter for which the meeting is called, or in such other manner as may be provided by statute. Each such special meeting shall be held at such location, within or without the State of Illinois, as the Board of Directors shall order.

 Section 3. Written notice of the place, day and hour of each meeting of shareholders and, in the case of a special meeting, the purpose or purposes for which the meeting is called, shall be given to each shareholder of record entitled to vote at such meeting. Such notice shall be sent by mail to each such shareholder, at the address of such shareholder as it appears on the records of the Company, not less than ten days or more than sixty days before the date of the meeting, except in cases where some other special method of notice may be required by statute, in which case the statutory method shall be followed. Notice of any meeting of the shareholders may be waived by any shareholder. Attendance of a shareholder (either in person or by proxy) at any meeting s hall constitute waiver of notice thereof unless the shareholder (in person or by proxy, as the case may be) at the meeting objects to the holding of the meeting because proper notice was not given.

 Section 4. At any shareholders' meeting a majority of the shares outstanding and entitled to vote on the matter (excluding such shares as may be owned by the Company) must be represented (either in person or by proxy) in order to constitute a quorum for consideration of such matter, but the shareholders represented at any meeting, though less than a quorum, may adjourn the meeting to some other day or sine die. If a quorum is present (either in person or by proxy) at a shareholders' meeting, the affirmative vote of the holders of the majority of shares represented at the meeting and entitled to vote on a matter shall be the act of the shareholders, unless the vote of a greater number or voting by classes shall be required by law or the Articles of Incorporatio n.

 Section 5. The President and Secretary of the Company shall act as Chairman and Secretary, respectively, of each shareholders' meeting, unless the shareholders represented at the meeting shall otherwise decide.
 
  
   


ARTICLE III
BOARD OF DIRECTORS

 Section 1. The business and affairs of the Company shall be managed by or under the direction of the Board of Directors consisting of a minimum of three (3) or not more than eight (8) members. The exact number of directors within the minimum and maximum limitations specified in the preceding sentence shall be fixed from time to time by the Board of Directors pursuant to a resolution adopted by a majority of the entire Board of Directors. The Board of Directors shall be elected at each annual meeting of the shareholders, but, if for any reason the election shall not be held at an annual meeting, it may be subsequently held at any special meeting of the shareholders after proper notice. Directors so elected shall hold office until the next succeeding annual meet ing of shareholders or until their respective successors, willing to serve, shall have been elected and qualified. Any vacancy occurring in the Board of Directors arising between meetings of shareholders by reason of an increase in the number of directors or otherwise may be filled by a majority of the members of the Board.

 Section 2. A meeting of the Board of Directors shall be held on the same date as the annual meeting of shareholders in each year, at the same place where such annual meeting shall have been held or at such other place as shall be determined by the Board. Regular meetings of the Board shall be held in such place, within or without the State of Illinois, and on such dates each year as shall be established from time to time by the Board. Notice of every such regular meeting of the Board, stating the place, day and hour of the meeting, shall be given to each director personally, or by telegraph or other written means of electronic communication, or by depositing the same in the mails properly addressed, at least two days before the date of such meeting. Except whe re required by statute, neither the business to be transacted at, nor the purpose of, any regular or special meeting of the Board need be specified in the notice or waiver of notice of such meeting.

 Section 3. Special meetings of the Board of Directors may be called at any time by the President, or by a Vice President, when acting as President, or by any two directors. Notice of such meeting, stating the place, day and hour of the meeting shall be given to each director personally in writing, or by telegraph or other written means of electronic communication, or by depositing the same in the mails properly addressed, or orally promptly confirmed by written notice in any one of the aforesaid forms, not less than the day prior to the date of such meeting.

 Section 4. Notice of any meeting of the Board may be waived by any director. Attendance of a director at any meeting shall constitute waiver of notice of such meeting except where a director attends a meeting for the express purpose of objecting to the transaction of any business at the meeting because the meeting is not lawfully called or convened.

 Section 5. A majority of the Board of Directors shall constitute a quorum for the transaction of business at any meeting of the Board, but less than a majority of the Board may adjourn the meeting to some other day or sine die. The act of the majority of the directors present at a meeting at which a quorum is present shall be the act of the Board unless the vote of

  
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a greater number or the vote of any class of directors shall be required by the Articles of Incorporation. The President of the Company shall act as Chairman at each meeting of the Board but, in the President's absence, one of the directors present at the meeting who shall have been elected for the purpose by majority vote of those directors in attendance shall act as Chairman; and the Secretary of the Company, or in the Secretary's stead, an Assistant Secretary shall act as Secretary at each such meeting. The members of the Board shall receive such compensation as the Board may from time to time by resolution determine.


ARTICLE IV
COMMITTEES OF THE BOARD OF DIRECTORS

 Section 1. A majority of directors may appoint committees, standing or special, from time to time from among members of the Board, and confer powers on such committees and revoke such powers and terminate the existence of such committees at its pleasure.

 Section 2. Meetings of any committee may be called in such manner and may be held at such times and places as such committee may by resolution determine, provided that a meeting of any committee may be called at any time by the President of the Company. Members of all committees shall receive such compensation as the Board of Directors may from time to time by resolution determine.

 Section 3. Each committee shall have such authority of the Board of Directors as shall be granted to it by the Board; provided, however, a committee may not take any action not permitted to be taken by a committee pursuant to the Illinois Business Corporation Act, as amended from time to time.

 
ARTICLE V
OFFICERS

 Section 1. There shall be elected by the Board of Directors (if practicable at its first meeting after the annual election of directors in each year) the following principal officers, namely: A President, such number of Vice Presidents as the Board may from time to time decide upon (any one or more of whom may be designated as Executive Vice President, Senior Vice President or otherwise), a Secretary and a Treasurer. References in these Bylaws to Vice Presidents shall include any such Executive Vice President, Senior Vice President or other Vice President, however denominated. The Board may in its discretion also elect such other officers as may from time to time be provided for by the Board. Any two or more offices may be held by the same person. All officers , unless sooner removed, shall hold their respective offices until the first meeting of the Board of Directors after the next succeeding annual election of directors and until their successors, willing to serve, shall have been elected, but any officer, including any officer appointed by the President as provided in Section 2 of this Article V, may be removed from office at the pleasure of the Board. Election or appointment of an officer shall not of itself create contract rights.

  
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 Section 2. The President shall be the chief executive officer of the Company and shall have the general management and direction, subject to the control of the Board of Directors, of the business of the Company, including the power to appoint and to remove and discharge any and all assistant officers, agents and employees of the Company not elected or appointed directly by the Board of Directors. The President may execute for and on behalf of the Company any contracts, deeds, mortgages, leases, bonds, or other instruments and may accomplish such execution either under or without the seal of the Company and either individually or with the Secretary, any Assistant Secretary, or any other officer or person thereunto authorized by the Board of Directors, according to the requirements of the form of the instrument. The President shall have such other powers and duties as usually devolve upon the president of a corporation, and such further powers and duties as may from time to time be prescribed by the Board of Directors. The President may delegate any part of the duties of that office to one or more of the Vice Presidents of the Company.

 Section 3. Each of the Vice Presidents shall have such powers and duties as may be prescribed for such office by the Board of Directors or as may be prescribed for or delegated to such officer by the President. Each Vice President may execute for and on behalf of the Company any contracts, deeds, mortgages, leases, bonds, or other instruments in each case in accordance with the authority therefor granted by the President or the Board of Directors, which authority may be general or confined to specific instances. Such execution may be accomplished either individually or with any other officer or person thereunto authorized by the President or the Board of Directors, according to the requirements of the form of the instrument. In the absence or inability of the President or in case of the President's death, resignation or removal from office, the powers and duties of the President shall temporarily devolve upon such one of the Vice Presidents as the Board shall have designated or shall designate for the purpose and the Vice President so designated shall have and exercise all the powers and duties of the President during such absence or disability or until the vacancy in the office of President shall be filled. Each Vice President may delegate any part of the duties of that office to employees of the Company under such Vice President's supervision.

 Section 4. 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 have the custody and care of the corporate seal, records, minutes and stock books of the Company. The Secretary shall also act as Secretary of all shareholders' meetings, and keep a record thereof, except to the extent some other person may have been selected to act as Secretary by such meeting. The Secretary shall keep a suitable record of the addresses of shareholders, shall have general charge of the stock transfer books of the Company, and shall, except as may be otherwise required by statute or by the Bylaws, sign, issue and publish all notices required for meetings of shareh olders and for meetings of the Board of Directors. The Secretary shall sign all share certificates, bonds and mortgages, and all other documents and papers to which the Secretary's signature may be necessary or appropriate, shall affix 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 or delegated to that office by the Board of Directors, by the President, or, if authorized by the Board or the President to prescribe such powers and duties, by a Vice President. The Secretary may

  
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delegate any part of the duties of that office to employees of the Company under the Secretary's supervision.

 Section 5. The Treasurer shall have charge of, and be responsible for, the collection, receipt, custody and disbursement of the funds of the Company, and the deposit of its funds in the name of the Company in such banks, trust companies or safety vaults as the Board of Directors may direct which direction may be general or confined to specific depositories. The Treasurer shall have custody of such books, receipted vouchers and other papers and records as in the practical business operations of the Company shall naturally belong in the office or custody of the Treasurer or as shall be placed in the custody of the Treasurer by the Board of Directors, by the President, or, if authorized by the Board or the President, by a Vice President. The Treasurer shall have such other powers and duties as are commonly incidental to the office of Treasurer or as may be prescribed for or delegated to that office by the Board of Directors, by the President, or, if authorized by the Board or the President to prescribe such powers and duties, by a Vice President. The Treasurer may be required to give a bond to the Company for the faithful discharge of the Treasurer's duties, in such form and in such amount and with such sureties as shall be determined by the Board of Directors. The Treasurer may delegate any part of the Treasurer's duties to employees of the Company under the Treasurer's supervision.

 Section 6. The Assistant Vice Presidents, Assistant Secretaries and Assistant Treasurers shall, respectively, assist the Vice Presidents, the Secretary and the Treasurer of the Company in the performance of the respective duties assigned to such principal officers and, in assisting the respective principal officer, each assistant officer shall, for such purposes, have the same powers as the respective principal officer. The powers and duties of any principal officer shall, except as otherwise ordered by the Board of Directors, temporarily devolve upon the respective assistant in case of the absence, disability, death, resignation or removal from office of such principal officer.


ARTICLE VI
MISCELLANEOUS

 Section 1. The funds of the Company shall be deposited to its credit in such banks or trust companies, as the Board of Directors from time to time shall approve, which approval may be general or confined to specific instances. Such funds shall be withdrawn only on checks or drafts of the Company or by direct, wire or other electronic transfer of funds for the purposes of the Company in accordance with procedures relating to signatures and authorizations by officers of the Company which are approved by the Board of Directors from time to time, which approval may be general or confined to specific instances.

 Section 2. No loans shall be contracted on behalf of the Company and no evidences of indebtedness shall be issued in its name except for current expenses unless authorized by the Board of Directors. Such authority may be general or confined to specific instances.

  
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 Section 3. The Board of Directors may authorize any officer or officers, agent or agents to enter into any contract or execute and deliver any instrument in the name of and on behalf of the Company, and such authority may be general or confined to specific instances.
 
 Section 4. All distributions to shareholders and all acquisitions by the Company of its own shares shall be authorized by the Board of Directors.

 Section 5. The fiscal year of the Company shall close at the end of December annually.

 Section 6. All or any shares of stock of any corporation owned by the Company may be voted at any meeting of the shareholders of such corporation by the President, any Vice President or the Secretary of the Company upon any question that may be presented at such meeting, and any such officer may, on behalf of the Company, waive any notice of the calling of such meeting required by any statute or Bylaw and consent to the holding of any such meeting without notice. The President, any Vice President or the Secretary of the Company shall have authority to give to any person a written proxy in the name of the Company and under its corporate seal to vote at any meeting of the shareholders of any corporation all or any shares of stock of such corporation owned by the Company upon any question that may be presented at such meeting, with full power to waive any notice of the calling of such meeting required by any statute or Bylaw and to consent to the holding of any such meeting without notice.

 Section 7. (a) The Company shall indemnify any person who was or is a party, or is threatened to be made a party to, any threatened, pending or completed action, suit or proceeding, whether civil, criminal, administrative or investigative (other than an action by or in the right of the Company) by reason of the fact that such person is or was a director, officer, employee or agent of the Company, or who is or was serving at the request of the Company as a director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise, against expenses (including attorneys' fees), judgments, fines and amounts paid in settlement actually and reasonably incurred by such person in connection with such action, suit or proceeding, if such person acted in good faith and in a manner such person reasonably believed to be in, or not opposed to, the best interests of the Company and, with respect to any criminal action or proceeding, if such person had no reasonable cause to believe such person's conduct was unlawful. The termination of any action, suit or proceeding by judgment, order, settlement, conviction, or upon a plea of nolo contendere or its equivalent, shall not, of itself, create a presumption that the person did not act in good faith and in a manner which such person reasonably believed to be in or not opposed to the best interests of the Company and, with respect to any criminal action or proceeding, that the person had reasonable cause to believe that such person's conduct was unlawful.

 (b) The Company shall indemnify any person who was or is a party, or is threatened to be made a party to, any threatened, pending or completed action or suit by or in the right of the Company to procure a judgment in its favor by reason of the fact that such person is or was a director, officer, employee or agent of the Company, or is or was serving at the request of the Company as a director, officer, employee or agent of another corporation, partnership, joint

  
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venture, trust or other enterprise, against expenses (including attorneys' fees) actually and reasonably incurred by such person in connection with the defense or settlement of such action or suit, if such person being indemnified acted in good faith and in a manner such person reasonably believed to be in, or not opposed to, the best interests of the Company, provided that no indemnification shall be made with respect to any claim, issue, or matter as to which such person has been adjudged to have been liable to the Company, unless, and only to the extent that, the court in which such action or suit was brought shall determine upon application that, despite the adjudication of liability, but in view of all the circumstances of the case, such person is fairly and reasonably entitled to indemnity for such expense s as the court shall deem proper.

 (c) To the extent that a director, officer, employee or agent has been successful, on the merits or otherwise, in the defense of any action, suit or proceeding referred to in paragraph (a) or (b), or in defense of any claim, issue or matter therein, such person shall be indemnified against expenses (including attorneys' fees) actually and reasonably incurred by such person in connection therewith.

 (d) Any indemnification under paragraph (a) or (b) (unless ordered by a court) shall be made by the Company only as authorized in the specific case, upon a determination that indemnification of the director, officer, employee or agent is proper in the circumstances because such person has met the applicable standard of conduct set forth in paragraph (a) or (b). Such determination shall be made (1) by the Board of Directors by a majority vote of a quorum consisting of directors who were not parties to such action, suit or proceeding, or (2) if such a quorum is not obtainable, or, even if obtainable, if a quorum of disinterested directors so directs, by independent legal counsel in a written opinion, or (3) by the shareholders of the Company.

 (e) Expenses incurred in defending a civil or criminal action, suit or proceeding may be paid by the Company in advance of the final disposition of such action, suit or proceeding, upon receipt of an undertaking by or on behalf of the director, officer, employee or agent to repay such amount if it shall ultimately be determined that such person is not entitled to be indemnified by the Company as authorized in this Section 7.

 (f) The indemnification and advancement of expenses provided by or granted under the other subsections of this Section 7 shall be effective with respect to acts, errors or omissions occurring prior to, on or subsequent to the date of adoption hereof and such indemnification shall not be deemed exclusive of any other rights to which those seeking indemnification or advancement of expenses may be entitled under any Bylaw, agreement, vote of shareholders or disinterested directors, or otherwise, both as to action by a director, officer, employee or agent in such person's official capacity and as to action in another capacity while holding such office.

 (g) The Company may purchase and maintain insurance on behalf of any person who is or was a director, officer, employee or agent of the Company, or who is or was serving at the request of the Company as a director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise, against any liability asserted against such
person and incurred by such person in any such capacity, or arising out of such person's status as such, whether or not the Company would have the power to indemnify such person against such liability under the provisions of this Section 7.

  
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 (h) If the Company has paid indemnity or has advanced expenses to a director, officer, employee or agent, the Company shall report the indemnification or advance in writing to the shareholders with or before the notice of the next shareholders' meeting.

 (i) For purposes of this Section 7 references to "the Company" shall include, in addition to the surviving corporation, any merging corporation (including any corporation having merged with a merging corporation) absorbed in a merger which, if its separate existence had continued, would have had the power and authority to indemnify its directors, officers, and employees or agents, so that any person who was a director, officer, employee or agent of such merging corporation, or was serving at the request of such merging corporation as a director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise, shall stand in the same position under the provisions of this Section 7 with respect to the surviving corporatio n as such person would have with respect to such merging corporation if its separate existence had continued.

 (j) For purposes of this Section 7, references to "other enterprise" shall include employee benefit plans, and references to "serving at the request of the Company" shall include any service as a director, officer, employee or agent of the Company which imposes duties on, or involves services by such director, officer, employee, or agent with respect to an employee benefit plan, its participants, or beneficiaries. A person who acted in good faith and in a manner such person reasonably believed to be in the best interests of the participants and beneficiaries of an employee benefit plan shall be deemed to have acted in a manner "not opposed to the best interests of the Company" as referred to in this Section 7.

 (k) The indemnification and advancement of expenses provided by or granted under this Section 7 shall, unless otherwise provided when authorized or ratified, continue as to a person who has ceased to be a director, officer, employee, or agent and shall inure to the benefit of the heirs, executors, and administrators of that person.

ARTICLE VII
AMENDMENT OR REPEAL OF BYLAWS


 These Bylaws may be added to, amended or repealed by the Board of Directors at any regular or special meeting of the Board.
 
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EX-3.2 4 ex3_2.htm EXHIBIT 3.2 CILCORP BYLAWS Exhibit 3.2 CILCORP Bylaws

                                                                                                                                           &n bsp;                                                                                                                                                                           ;                      Exhibit 3.2

BY-LAWS

 

OF

 

CILCORP INC.

 

AMENDED AND RESTATED AS OF OCTOBER 8, 2004

 

 

ARTICLE I.

 

OFFICES

 

Section 1.  The registered office of the Corporation required by the Illinois Business Corporation Act of 1983, as amended (the "Act"), to be maintained in the State of Illinois shall be in the City of Chicago, County of Cook, State of Illinois.  The Corporation may also have offices at such other places both within and without the State of Illinois as the Board of Directors may from time to time determine or the business of the Corporation may require. 

 

ARTICLE II.

 

SHAREHOLDERS

 

Section 1.  Time and Place of Meetings.  The annual meeting of the shareholders shall be held on the fourth Tuesday in May of each year (or if such day shall be a legal holiday, then upon the next succeeding day not a legal holiday) or upon such other day determined by resolution of the Board of Directors.  Each such regular annual meeting shall be held at such time and at such location, within or without the State of Illinois, as the Board of Directors shall order.  At such annual meeting, a board of directors shall be elected and such other business shall be transacted as may properly come before such meeting. 

 

Section 2.  Annual Meetings.  An annual meeting of shareholders shall be held for the purpose of electing directors and transacting such other business as may properly be brought before the meeting.  The date of the annual meeting shall be determined by the Board of Directors. 

 

Section 3.  Special Meetings.  Special meetings of the shareholders, for any purpose or purposes, unless otherwise prescribed by law, may be called by the Chief Executive Officer, by the President, by the Chairman of the Board, by a majority of the Board of Directors, or by the holders of not less than twenty percent of the outstanding shares entitled to vote on the matter for which the meeting is called by written request executed by such holders and delivered to the President or the Secretary of the Corporation. 

 

Section 4.  Notice of Meetings.  Written notice of each meeting of the shareholders stating the place, date and time of the meeting and, in the case of a special meeting, the purpose or purposes for which the meeting is called, shall be delivered not less than ten nor more than sixty days before the date of the meeting, or in the case of a merger, consolidation, share exchange, dissolution or sale, lease or exchange of assets, not less than twenty nor more than sixty days before the date of the meeting, either personally or by mail, by the President, or by the Secretary at the direction of the President or the person or persons calling the meeting, to each shareholder of record entitled to vote at such meeting.  If mailed, such notice shall be deemed to be delivered when deposited in the United States mail, addressed to the shareholder at his address as it appears on the records of the Corporation, with postage thereon prepaid. 

 

 


 
   

 

Any shareholder entitled to receive notice may waive notice of any meeting by a writing executed and delivered to the Corporation either before or after the meeting.  Attendance of a shareholder at any meeting shall constitute a waiver of notice of such meeting, unless the shareholder attends such meeting for the express purpose of objecting to the holding of such meeting because proper notice was not given and at the beginning of such meeting records such objection with the person acting as secretary of the meeting and does not thereafter vote on any action taken at the meeting. 

 

Section 5.  Quorum.  The holders of record of a majority of the shares issued and outstanding and entitled to vote thereat, represented in person or by proxy, shall constitute a quorum at all meetings of the shareholders for the transaction of business, except as otherwise provided by the Act or by the Articles of Incorporation.  If a quorum is not represented, the holders of record of the shares represented in person or by proxy at the meeting and entitled to vote thereat shall have power, by the affirmative vote of the holders of a majority of such shares, to adjourn the meeting to another time and/or place, without notice other than announcement at the meeting, except as hereinafter provided, until a quorum shall be present or represented.  A t such adjourned meeting, at which a quorum shall be present or represented, any business may be transacted which might have been transacted at the original meeting.  If the adjournment is for more than thirty days, or if after the adjournment a new record date is fixed for the adjourned meeting, a notice of the adjourned meeting shall be given to each shareholder of record entitled to vote at the meeting.  Withdrawal of shareholders from any meeting shall not cause the failure of a duly constituted quorum at such meeting. 

 

Section 6.  Voting.  At all meetings of the shareholders, each shareholder shall be entitled to vote, in person or by proxy, each share owned by such shareholder of record on the record date for the meeting.  Each outstanding share shall be entitled to one vote on each matter submitted to a vote at a meeting of shareholders, unless otherwise provided in the Act or in the Articles of Incorporation.  When a quorum is present at any meeting, the affirmative vote of the holders of record of a majority of the shares having voting power represented in person or by proxy shall decide any question brought before such meeting, unless the question is one upon which, by express provision of the Act or of the Articles of Incorporation, a different vote is r equired, in which case such express provision shall govern and control the decision of such question.  A shareholder who is in attendance at a meeting of shareholders in person or by proxy, but who abstains from the vote on any matter, shall not be deemed to be represented at such meeting for purposes of the preceding sentence with respect to such vote, but shall be deemed to be represented at such meeting for all other purposes. 

 

Section 7.  Informal Action by Shareholders.  Unless otherwise provided by the Act or by the Articles of Incorporation, any action required to be taken at a meeting of the shareholders, or any other action which may be taken at a meeting of the shareholders, may be taken without a meeting and without a vote, if a consent in writing, setting forth the action so taken, shall be signed by (a) the holders of outstanding shares having not less than the minimum number of votes that would be necessary to authorize or take such action at a meeting at which all shares entitled to vote thereon were present and voting, provided, that (i) at least five days prior to the execution of the consent a notice in writing is delivered to all of the shareholders entitl ed to vote with respect to the subject matter thereof, and (ii) those shareholders who have not consented in writing are notified in writing of the taking of the corporate action promptly after the effective date of such action; or (b) all of the shareholders entitled to vote with respect to the subject matter thereof. 

 

Section 8.  Proxies.  At all meetings of shareholders, a shareholder may vote in person or vote by proxy which is executed by the shareholder or his duly authorized attorney-in-fact.  Such proxy shall be filed with the Secretary or other person authorized to tabulate votes at any time

 

 


 
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prior to the commencement of the meeting.  No proxy shall be valid after eleven months from the date of its execution unless otherwise provided in the proxy. 

 

ARTICLE III.

 

DIRECTORS

 

Section 1.  General Powers.  The business and affairs of the Corporation shall be managed and controlled by or under the direction of its Board of Directors, which may exercise all such powers of the Corporation and do all such lawful acts and things as are not by law or by the Articles of Incorporation or by these By-laws directed or required to be exercised or done by the shareholders. 

 

Section 2.  Number, Qualification and Tenure.  The Board of Directors of the Corporation shall consist of not less than three (3) members and not more than eight (8) members, as may be determined by the Board of Directors from time to time.  Within the limits above specified, the number of directors shall be determined from time to time by resolution of the Board of Directors.  The directors shall be elected at the annual meeting of the shareholders, except as provided in the Articles of Incorporation or Section 3 of this Article, and each director elected shall hold office until his successor is elected and qualified or until his earlier death, termination, resignation or removal from office.  Any decrease in the number of directors shall not have the effect of shortening the term of any incumbent director. 

 

Section 3.  Vacancies and Newly Created Directorships.  Vacancies and newly created directorships resulting from any increase in the number of directors may be filled by the appointment of a majority of the directors then in office though less than a quorum, and each director so appointed shall hold office until the next annual meeting of shareholders and until his successor is elected and qualified or until the earlier death, termination, resignation or removal from office of such director. 

 

Section 4.  Independent Director

 

(a)  The Corporation shall have at all times one indi­vid­ual who is an Inde­pen­dent Director (as defined below).  If the Independent Director resigns, dies or be­comes inca­pacitated, or such position is otherwise vacant, no action requiring the unanimous affirma­tive vote of the directors shall be taken until a successor Independent Director is appointed and qualified and approves such ac­tion.

 

(b)  Notwithstanding any other provision of these By‑laws and any provision of law that otherwise so empow­ers the Corporation, the Corporation shall not, without the prior unanimous con­sent of the Board of Directors, including the Independent Director, do any of the fol­low­ing: (i) make a general assignment for the benefit of creditors; (ii) file a voluntary petition in bankruptcy; (iii) file a petition or answer seeking reorganization, arrangement, composition, readjustment, liquidation, dissolution or similar relief under any statute, law or regulation; (iv) file an answer or other pleading admitting or failing to contest the material allegations of a petition filed against it in any proceeding seeking reorganization, arrangement, composition, readjustment, liquidation, dissolution or similar relief under any statute, law or regulation, or the entry of any order appointing a trustee, liquidator or receiver of it or of its assets or any substantial portion thereof; or (v) seek, consent to or acquiesce in the appointment of a trustee, receiver or liquidator of it or of all or any substantial part of its assets.  With regard to any action con­tem­plated by the pre­ceding sentence, or with regard to any action taken or determination made at any time when the Corporation is insolvent, each director will owe its prima­ry fidu­ciary duty to the Corporation (including the credi­tors of the Corporation).


 
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(c)  For purposes of these By‑laws of the Corporation, "Independent Director" shall mean, with respect to the Corporation, a director who is not, and within the last five years was not (except solely by virtue of such person's serving as, or affiliation with any other person serving as, an independent director of The AES Corporation ("Parent") or any of its affiliates, (i) a stockholder, member, partner, director, officer, employee, affiliate, customer, supplier, creditor or independent contractor of, or any person that has received any benefit in any form what­ever from, or any person that has provid­ed any ser­vice in any form whatever to, or any major creditor (or any affiliate of any major creditor) of, the Parent or any of its affiliates, o r (ii) any person owning beneficially, directly or indirectly, any outstanding shares of common stock, any limited liability corporation interests or any partnership interests, as applicable, of the Parent or any of its affiliates, or of any major creditor (or any affiliate of any major creditor) of any of the foregoing, or a stockholder, member, partner, director, officer, employee, affiliate, customer, supplier, creditor or independent contractor of, or any person that has received any benefit in any form whatever from, or any person that has provided any service in any form whatever to, such bene­ficial owner or any of such beneficial owner's affiliates, or (iii) a member of the immediate family of any person de­scribed above; provided that the indirect or beneficial ownership of stock through a mutual fund or similar diversified investment vehicle with respect to which the owner does not have discretion or control over the investments held by such diversified investment vehicle shall not p reclude such owner from being an Independent Director.  For purposes of this definition, "major creditor" shall mean a natural person or business entity to which the Parent or any of its affiliates has outstanding indebtedness for borrowed money or credit on open account in a sum sufficiently large as would reasonably be expected to influence the judgment of the proposed Independent Director adversely to the interests of the Corporation when the interests of that person or entity are adverse to those of the Corporation.

 

Section 5.  Directors' Duties.  The directors, including the Independent Director, will act in good faith in accordance with the terms of the organizational documents and applicable law, and make decisions with respect to the business and operations of the Corporation independent of, and not dictated by, the Parent, or any other affiliate thereof, and any director shall bear a fiduciary duty to the Corporation (including its creditors).

 

Section 6.  Place of Meetings.  The Board of Directors may hold meetings, both regular and special, either within or without the State of Illinois. 

 

Section 7.  Meetings.  The Board of Directors shall hold a regular meeting, to be known as the annual meeting, immediately following each annual meeting of the shareholders without any notice being given.  Other regular meetings of the Board of Directors shall be held at such time and place as the Board of Directors may designate from time to time.  No notice of regular meetings need be given, other than by announcement at the immediately preceding regular meeting.  Special meetings of the Board of Directors may be called by or at the request of the Chairman of the Board or a majority of the Board of Directors.  Notice of any special meeting of the Board shall be given at least two days prior thereto, either in writing, or telephonically if confirmed promptly in writing, to each director at the address shown for such director on the records of the Corporation.                              

 

Section 8.  Waiver of Notice; Business and Purpose.  Notice of any meeting of the Board of Directors may be waived in writing signed by the person or persons entitled to such notice either before or after the time of the meeting.  The attendance of a director at any 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 any business because the meeting is not lawfully called or convened and at the beginning of such meeting records such objection with the person acting as secretary of the meeting and does not thereafter vote on any action taken at the meeting.  Neither the business to be transacted at, nor the purpose of, any regular or spec ial

 

 

 


 
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meeting of the Board need be specified in the notice or waiver of notice of such meeting, unless specifically required by the Act. 

 

Section 9.  Quorum and Voting.  At all meetings of the Board of Directors a majority of the total number of directors then in office shall constitute a quorum for the transaction of business.  If a quorum shall not be present at any meeting of the Board of Directors, the directors present thereat may adjourn the meeting without notice other than announcement at the meeting, to any other date, time and place until a quorum shall be present.  The act of a majority of the directors present at any meeting at which there is a quorum shall be the act of the Board of Directors, unless the act of a greater number is required by the Act or by the Articles of Incorporation.  Withdrawal of directors from any meeting shall not cause the failure of a du ly constituted quorum at such meeting.  A director who is in attendance at a meeting of the Board of Directors but who abstains from the vote on any matter by announcing his abstention to the person acting as secretary of the meeting and not voting on such matter shall not be deemed to be present at such meeting for purposes of the preceding sentence or Section 15 of this Article with respect to such vote, but shall be deemed to be present at such meeting for all other purposes. 

 

Section 10.   Organization.  The Chairman of the Board, if elected, shall act as chairman at all meetings of the Board of Directors.  If the Chairman of the Board is not elected or if elected, is not present, the Vice Chairman, if any, or, if no such Vice Chairman is present, a director chosen by a majority of the directors present, shall act as chairman at such meeting of the Board of Directors.

 

Section 11.  Committees.  The Board of Directors, by resolution adopted by a majority of the whole Board, may designate two or more directors to constitute an Executive Committee.  The Board of Directors, by resolution adopted by a majority of the whole Board, may create one or more other committees and appoint two or more directors to serve on such committee or committees.  Each director appointed to serve on any such committee shall serve, unless the resolution designating the respective committee is sooner amended or rescinded by the Board of Directors, until the next annual meeting of the Board or until his respective successor is designated.  The Board of Directors, by resolution adopted by a majority of the whole Board, may also designate additional directors as alternate members of any committee to serve as members of such committee in the place and stead of any regular member or members thereof who may be unable to attend a meeting or otherwise unavailable to act as a member of such committee.  In the absence or disqualification of a member and all alternate members designated to serve in the place and stead of such member, the member or members thereof present at any meeting and not disqualified from voting, whether or not such member or members constitute a quorum, may unanimously appoint another director to act at the meeting in the place and stead of such absent or disqualified member.

 

      The Executive Committee may exercise all the powers and authority of the Board of Directors in the management of the business and affairs of the Corporation between the meetings of the Board of Directors, and any other committee may exercise the power and authority of the Board of Directors to the extent specified by the resolution designating such committee, or the Articles of Incorporation or these By-laws; provided, however, that no committee may take any action that is expressly required by the Act or the Articles of Incorporation or these By-laws to be taken by the Board of Directors and not by a committee thereof.  Each committee shall keep a record of its acts and proceedings, which shall form a part of the records of the Corporation in the custody of the Secretary, and all actions of each committee shall be reported to the Board of Directors at the next meeting of the Board.

 

      Meetings of committees may be called at any time by the Chairman of the Board, if any, or the chairman of the respective committee.  A majority of the members of the committee shall constitute a quorum for the transaction of business and, except as expressly limited by this

 

 


 
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section, the act of a majority of the members present at any meeting at which there is a quorum shall be the act of such committee.  Except as expressly provided in this section or in the resolution designating the committee, a majority of the members of any such committee may select its chairman, fix its rules of procedure, fix the time and place of its meetings and specify what notice of meetings, if any, shall be given. 

 

Section 12.   Action without Meeting.  Unless otherwise specifically prohibited by the Articles of Incorporation or these By-laws, any action required or permitted to be taken at any meeting of the Board of Directors or any committee thereof may be taken without a meeting, if all members of the Board of Directors or such committee, as the case may be, execute a consent thereto in writing setting forth the action so taken, and the writing or writings are filed with the minutes of proceedings of the Board of Directors or such committee. 

 

Section 13.   Attendance by Telephone.  Members of the Board of Directors or any committee thereof may participate in and act at any meeting of the Board of Directors or such committee, as the case may be, through the use of a conference telephone or other communications equipment by means of which all persons participating in the meeting can hear each other.  Participation in such meeting shall constitute attendance and presence in person at the meeting of the person or persons so participating. 

 

Section 14.  Compensation.  By resolution of the Board of Directors, irrespective of any personal interest of any of the members thereof, the directors may be paid their reasonable expenses, if any, of attendance at each meeting of the Board of Directors and may be paid a fixed sum for attendance at meetings or a stated salary as directors, payable in cash or securities.  These payments shall not preclude any director from serving the Corporation in any other capacity and receiving compensation therefor.  Members of special or standing committees may be allowed like compensation for attending committee meetings. 

 

Section 15.  Presumption of Assent.  A director who is present at a meeting of the Board of Directors or any committee thereof when corporate action is taken shall be deemed to have assented to the action taken unless: (1) he objects at the beginning of the meeting to holding such meeting or transacting business at such meeting; (2) his dissent from the action taken is entered in the minutes of such meeting; or (3) he delivers written notice of his dissent to the person acting as the secretary of the meeting before the adjournment thereof or forwards such dissent by registered or certified mail to the Secretary immediately after the adjournment of such meeting.  The right of dissent is not available to a director who votes in favor of the action take n. 

 

ARTICLE IV.

 

OFFICERS

 

     Section 1.  Enumeration.  The officers of the Corporation shall be chosen by the Board of Directors and shall include a President and a Secretary. The Board of Directors may also elect a Chairman of the Board, a Vice Chairman, one or more Vice Presidents, a Treasurer, one or more Assistant Secretaries and Assistant Treasurers and such other officers and agents as it may deem appropriate.  Any number of offices may be held by the same person. 

 

 


 
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      Section 2.  Term of Office.  The officers of the Corporation shall be elected at the annual meeting of the Board of Directors and shall hold office until their successors are elected and qualified or until their earlier death, termination, resignation or removal from office.  Any officer or agent of the Corporation may be removed, with or without cause, 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 or agent shall not of itself create contract rights.  Any vacancy in any office because of death, resignation, term ination, removal, disqualification or otherwise, may be filled by the Board of Directors for the unexpired portion of the term.  

 

     Section 3.  Chief Executive Officer.  The Chief Executive Officer of the Corporation, if elected, shall have general supervision, direction and control of the business and affairs of the Corporation, subject to the control of the Board of Directors, and shall have such other functions, authority and duties as customarily appertain to the office of the chief executive officer of a business corporation or as may be prescribed by the Board of Directors. 

 

     Section 4.  President.  During any period when there shall be an office of Chief Executive Officer, the President shall be the chief operating officer of the Corporation and shall have such functions, authority and duties as may be prescribed by the Board of Directors or the Chief Executive Officer.  During any period when there shall not be an office of Chief Executive Officer, the President shall be the chief executive officer of the Corporation, and, as such, shall have the functions, authority and duties provided for the Chief Executive Officer.

 

     Section 5.  Vice President. The Vice President or, if there shall be more than one, each Vice President, in the absence of the President or in the event of the President's inability or refusal to act (and if there be no Chief Executive Officer), shall have the authority to perform the duties of the President, subject to such limitations thereon as may be imposed by the Board of Directors, and such other duties as may from time to time be prescribed by the Board of Directors, the Chief Executive Officer or the President.

 

     Section 6.  Secretary.  The Secretary shall:  (a) keep a record of all proceedings of the shareholders, the Board of Directors and any committees thereof in one of more books provided for that purpose; (b) give, or cause to be given, all notices that are required by law or these By-laws to be given by the Secretary; (c) be custodian of the corporate records and, if the Corporation has a corporate seal, of the seal of the Corporation; (d) have authority to affix the seal of the Corporation to all instruments the execution of which requires such seal and to attest such affixing of the seal; (e) keep a register of the post office address of each shareholder which shall be furnished to the Secretary by such shareholder; (f) sign, with the Chief Executive Officer, if any, or President or any Vice President, or any other officer thereunto authorized by the Board of Directors, any certificates for shares of the Corporation, or any deeds, mortgages, bonds, contracts or other instruments which the Board of Directors has authorized to be executed by the signature of more than one officer; (g) have general charge of the share transfer books of the Corporation; (h) have authority to certify as true and correct copies of the By-laws, or resolutions of the shareholders, the Board of Directors and committees thereof, and of other documents of the Corporation; and (i) in general, perform the duties incident to the office of secretary and such other duties as from time to time may be prescribed by the Board of Directors, the Chief Executive Officer or the President.  The Board of Directors may give general authority to any other officer to affix the seal of the Corporation and to attest such affixing of the seal.

 

     Section 7.  Assistant Secretary.  The Assistant Secretary, or if there shall be more than one, each Assistant Secretary in the absence of the Secretary or in the event of the Secretary's inability or refusal to act, shall have the authority to perform the duties of the Secretary, subject to such limitations thereon as may be imposed by the Board of Directors, and such other duties as may
 
 

 
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 from time to time be prescribed by the Board of Directors, the Chief Executive Officer, the President or the Secretary.

 

     Section 8.  Treasurer.  The Treasurer shall be the principal accounting and financial officer of the Corporation.  The Treasurer shall:  (a) have charge of and be responsible for the maintenance of adequate books of account for the Corporation; (b) have charge and custody of all funds and securities of the Corporation, and be responsible therefor and for the receipt and disbursement thereof; and (c) perform the duties incident to the office of treasurer and such other duties as may from time to time be prescribed by the Board of Directors, the Chief Executive Officer or the President.  The Treasurer may sign with the Chief Executive Officer, if any, or the President, or any Vice President, or any other officer thereunto authorized by th e Board of Directors, certificates for shares of the Corporation.  If required by the Board of Directors, the Treasurer shall give a bond for the faithful discharge of his duties in such sum and with such surety or sureties as the Board of Directors may determine.

 

     Section 9.  Assistant Treasurer.  The Assistant Treasurer, or if there shall be more than one, each Assistant Treasurer, in the absence of the Treasurer or in the event of the Treasurer's inability or refusal to act, shall have the authority to perform the duties of the Treasurer, subject to such limitations thereon as may be imposed by the Board of Directors, and such other duties as may from time to time be prescribed by the Board of Directors, the Chief Executive Officer, the President or the Treasurer.

 

     Section 10.  Other Officers and Agents.  Any officer or agent who is elected or appointed from time to time by the Board of Directors and whose duties are not specified in these By-laws shall perform such duties and have such powers as may from time to time be prescribed by the Board of Directors, the Chief Executive Officer or the President.

 

ARTICLE V.

 

CERTIFICATES FOR SHARES

 

     Section 1.  Form.  The shares of the Corporation shall be represented by certificates; provided, however, the Board of Directors may provide by resolution or resolutions that some or all of any or all classes or series of the Corporation's shares shall be uncertificated shares.  Each certificate for shares shall be consecutively numbered or otherwise identified.  Certificates representing shares in the Corporation shall be signed by or in the name of the Corporation by the Chief Executive Officer or the President or a Vice President and by the Treasurer or an Assistant Treasurer or the Secretary or an Assistant Secretary of the Corporation.  Where a certificate is countersigned by a transfer agent, other than the Corporati on or an employee of the Corporation, or by a registrar, the signatures of one or more officers of the Corporation may be facsimiles.  In case any officer, transfer agent or registrar who has signed or whose facsimile signature has been placed upon a certificate shall have ceased to be such officer, transfer agent or registrar before such certificate is issued, the certificate may be issued by the Corporation with the same effect as if such officer, transfer agent or registrar were such officer, transfer agent or registrar at the date of its issue. 

 

     Section 2.  Transfer.  Upon surrender to the Corporation or the transfer agent of the Corporation of a certificate for shares duly endorsed or accompanied by proper evidence of succession, assignment or authority to transfer, it shall be the duty of the Corporation to issue a new certificate or uncertificated shares in place of any certificate therefor issued by the Corporation to the person entitled thereto, cancel the old certificate and record the transaction in its share book.

 



 
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     Section 3.  Replacement.  In case of the loss, destruction, mutilation or theft of a certificate representing shares of the Corporation, a new certificate may be issued upon the surrender of the mutilated certificate or, in the case of loss, destruction or theft of a certificate, upon satisfactory proof of such loss, destruction or theft and upon such terms as the Board of Directors may prescribe.  The Board of Directors may in its discretion require the owner of the lost, destroyed or stolen certificate, or his legal representative, to give the Corporation a bond, in such sum and in such form and with such surety or sureties as it may direct, to indemnify the Corporation against any claim that may be made against it with respect to the certifica te alleged to have been lost, destroyed or stolen.

 

ARTICLE VI.

 

INDEMNIFICATION OF DIRECTORS, OFFICERS,

EMPLOYEES AND AGENTS

 

     Section 1.  Third Party Actions.  The Corporation shall indemnify any person who was or is a party or is threatened to be made a party to any threatened, pending, or completed action, suit or proceeding, whether civil, criminal, administrative or investigative, including all appeals (other than an action, suit or proceeding by or in the right of the Corporation) by reason of the fact that he is or was a director or officer of the Corporation (and the Corporation, in the discretion of the Board of Directors, may so indemnify a person by reason of the fact that he is or was an employee or agent of the Corporation or is or was serving at the request of the Corporation, another corporation, partnership, joint venture, trust or other enterprise in any capa city), against expenses (including attorneys' fees), judgments, decrees, fines, penalties and amounts paid in settlement actually and reasonably incurred by him in connection with such action, suit or proceeding if he acted in good faith and in a manner he reasonably believed to be in or not opposed to the best interests of the Corporation and, with respect to any criminal action or proceeding, had no reasonable cause to believe his conduct was unlawful.  The termination of any action, suit or proceeding by judgment, order, settlement, conviction, or upon a plea of nolo contendere or its equivalent, shall not, of itself, create a presumption that the person did not act in good faith or in a manner he reasonably believed to be in or not opposed to the best interests of the Corporation and, with respect to any criminal action or proceeding, had reasonable cause to believe his conduct was unlawful.


 

     Section 2.  Actions By or in the Right of the Corporation.  The Corporation shall indemnify any person who was or is a party or is threatened to be made a party to any threatened, pending or completed action or suit, including all appeals, by or in the right of the Corporation to procure a judgment in its favor by reason of the fact that he is or was a director or officer of the Corporation (and the Corporation, in the discretion of the Board of Directors, may so indemnify a person by reason of the fact that he is or was an employee or agent of the Corporation or is or was serving at the request of the Corporation in any other capacity for or on behalf of the Corporation), against expenses (including attorneys' fees) actually and reasonably incurred b y him in connection with the defense or settlement of such action or suit if he acted in good faith and in a manner he reasonably believed to be in or not opposed to the best interests of the Corporation, except that no indemnification shall be made in respect of any claim, issue or matter as to which such person shall have been finally adjudged to be liable for negligence or misconduct in the performance of his duty to the Corporation unless and only to the extent that the court in which such action or suit was brought, or any other court of competent jurisdiction, shall determine upon application that, despite the adjudication of liability but in view of all the circumstances of the case, such person is fairly and reasonably entitled to indemnity for such expenses as such court shall deem proper.  Notwithstanding the foregoing, the Corporation shall be required to indemnify an officer or director in connection with an action, suit or proceeding initiated by such person only if such action, suit or pro ceeding was authorized by the Board of Directors.

 

 

 


 
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     Section 3.  Indemnity if Successful.  To the extent that a director, officer, employee or agent of the Corporation has been successful on the merits or otherwise in defense of any action, suit or proceeding referred to in Section 1 or 2 of this Article, or in defense of any claim, issue or matter therein, he shall be indemnified against expenses (including attorneys' fees) actually and reasonably incurred by him in connection therewith.

 

     Section 4.  Standard of Conduct.  Except in a situation governed by Section 3 of this Article, any indemnification under Section 1 or 2 of this Article (unless ordered by a court) shall be made by the Corporation only as authorized in the specific case upon a determination that indemnification of the director or officer, employee or agent is proper in the circumstances because he has met the applicable standard of conduct set forth in Section 1 or 2, as applicable, of this Article.  Such determination shall be made (i) by a majority vote of directors acting at a meeting at which a quorum consisting of directors who were not parties to such action, suit or proceeding is present, or (ii) if such a quorum is not obtainable, or even if obtainable, a quorum of disinterested directors so directs, by independent legal counsel in a written opinion, or (iii) by the shareholders.

 

     Section 5.  Expenses.  Expenses of each officer and director hereunder indemnified actually and reasonably incurred in defending a civil or criminal action, suit or proceeding or threat thereof shall be paid by the Corporation in advance of the final disposition of such action, suit or proceeding upon receipt of any undertaking by or on behalf of such person to repay such amount unless it shall ultimately be determined that he is entitled to be indemnified by the Corporation as authorized in this Article.  Such expenses incurred by employees and agents may be so paid upon receipt of the aforesaid undertaking and such other terms and conditions, if any, as the Board of Directors deems appropriate.

 

     Section 6.  Nonexclusivity.  The indemnification and advancement of expenses provided by, or granted pursuant to other Sections of this Article, shall not be deemed exclusive of any other rights to which those seeking indemnification or advancement of expenses may now or hereafter be entitled under any law, by-law, agreement, vote of shareholders or disinterested directors or otherwise, both as to action in his official capacity and as to action in another capacity while holding such office.

 

     Section 7.  Insurance.  The Corporation may purchase and maintain insurance, on behalf of any person who is or was a director, officer, employee or agent of the Corporation, or is or was serving at the request of the Corporation as a director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise against any liability asserted against him and incurred by him in any such capacity, or arising out of his status as such, whether or not the Corporation would have the power to indemnify him against such liability under the provisions of the Act.

     Section 8.  Definitions.  For purposes of this Article, references to "the Corporation" shall include, in addition to the surviving corporation, any merging corporation (including any corporation having merged with a merging corporation) absorbed in a merger which, if its separate existence had continued, would have had the power and authority to indemnify any or all of its directors, officers, employees and agents, so that any person who was a director, officer, employee or agent of such merging corporation, or was serving at the request of such merging corporation in any other capacity, shall stand in the same position under the provisions of this Article with respect to the surviving corporation as such person would have had with respect to such me rging corporation if its separate existence had continued as such corporation was constituted immediately prior to such merger.

 

 

 


 
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     For purposes of this Article, references to "other capacities" shall include serving as a trustee or agent for any employee benefit plan; references to "fines" shall include any excise taxes assessed on a person with respect to an employee benefit plan; and references to "serving at the request of the Corporation" shall include any service as a director, officer, employee or agent of the Corporation which imposes duties on, or involves services by, such director, officer, employee, or agent with respect to an employee benefit plan, its participants, or beneficiaries.  A person who acted in good faith and in a manner he reasonably believed to be in the best interests of the participants and beneficiaries of an employee benefit plan shall be deemed to have acted in a manner "not opposed to the best interests of the Corporation" as referred to in this Article.

 

     Section 9.  Reports to Shareholders.  If required by the Act, the Corporation shall report any indemnity payment or advancement of expenses by the Corporation to any director, officer, employee or agent provided for in this Article to the shareholders in writing either with or before the distribution of the notice of the next shareholders' meeting. 

 

     Section 10.  Severability.  If any provision hereof is invalid or unenforceable in any jurisdiction, the other provisions hereof shall remain in full force and effect in such jurisdiction, and the remaining provisions hereof shall be liberally construed to effectuate the provisions hereof, and the invalidity of any provision hereof in any jurisdiction shall not affect the validity or enforceability of such provision in any other jurisdiction.

 

     Section 11.  Amendment.  The right to indemnification conferred by this Article shall be deemed to be a contract between the Corporation and each person referred to herein until amended or repealed, but no amendment to or repeal of these provisions shall apply to or have any effect on the right to indemnification of any person with respect to any liability or alleged liability of such person for or with respect to any act or omission of such person occurring prior to such amendment or repeal

 

ARTICLE VII.

 

SEPARATENESS

 

Section 1.  Funds, Assets and Accounts.  The funds and other assets of the Corporation shall not be commingled with those of any other entity, and the Corporation shall maintain its accounts separate from any other person or entity.

 

Section 2.  Liability for Debts and Name.  The Corporation shall not hold itself out as being liable for the debts of any other entity, and shall conduct its own business in its own name.

 

Section 3.  Action through Agents and Identity.  The Corporation shall act solely in its own name and through its duly autho­rized directors, officers or agents in the conduct of its business, and shall conduct its business so as not to mislead others as to the identity of the entity or assets with which they are con­cerned.

 

Section 4.  Separate Records.  The Corporation shall maintain separate re­cords, books of account and financial statements, and shall not commingle its records and books of account with the records and books of account of any other entity.

 

Section 5. Formalities.  The Corporation shall observe in all material respects all formalities required by its organizational documents and applicable law.

 

Section 6.  Capitalization.  The Corporation shall at all times ensure that its capitalization is adequate in light of its business and purpose.

 

 


 
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Section 7.  Debts of Affiliates.  Subject to the last sentence of this Section 7, (i) neither the Parent nor any affiliate of the Parent (other than the Corporation) shall guaranty, become liable on or hold itself out as being liable for the debts of the Corporation; (ii) the Corporation shall not guarantee or become obligated for the debts of the Parent or any affiliate thereof (other than the Corporation), or otherwise hold out its credit as being available to satisfy the obligations of the Parent or any affiliate thereof (other than the Corporation); (iii) the Corporation shall not pledge its assets for the benefit of Parent or any of its affiliates;  (iv) the Corporation shall not make loans or advances to Parent or any of its affiliates, and sha ll not acquire obligations or securities of the Parent or any affiliate thereof (other than the Corporation), other than the settlement of purchase contracts with respect to any Premium Income Equity Securities or similar securities issued by the Corporation.  Notwithstanding the foregoing, the Corporation may take any action otherwise prohibited under this Section 7 if such action is taken with respect to its own subsidiaries, and its own subsidiaries may take any action otherwise prohibited under this Section 7 if such action is taken with respect to the Corporation. 

 

Section 8.  Payment of Liabilities.  The Corporation shall pay its own liabilities out of its own funds.

 

Section 9.  Arm's Length Relationship with Affiliates.  The Corporation shall maintain an arm's-length relationship with its affiliates.

 

Section 10.  Overhead and Office Space.  The Corporation shall allocate fairly and reasonably any overhead for office space shared with the Parent or any affiliate thereof.

 

Section 11.  Separate Business Forms.  The Corporation shall use its own separate stationery, invoices, checks and other business forms.

 

Section 12.  Correction of Misunderstandings.  The Corporation shall correct any known misunderstanding regarding its separate identity.

 

 

ARTICLE VIII.

 

GENERAL PROVISIONS

 

     Section 1.  Fiscal Year.  The fiscal year of the Corporation shall be fixed from time to time by resolution of the Board of Directors.

 

     Section 2.  Corporation Seal.  The corporate seal, if any, of the Corporation shall be in such form as may be approved from time to time by the Board of Directors.  The seal may be used by causing it or a facsimile thereof to be impressed or affixed or in any other manner reproduced.

 

     Section 3.  Notices and Mailing.  Except as otherwise provided in the Act, the Articles of Incorporation or these By-laws, all notices required to be given by any provision of these By-laws shall be deemed to have been given (i) when received, if given in person, (ii) on the date of acknowledgment of receipt, if sent by telex, facsimile or other wire transmission, (iii) one day after delivery, properly addressed, to a reputable courier for same day or overnight delivery, or (iv) three days after being deposited, properly addressed, in the U.S. mail, certified or registered mail, postage prepaid.

 

     Section 4.  Waiver of Notice.  Whenever any notice is required to be given under the Act or the provisions of the Articles of Incorporation or these By-laws, a waiver thereof in writing, signed by the person or persons entitled to said notice, whether before or after the time stated therein, shall be deemed equivalent to notice.

 

 


 
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     Section 5.  Interpretation.  In these By-laws, unless a clear contrary intention appears, the singular number includes the plural number and vice versa, and reference to either gender includes the other gender.

 

ARTICLE IX.

 

AMENDMENTS

 

     Unless the power to make, alter, amend or repeal these By-laws is reserved to the shareholders by the Articles of Incorporation, these By-laws, including any By-law adopted by the share­holders, may be made, altered, amended or repealed by the shareholders or the Board of Directors, provided, that (i) the unanimous consent of the Board of Directors, including the Independent Director, shall be required to alter, amend or repeal (a) Section 4 and Section 5 of Article III hereof; (b) Article VII hereof; and (c) this Article IX; and (ii) subject to paragraph (i) above, the fact that the power to make, alter, amend or repeal these By-laws has been conferred upon the Board of Directors shall not divest the shareholders of the same powers.

 

 

 
  -13-  

 
EX-10.1 5 ex10_1.htm EXHIBIT 10.1 ESCROW AGREEMENT Exhibit 10.1 Escrow Agreement
                                        Exhibit 10.1

 
ESCROW AGREEMENT
 
ESCROW AGREEMENT (“Agreement”), dated as of 30th day of September, 2004, by and among Illinova Corporation, an Illinois corporation ( “Illinova”), Ameren Corporation, a Missouri corporation (“Ameren”), and JPMorgan Chase Bank, a New Yor k State Bank with an office in Houston, Harris County, Texas, as escrow agent (the “Escrow Agent”).
 
 
W I T N E S S E T H
 
WHEREAS, Illinova and Ameren, among other parties, have entered into a Stock Purchase Agreement dated as of February 2, 2004, as amended (the “Purchase Agreement”), pursuant to which Ameren will purchase from Illinova, and Illinova will sell to Ameren, all of the outstanding common stock of Illinois Power Company, an Illinois corporation (“IPC”), subject to the terms and conditions set forth in the Purchase Agreement; and
 
WHEREAS, under the terms of the Purchase Agreement, the Escrow Funds (as such term is defined below) are to be delivered to the Escrow Agent and deposited into the escrow account established hereunder to secure payment of the indemnification obligations of Illinova and its Affiliates pursuant to the Purchase Agreement as they relate to (i) the Baldwin Litigation and (ii) any plant included within the Generation Assets (excluding the Baldwin plant) (the “Other Plants”);
 
NOW, THEREFORE, in consideration of the mutual promises herein contained and for other good and valuable consideration, and intending to be legally bound, the parties hereto agree as follows:
 
1.  Definitions. Capitalized terms used but not otherwise defined herein shall have the meanings ascribed to such terms in the Purchase Agreement. As used in this Agreement the following terms shall have the meanings set forth below:
 
Baldwin Litigation” shall mean the Action listed at item 1 of Schedule 3.11 to the Purchase Agreement.
 
Other Claim” shall mean a lawsuit by any state or federal agency having authority to enforce the Clean Air Act (a) against IPC, (b) with respect to any Other Plant, (c) which lawsuit is based on claims that are substantially the same as the claims pending under the Baldwin Litigation on February 2, 2004 and (d) which lawsuit is filed prior to October 1, 2004.
 
2.  Appointment of Escrow Agent. Illinova and Ameren hereby appoint the Escrow Agent to act as escrow agent hereunder and the Escrow Agent hereby accepts such appointment for the purpose of receiving and disbursing the Escrow Funds in accordance with the terms and conditions set forth herein.
 

 
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3.  Deposit of Escrow Funds. At the Closing, Ameren will deliver to the Escrow Agent, by wire transfer of same day funds, for deposit in an escrow account (the “Escrow Account”), the sum of $100,000,000 (such sum, the “Escrow Funds”).
 
4.  Investment of Escrow Funds. Promptly after the deposit of the Escrow Funds pursuant to Section 3 hereof and until such time as all payments of principal and interest are made pursuant to Section 5 hereof, the Escrow Agent shall invest the Escrow Funds in and continue to invest the Escrow Funds in a JPMorgan Money Market Account holding Cash Eequivalents (as such term is defined below) unless otherwise instructed in writing by Illinova to invest in Cash Equivalents. For the purposes of this Agreement, “Cash Equivalents” shall mean (a) securities with maturities of 360 days or less from the date of determination, issued or fully guaranteed or insured by the United States government or any agency thereof, (b) commercial paper (in an aggregate amount of no more than $10,000,000 per issuer) of an issuer organized under the laws of any State of the United States rated at least A-l by Standard & Poor’s Corporation or P-l by Moody’s Investors Service, Inc., and (c) interest-bearing demand deposits, insured certificates of deposit, time deposits, and bankers’ acceptances of any commercial bank organized under the laws of the United States of America or any State thereof and is a member of the Federal Reserve System which issues commercial paper rated as described in the preceding clause (b) and has combined capital and surplus of at least $1,000,000,000 having maturities of 180 days or less from the date of determination, and (d) money market mutual funds consisting of one or more of the investments specified in clause (a), (b) or (c) above.
 
Receipt, investment and reinvestment of the Escrow Funds shall be confirmed by the Escrow Agent as soon as practicable by account statement.
 
5.  Escrow Payments. The Escrow Agent shall make a payment of all or part of the Escrow Funds in respect of payments authorized by paragraphs (a) or (b) or (c) below following receipt of joint instructions from Illinova and Ameren that such payment is authorized.
 
(a) Payment to Illinova in Full. The Escrow Funds and any accumulated income thereon shall be paid to Illinova following the earliest to occur of:
 
(i) Dynegy Holdings Inc.’s senior unsecured indebtedness obtaining a rating of BBB- or higher from Standard & Poor’s or Baa3 or higher from Moody’s Investor Services, Inc., and Dynegy Holdings Inc. shall not have reorganized under the federal bankruptcy law after the date of this Agreement; or
 
(ii) Potential Liability (as defined below) is less than $20,000,000.
 
(b) Payment to Illinova in Part. Until the occurrence of any of the events set forth in paragraph (a) of this Section 5, at the end of each calendar quarter following the Closing Date, if the amount of Escrow Funds exceeds the Potential Liability, such excess will be paid by the Escrow Agent to Illinova following the end of such calendar quarter.
 
(c) Payment to Ameren. To the extent that Ameren or any of its Affiliates is required to pay an amount with respect to the Baldwin Litigation or any Other Claim, and such payment would be an Indemnifiable Loss pursuant to Article IX of the Purchase Agreement, the Escrow Agent will
 

 
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pay to Ameren from the Escrow Funds the lesser of (x) such amount and (y) the full amount of the Escrow Funds. To the extent of such payment, the Seller Indemnitors’ indemnity obligation will be deemed discharged.
 
(d) Distributions of Income. On the last day of each March, June, September and December, the Escrow Agent will pay to Illinova an amount equal to the net income and gain earned on the Escrow Funds.
 
(e) Payment at Expiration Date. On the Expiration Date (as such term is defined below), the Escrow Agent shall pay all amounts remaining in the Escrow Account to Illinova; provided, however, that if, on the Expiration Date, a dispute is pending between Ameren and Illino va with respect to Ameren’s entitlement to receive a payment pursuant to paragraph (c) of this Section 5, the Escrow Agent shall pay all amounts remaining in the Escrow Account to Illinova except for any amount that is subject to such dispute (the “Disputed Amount”). The Escrow Agent shall continue to hold the Disputed Amount pursuant to this Agreement until such dispute is resolved. After the payment of any portion of the Disputed Amount, if any, required to be made to Ameren pursuant to the resolution of such dispute, the balance, if any, of the Disputed Amount shall be paid to Illinova. For purposes of this Agreement, the term “Expiration Date” shall mean December 31, 2010.
 
(f) For purposes of this Agreement, “Potential Liability” shall mean, as of any date, the amount that is the sum of :
 
(i) with respect to the Baldwin Litigation, the lesser of (A) $100,000,000 or (B) the remaining cost to IPC of complying with any settlement, consent decree or judgment applicable to IPC in the Baldwin Litigation; and
 
(ii) with respect to each Other Plant that is the subject of an Other Claim for which a settlement, consent decree or judgment with respect to such Other Plant has been entered into by or rendered against IPC, the remaining cost to IPC of complying with such settlement, consent decree or judgment; and
 
(iii) with respect to each Other Plant that is the subject of an Other Claim for which a settlement, consent decree or judgment with respect to such Other Plant has not been entered into or rendered in such litigation or proceeding, $15,000,000.
 
In the event that any settlement, consent decree or judgment requires action by IPC other than the payment of money to any Governmental Authority, the cost to IPC of compliance will be determined by applying estimated costs as determined by an engineering firm mutually acceptable to Ameren and Illinova. The fees of such engineering firm shall be shared equally by Ameren and Illinova.
 
(g) Ameren and Illinova agree to (i) jointly instruct the Escrow Agent to make the payments provided for in this Section 5 when the circumstances that are described therein arise, and (ii) endeavor in good faith to resolve disputed matters.
 

 
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6.  Taxation of Income on Escrow Funds. Illinova agrees that it shall include the income on the Escrow Funds in its gross income for the taxable year of Illinova in which such income is accrued (the “Taxable Year”).
 
7.  Exculpation and Indemnification of Escrow Agent. It is understood and agreed that the Escrow Agent shall:
 
(a)  be under no duty to accept information from any person other than Ameren and Illinova and only to the extent and in the manner provided in this Agreement;
 
(b)  be protected in acting upon any written notice, opinion, request, certificate, approval, consent or other document believed by it to be genuine and to be signed by the proper party or parties;
 
(c)  be deemed conclusively to have given and delivered any notice required to be given or delivered hereunder if the same is in writing, and (i) sent by nationally recognized overnight courier, (ii) sent by facsimile, or (iii) hand delivered:
 
addressed to Illinova at:
 
  Illinova Corporation
  c/o Dynegy Inc.
  1000 Louisiana St., Suite 5800
  Houston, Texas 77002
  Facsimile No.: (713) 507-6808
  Attention: General Counsel
 
  with a copy to:
 
  O’Melveny & Myers LLP
  1625 Eye Street, NW
  Washington, DC 20006
  Attention: David G. Pommerening
  Facsimile No.: (202) 383-5414

        and addressed to Ameren at:
 
  Ameren Corporation
  1901 Chouteau Avenue
  St. Louis, MO 63166-6149
  Attention: Steven R. Sullivan
  Facsimile No.: (314) 554-4014

 
  with a copy to:
 
  Wachtell, Lipton, Rosen & Katz
  51 West 52 Street
  New York, NY 10019-6150
 
 

 
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  Attention: Elliott V. Stein
  Facsimile No.: (212) 403-2000
 
or, in each case, to such other address as any party hereto may specify by notice in writing given in the manner described above in this paragraph (c);
 
(d)  be indemnified and held harmless jointly and severally by the other parties hereto against any claim made against it by reason of its acting or failing to act in connection with any of the transactions contemplated hereby and against any loss, liability or expense, including the expense of defending itself against any claim of liability it may sustain in carrying out the terms of this Agreement, except such claims as are occasioned by its bad faith, gross negligence, willful misconduct, fraud or any other breach of fiduciary duty;
 
(e)  have no liability or duty to inquire into the terms and conditions of any agreements to which the Escrow Agent is not a party, its duties under this Agreement being understood to be purely ministerial in nature;
 
(f)  be permitted to consult with counsel of its choice and shall not be liable for any action taken, suffered or omitted by it in good faith in accordance with the written advice of such counsel; provided, however, that nothing contained in this paragraph (f), nor any action taken by the Escrow Agent, or of any counsel, shall relieve the Escrow Agent from liability for any claims which are occasioned by its bad faith, gross negligence, willful misconduct, fraud or any other breach of fiduciary duty, all as provided in paragraph (d) above;
 
(g)  not be bound by any modification, amendment, termination, cancellation, rescission or supersession of this Agreement, unless the same shall be in writing and signed by the parties hereto;
 
(h)  if and to the extent it is uncertain as to its duties and rights hereunder, be entitled to refrain from taking any action other than to keep all property held by it in escrow until it shall be directed otherwise in writing by Illinova and Ameren, in accordance with this Agreement, or by a final judgment of a court of competent jurisdiction;
 
(i)  have no liability for any act or omission done pursuant to the instructions contained or expressly provided for herein, or written instructions given by Illinova and Ameren pursuant hereto;
 
(j)  have the right, at any time, to resign hereunder by giving written notice of its resignation to Illinova and Ameren, at their addresses set forth above, at least 30 Business Days prior to the date specified for such resignation to take effect; in which case, upon the effective date of such resignation:
 
(i)  all cash and other payments and all other property then held by the Escrow Agent hereunder shall be delivered by it to such person as may be designated in writing by Illinova and Ameren, whereupon the Escrow Agent’s obligations hereunder shall cease and terminate;
 

 
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(ii)  if no such person has been designated by such date, the Escrow Agent’s sole responsibility thereafter shall be to keep all property then held by it and to deliver the same to a person designated in writing by Illinova and Ameren, or, if no such person shall have been so designated, in accordance with the directions of a final order or judgment of a court of competent jurisdiction, and the provisions of paragraphs (f), (j) and (k) of this Section 7 shall remain in effect;
 
(k)  be reimbursed upon its request for all reasonable expenses, disbursements and advances incurred or made by it in accordance with any provisions of this Agreement, except any such expenses, disbursements or advances as may be attributable to its gross negligence, willful misconduct, bad faith, fraud or other breach of fiduciary duty. All reimbursements pursuant to this Section 7(k) shall be made one-half by Illinova and one-half by Ameren;
 
(l)  Illinova and Ameren each hereby agree to pay the Escrow Agent for its services hereunder in accordance with the Escrow Agent’s fee schedule as attached as Schedule I hereto as in effect from time to time and to pay all expenses reasonably incurred by the Escrow Agent in connection with the performance of its duties and enforcement of its rights hereunder and otherwise in connection with the preparation, operation, administration and enforcement of this Agreement, including, without limitation, attorneys’ fees, brokerage costs and related expenses incurred by the Escrow Agent (the “Escrow Agent’s Fees”). The foregoing notwithstanding, each of Illinova and Ameren will be responsible for one half of the Escrow Agent’s Fees and shall not be jointly or severally liable for the other’s share of the Escrow Agent’s Fees. In the event that Illinova fails to pay its share of the Escrow Agent’s Fees as and when the same are due, the Escrow Agent may charge to and set off any or all of such unpaid Escrow Agent’s Fees from interest earned on the Escrow Funds without any further notice; and
 
(m)  in no event shall the Escrow Agent be liable for special, indirect or consequential loss or damage of any kind whatsoever (including but not limited to lost profits), even if the Escrow Agent has been advised of the likelihood of such loss or damage and regardless of the form of action and, further, the Escrow Agent shall have no liability for any loss arising from any cause beyond its control, including, but not limited to, the following: (a) acts of God or force majeure, including, without limitation, war (whether or not declared or existing), revolution, insurrection, riot, civil commotion, accident, fire, explosion, stoppage of labor, strikes and other differences with employees; (b) any delay, error, omission or default of any mail, courier, telegraph, cable or wireless agency or operator; or (c) the acts or edicts of any government or governmental agency or other group or entity exercising governmental powers.
 
8.  Representations and Warranties of Illinova. Illinova hereby represents and warrants to each other party hereto that:
 
(a)  this Agreement has been duly authorized, executed and delivered by Illinova and is the legal, valid and binding agreement of Illinova, enforceable against Illinova in accordance with its terms, subject to applicable bankruptcy, insolvency, reorganization, moratorium or other laws relating to or affecting the rights and remedies of creditors generally and to general principles of equity (regardless of whether in equity or at law); and
 

 
-6-

 

(b)  the execution, delivery and performance of this Agreement and the consummation of the transactions contemplated hereby will not violate any provision of, or be an event that is or, with the passage of time will result in, a violation of, or result in the acceleration of or entitle any party to accelerate (whether after the giving of notice or lapse of time or both) any obligation under or pursuant to any mortgage, lien, lease, agreement, instrument, order, arbitration award, judgment or decree to which Illinova is a party or by which it or any of its assets are bound.
 
9.  Representations and Warranties of Ameren. Ameren hereby represents and warrants to each other party hereto that:
 
(a)  this Agreement has been duly authorized, executed and delivered by Ameren, and is the legal, valid and binding agreement of Ameren, enforceable against Ameren in accordance with its terms, subject to applicable bankruptcy, insolvency, reorganization, moratorium or other laws relating to or affecting the rights and remedies of creditors generally and to general principles of equity (regardless of whether in equity or at law); and
 
(b)  the execution, delivery and performance of this Agreement and the consummation of the transactions contemplated hereby will not violate any provision of, or be an event that is or, with the passage of time will result in, a violation of, or result in the acceleration of or entitle any party to accelerate (whether after the giving of notice or lapse of time or both) any obligation under or pursuant to any mortgage, lien, lease, agreement, instrument, order, arbitration award, judgment or decree to which Ameren is a party or by which it or any of its assets is bound.
 
10.  Representations and Warranties of the Escrow Agent. The Escrow Agent hereby represents and warrants to each other party hereto that:
 
(a)  this Agreement has been duly authorized, executed and delivered by the Escrow Agent, and is the legal, valid and binding agreement of the Escrow Agent, enforceable against the Escrow Agent in accordance with its terms, subject to applicable bankruptcy, insolvency, reorganization, moratorium or other laws relating to or affecting the rights and remedies of creditors generally and to general principles of equity (regardless of whether in equity or at law); and
 
(b)  the execution, delivery and performance of this Agreement and the consummation of the transactions contemplated hereby will not violate any provision of, or be an event that is or, with the passage of time will result in, a violation of, or result in the acceleration of or entitle any party to accelerate (whether after the giving of notice or lapse of time or both) any obligation under or pursuant to any mortgage, lien, lease, agreement, instrument, order, arbitration award, judgment or decree to which the Escrow Agent is a party or by which it or any of its assets is bound.
 
11.  Notices. All requests, notices or other communications hereunder shall be in writing, shall be deemed to have been given and delivered if the same is in writing, and (i) sent by nationally recognized overnight courier, (ii) sent by facsimile, or (iii) hand delivered to
 
 

 
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 the address of Illinova and Ameren, set forth in Section 7(c), and (ii) to the address of the Escrow Agent as follows:
 
     JPMorgan Chase Bank
     600 Travis Street, Suite 1150
     Houston, Texas 77002
     Attn: May Ng
     Facsimile No. (713) 216-6927

12.  Miscellaneous.
 
(a)  Illinova represents that the transfers of the Baldwin plant and the Other Plants contemplated in the Asset Transfer Agreements were completed on October 1, 1999. If the transfers of the Baldwin plant and the Other Plants contemplated in the Asset Transfer Agreements were completed at a later date than October 1, 1999, the parties agree that the reference to October 1, 2004 in this Agreement shall instead refer to the fifth anniversary of the date on which such transfers were completed.
 
(b)  Nothing in this Agreement is intended to or shall confer upon anyone other than the parties hereto any legal or equitable right, remedy or claim. This Agreement shall be governed by, and its provisions construed in accordance with, the laws of the State of New York applicable to contracts made and to be wholly performed within such state and may be modified only in writing signed by each of the parties hereto. This Agreement may be executed simultaneously in two or more counterparts, each of which shall be deemed an original, and all such counterparts shall constitute one and the same instrument. Section headings contained in this Agreement are solely for convenience of referen ce and shall not affect the meaning or interpretation of any term or provision hereof. All signatures of the parties to this agreement may be transmitted by facsimile, and such facsimile will, for all purposes, be deemed to be the original signature of such party whose signature it reproduces, and will be binding upon such party.
 
(c)  In the event funds transfer instructions are given (other than in writing at the time of execution of the Agreement), whether in writing, by telefax, or otherwise, the Escrow Agent is authorized to seek confirmation of such instructions by telephone call-back to the person or person designated on Schedule II hereto, and the Escrow Agent may rely upon the confirmations of anyone purporting to be the person or persons so designated. The persons and telephone numbers for call-backs may be changed only in writing actually received and acknowledged by the Escrow Agent. The parties to this Agreement acknowledge that such security procedure is commercially reasonable.
 
It is understood that the Escrow Agent and the beneficiary’s bank in any funds transfer may rely upon any account numbers or similar identifying numbers provided by either of the other parties hereto (provided that the Escrow Agent has acted only in accordance with such account numbers or similar identifying numbers without error or omission) to identify (i) the beneficiary, (ii) the beneficiary’s bank, or (iii) an intermediary bank. The Escrow Agent may apply any of the escrowed funds for any payment order it executes using any such identifying number,
 

 
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even where its use may result in a person other than the beneficiary being paid, or the transfer of funds to a bank other than the beneficiary’s bank or an intermediary bank, designated.
 
 (d)  This Agreement shall terminate upon the disbursement, in accordance with Sections 5 or 7(j) hereof, of the Escrow Funds in full; provided, however, that in the event all fees, expenses, costs and other amounts required to be paid to Escrow Agent hereunder are not fully and finally paid prior to termination, the provisions of Section 7(l) and 7(d) hereof shall survive the termination.
 
(e)  This Agreement shall not be assigned by any party hereto without the prior written consent of the other parties hereto, which consent shall not be unreasonably withheld, delayed, or conditioned.

 
13.  Severability. If any provision of this Agreement or the application of any such provision to any person or circumstance shall be held invalid, illegal or unenforceable in any respect by a court of competent jurisdiction, such invalidity, illegality or unenforceability shall not affect any other provision hereof.
 

 
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IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be executed as of the date first above written.
 
Tax Certification: Taxpayer ID#:                     
 
NOTE: The following certification shall be used by and for a U.S. resident only. Non-residents must use and provide Form W8-BEN
 
Customer is a (check one):
 
___ Corporation           ___ Municipality    ___ Partnership      ___ Non-profit or Charitable Org
___ Individual        ___ REMIC          ___ Trust       ___ Other _________________
 
Under the penalties of perjury, the undersigned certifies that:
 
(1)   the entity is organized under the laws of the United States;
 
(2)   the number shown above is its correct Taxpayer Identification Number (or it is waiting for a number to be issued to it); and
 
(3)   it is not subject to backup withholding because: (a) it is exempt from backup withholding or (b) it has not been notified by the Internal Revenue Service (IRS) that it is subject to backup withholding as a result of failure to report all interest or dividends, or (c) the IRS has notified it that it is no longer subject to backup withholding.
 
(If the entity is subject to backup withholding, cross out the words after the (3) above.)[ascertain]
 
Investors who do not supply a tax identification number will be subject to backup withholding in accordance with IRS regulations.
 
Note: The IRS does not require your consent to any provision of this document other than the certifications required to avoid backup withholding.
 

 
      ILLINOVA CORPORATION

 
      By ___/s/ R. Blake Young__________________    
      Name:      R. Blake Young
      Title:        Executive Vice President-Administration
              and Technology

 

 
 
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Certification: Taxpayer ID#:                     
NOTE: The following certification shall be used by and for a U.S. resident only. Non-residents must use and provide Form W8-BEN
 
Customer is a (check one):
 
___ Corporation          ___ Municipality   ___ Partnership    ___ Non-profit or Charitable Org
___ Individual             ___ REMIC      ___ Trust           ___ Other _________________
 
Under the penalties of perjury, the undersigned certifies that:
 
(4)   the entity is organized under the laws of the United States;
 
(5)   the number shown above is its correct Taxpayer Identification Number (or it is waiting for a number to be issued to it); and
 
(6)   it is not subject to backup withholding because: (a) it is exempt from backup withholding or (b) it has not been notified by the Internal Revenue Service (IRS) that it is subject to backup withholding as a result of failure to report all interest or dividends, or (c) the IRS has notified it that it is no longer subject to backup withholding.
 
(If the entity is subject to backup withholding, cross out the words after the (3) above.)
 
Investors who do not supply a tax identification number will be subject to backup withholding in accordance with IRS regulations.
 
Conforming comments
 
Note: The IRS does not require your consent to any provision of this document other than the certifications required to avoid backup withholding.
 

 
       AMEREN CORPORATION


       By      /s/Steven R. Sullivan___________
       Name:    Steven R. Sullivan
       Title:       Senior Vice President
         Regulatory Policy, General Counsel
              and Secretary

       JPMORGAN CHASE BANK

       By___/s/ MayNg____________________
       Name:     May Ng
       Title:       Vice President
                                  Trust Officer



 
 
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Schedule I
 
 
Fee Schedule
 
 
(See attached)
 

 
 
-12-

 

 

 

[Missing Graphic Reference]
 
Schedule of Fees
for
Escrow Agent Services




 New Account Acceptance Fee . . . . . . . . . . . . . . . . . . . $ 750
  Payable upon Account Opening                               &n bsp; 
 
 Minimum Administrative Fee . . . . . . . . . . . . . . . . . . . .$ 4,000
  Payable Upon Account Opening and in Advance
  each year in which we act as Escrow Agent

ACTIVITY FEES:

Disbursements

Per Check
$
  35
Per Wire U.S.
$
  35
International
$
100
     
Receipts
   
     
Per Deposit
$
  10


Investments
   
Per directed buy/sell 
$
 75

  
 
  
The Investments fee will be waived if JPMorgan's Money Market Account sweep product offered byJPMorgan's Escrow Group is the selected investment.


LEGAL EXPENSES:  At Cost
There will be no legal expense for JPMorgan Chase if our standard form escrow agreement is employed without substantive amendments.

 
 
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A New Account Acceptance Fee will be charged for the Bank's review of the Escrow Agreement along with any related account documentation. A one (1) year Minimum Administrative Fee will be assessed for any account that is funded. The account will be invoiced in the month in which the account is opened and annually thereafter. Payment of the invoice is due 30 days following receipt.

The Administrative Fee will cover the Bank's standard escrow services including account setup, safekeeping of assets, investment of funds, collection of income and other receipts, preparation of statements comprising account activity and asset listing, and distribution of assets in accordance with the specific terms of the Escrow Agreement.

Extraordinary Services and Out-of Pocket Expenses:

Any services not specifically anticipated within the escrow agreement, and all reasonable out-of-pocket expenses including attorney's fees will be considered extraordinary services for which related costs, transaction charges, and additional fees will be billed at the Bank's standard rate.

Modification of Fees:

Circumstances may arise necessitating a change in the foregoing fee schedule. The Bank will attempt at all times, however, to maintain the fees at a level that is fair and reasonable in relation to the responsibilities assumed and the duties performed.

Disclosure & Assumptions:

·   The escrow deposit shall be continuously invested in a JPMorgan Money Market Account. The Minimum Administrative Fee would include a supplemental charge up to 10 basis points on the escrow deposit amount if another investment option were chosen.
·   The account will be invoiced in the month in which the account is opened and annually thereafter.
·   Payment of the invoice is due 30 days following receipt.
·   To help the government fight the funding of terrorism and money laundering activities, Federal law requires all financial institutions to obtain, verify, and record information that identifies each person who opens an account. When you open an account, we will ask for information that will allow us to identify you.
 

 

 
 
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Schedule II
 

Telephone Number(s) for Call-backs and Person(s)
Designated to Confirm Funds Transfer Instructions


If to Illinova:    
 
Name                   Telephone Number
 
1. Monica Herring
(713) 767 0402
2. Kyle Kettler
(713) 767 4764
3. Amin Maredia
(713) 767 1042
4. Chuck Cook
(713) 767 8649
5. Holli Nichols
(713) 767 8477
   
If to Ameren:
 
   
Name
Telephone Number
   
1. Warner Baxter
(314) 554 6302
2. Jerre Birdsong
(314) 554 2502
3. Lee Nickloy
(314) 554 4140
4. Don Hollingsworth
(314) 554 2838

 
Telephone call-backs shall be made to either Illinova or Ameren if joint instructions are required pursuant to the Agreement.
EX-10.2 6 ex10_2.htm EXHIBIT 10.2 POWER SUPPLY AGREEMENT Exhibit 10.2 Power Supply Agreement
                                                       &n bsp;                    Exhibit 10.2
 
ELECTRIC POWER SUPPLY AGREEMENT
 
Between Ameren Energy Marketing Company
 
And
 
Central Illinois Public Service Company


THIS ELECTRIC POWER SUPPLY AGREEMENT (hereinafter “EPSA”) made as of this 1st day of December, 1999, as amended this 30th day of March, 2001, and also as amended this 5th day of November, 2004, by and between A MEREN ENERGY MARKETING COMPANY, (hereinafter “Company”) and CENTRAL ILLINOIS PUBLIC SERVICE COMPANY, d.b.a. AmerenCIPS (hereinafter "Customer") (Company and Customer may be identified collectively as “Parties” or individually as a “Party”) is for the supply by Company of all electric p ower and energy, including ancillary services, needed to meet the Customer’s full requirements for electric power and energy.

WHEREAS, Company is engaged in the business of purchasing and reselling electric power and energy; and

WHEREAS, Customer, which is an electric public utility in Illinois, has restructured its operations in response to and in accordance with the Illinois Electric Service Customer Choice and Rate Relief Law of 1997 (the “Customer Choice Law”) by transferring all of its existing generating facilities to a newly-formed generation-company affiliate (“Ameren Energy Generating Company” or “Genco”); and

WHEREAS, Company has entered into an agreement to purchase from Genco all of the capacity and energy available from the generating units that were transferred by Customer to Genco and any additional generating units that may be acquired by Genco in the future; and

WHEREAS, Customer is required by the Customer Choice Law to continue to offer bundled retail electric service within its existing retail electric service area in Illinois at rates specified by the Illinois Commerce Commission (“ICC”) through December 31, 2006; and

WHEREAS, Customer may continue to make bundled sales of electricity to existing wholesale electric service customers; and

WHEREAS, Customer is also obligated by the Customer Choice Law to offer retail electric service to customers in Illinois under unbundled, market-priced tariffs on file with the ICC and may also sell power to others at market-based rates (“Market Price Sales”) through December 31, 2006; and

  
     

 

WHEREAS, a portion of the capacity and energy supplied by Company to Customer shall be provided in the form of certain ancillary services to fulfill Customer’s generation-based ancillary service requirements in support of its bundled sales and resales to Customer’s transmission customers under the Ameren Open Access Transmission, or any successor tariff thereof (“Ameren OATT”); and

WHEREAS, Customer desires to acquire from Company all the electric power and energy that is needed to enable it to provide electric service after the transfer of its generating units; and

WHEREAS, Company is capable of supplying all such power and energy to Customer and desires to do so pursuant to the rates, terms and conditions set forth herein;

NOW THEREFORE, in consideration for the agreements and undertakings established herein and the mutual benefits derived therefrom, it is agreed as follows:

1.    GENERATION SERVICES

  A. Firm Electric Power And Energy Services

Company will supply and deliver to Customer all of the firm electric capacity and energy (hereinafter “Energy”) needed by Customer to serve its native load, to operate its transmission and distribution system and to provide transmission and distribution services, to fulfill its obligations under all applicable federal and state tariffs or contracts, to satisfy regional reliability requirements, and for any other purpose related to the provision of wholesale or retail electric service and Customer shall purchase and pay for such Energy in accordance with the terms of this Agreement.

  B. Ancillary Services

Consistent with subsection 1.A above, a portion of the capacity and energy made available to Customer under this EPSA shall be in the form of certain generation-based ancillary services as needed by Customer to serve its native load, to operate its transmission and distribution system and to provide transmission and distribution services, to fulfill its obligations under all applicable federal and state tariffs or contracts, and to satisfy regional reliability requirements. Such ancillary services shall include Reactive Supply and Voltage Control from Generation Sources Service, Regulation and Frequency Response Service, Energy Imbalance Service and Retail Energy Imbalance Service, Operating Reserve - Spinning Reserve Service, Operating Reserve - Supplemental Reserve Service, and Loss Compensation Service, and s hall be delivered in accordance with the same terms and conditions as required for delivery of such services under the Ameren OATT. Customer shall purchase and pay for such ancillary services in accordance with the terms of this Agreement.


  
     


2.    TERM

Subject to acceptance of this EPSA by the Federal Energy Regulatory Commission (“FERC”), supply and delivery of Energy pursuant to the EPSA shall begin on the Transfer Date established in the “Asset Transfer Agreement” dated May 1, 2000 between Customer and Genco and terminate at 12:00 P.M. CPT on December 31, 2006.

3.    DELIVERY POINTS

All Energy supplied under this EPSA that is provided by generation sources acquired by Genco from Customer shall be deemed to be delivered at the bus bar connecting each such generation source to the Customer’s transmission system. All Energy supplied under this EPSA that is provided by other generation sources shall be deemed to be delivered at the point of interconnection between Customer’s transmission system and the transmission system over which the Energy is being delivered. Energy supplied under this EPSA shall be sixty (60) hertz, three (3) phase alternating current.

4.    TRANSMISSION

Transmission of Energy to Customer shall be firm transmission as such is defined in the transmission provider’s Open Access Transmission Tariff. Company shall be responsible for making all necessary transmission arrangements for transmission of Energy to the Points of Delivery identified above from sources not directly interconnected to the Ameren transmission system, and for any communication with any transmission provider relating to the transmission and delivery of Energy to Customer, including communications concerning scheduling, tagging, displacements, disputes, or other operational issues. Customer shall cooperate with Company for the purpose of attaining the necessary firm transmission service and for implementing the transmission service required for supplying the Energy to the Points of Delivery.

5.    METERING

The Parties recognize that certain meters used to measure the amount of Energy received by Customer are owned by Customer. In order that the accuracy of registration is maintained in accordance with good utility practice, metering equipment shall be tested by Customer at suitable intervals. At the request of Company, special tests shall be performed, but if less than two percent inaccuracy is found, Company shall pay for the test. The expense of all other tests shall be borne by Customer.

Representatives of each Party may be present at all routine or special tests or whenever any readings for the purposes of settlements are taken from meters not having an automatic record. If any test of metering equipment discloses an inaccuracy exceeding two percent, the accounts of the Parties shall be adjusted for the period, not exceeding 90 days, that such inaccuracy is estimated to have existed. Should any metering equipment fail to register, the amounts of Energy delivered and demands established shall be estimated from the best available data. Meters shall be adjusted as nearly as practicable to 100.0% at the time of any meter tests, and Customer shall furnish a copy of any meter test results when requested by Company.


 
     

 

6.    SYSTEM PLANNING 

In order for Company to plan adequately for Customer’s Energy requirements, Customer shall notify Company no later than November 1 of each year of its annual load plan for the next calendar year during the Term. Such annual load plan shall be consistent with the forecasted peak demand reported to the Mid-American Interconnected Network (“MAIN”) for such year. Customer shall also provide to Company an update to its annual load plan on or before March 1 of each year during the Term.

7.    RECORDS

Customer shall provide Company with all records that may reasonably be requested by Company for the purpose of administering this EPSA. The Parties shall keep such records as may be needed to afford a clear history of all transactions under this Agreement. The originals of all such records shall be retained by each party for a minimum of three years and copies shall be delivered to the other Party upon request.

8.    PRICES

  A. Charges For Energy Supplied To Customer (For Sales Other Than Market Price Sales And Other Than For Sales of Ancillary Services under the Ameren OATT)

  1. Capacity Charges

Each calendar year, Company will be entitled to be compensated at a rate of $69,708/MW/Yr. for the quantity (“Quantity”) of capacity supplied, which shall be equal to the greater of: (1) Customer’s forecasted peak demand reported to MAIN for that year, or (2) Customer’s actual annual peak demand (“Peak Demand”); minus the portion of the forecasted or actual peak demand, as applicable, represented by Market Price Sales and by sales of ancillary services pursuant to the Ameren OATT. For the purpose of this provision, Customer’s forecasted peak demand and actual annual peak demand shall be adjusted for losses to the extent necessary to be determined at the Points of Delivery.

Customer shall pay Company monthly for one-twelfth of the applicable annual capacity charges for each calendar year during the Term (or a pro rata share of such annual capacity charges during the year ending December 31, 2000) based on Customer’s forecasted peak demand for such year as reported to MAIN. Within 10 days after the close of each calendar year, Company shall calculate the Customer’s capacity charges on the basis of Customer’s actual annual peak demand. In the event that Customer’s actual annual peak demand for such year exceeded its forecasted peak demand that had been reported to MAIN for such year, Customer shall pay Company for any additional capacity charges that are due with respect to such year at the time of payment of its next monthly bill.


  
     

 

  2. Energy Charges

In addition to the capacity charges specified above, Customer shall pay Company an energy charge of $21.81/Mwh for all energy supplied by Company to the Points of Delivery for sale other than as Market Price Sales and other than for sales of ancillary services pursuant to the Ameren OATT. 
 
B.    Charges For Energy Supplied To Customer For Market Price Sales
 
In addition to the charges for Energy supplied to Customer as set forth above, Customer shall pay Company an amount equal to the amount Customer receives from retail customers for power and energy sold as Market Price Sales. Within 15 days following the close of each calendar month, Customer shall advise Company of the estimated amount of power and energy sold as Market Price Sales for such month and the average rate per Mwh at which such power and energy was sold. Payments for all Energy supplied to Customer for Market Price Sales shall be remitted by Customer to Company in the month following the month in which Customer receives payment for such Energy. Within 45 days following the close of each calendar month, Customer shall advise Company of the actual amounts of Market Price Sales for such month, and the su bsequent payments from Customer to Company shall be adjusted accordingly.

  C. Charges For Ancillary Services for Ameren OATT Transactions

Customer shall pay Company all amounts received by Customer for ancillary services provided hereunder and resold by Customer pursuant to the Ameren OATT. Within 15 days following the close of each calendar month, Customer shall advise Company of the estimated amount of such ancillary services resold by Customer and the amount of total charges Customer received from such resale. Payment of the total amount received by Customer shall be remitted to Company in the month following the month in which Customer receives payment for such ancillary services provided hereunder and resold by Customer.

9.    REGULATION

The parties recognize that this EPSA is subject to regulation by the FERC pursuant to Part II of the Federal Power Act. If the FERC should require the modification of this EPSA prior to its acceptance, the parties shall, in good faith, attempt to reach agreement on modifications that would be acceptable to the FERC in a manner that retains the economic benefits intended to be derived by each party under this EPSA.

10.    ACCESS

Customer shall provide, at no cost to Company, a suitable place (including means of support) on and access to Customer’s property for Company to install, maintain, operate, repair, replace, and remove all equipment and facilities necessary for Company to perform its obligations under this EPSA. Customer shall use reasonable diligence to protect all of Company’s equipment located on Customer’s property.


 
     

 

11.    PAYMENT OF BILLS

A.   BILLING FOR SERVICE: Bills for Energy supplied to Customer for sales other than Market Price Sales will be based upon the Quantity of capacity and amount of energy supplied by Company at the Points of Delivery. Bills and payment for ancillary services shall be rendered consistent with Section 8C of the EPSA. Within 15 days after the close of each calendar month, the Company will issue the bill to Customer electronically (commonly referred to as “EDI”), or other suitable means. If the Company is unable to obtain meter information, or if final Market Price Sales data or ancillary services data is unavailable, an estimated bill will be issued, computed on the basis of Customer’s previous use together with such other information as is available. Once all billing information is considered final, the estima ted bill will be adjusted and any payment due difference will be reflected on the next scheduled billing.

B.   PAYMENT PERIODS: The last date for payment of the “net amount” shown on the bill for Energy supplied to Customer for sales other than Market Price Sales and for ancillary services shall be seven days after the date the bill is issued (hereinafter “Net Payment Period”). Payment of all amounts for all Energy supplied to Customer for Market Price Sales and sales of ancillary services shall be due on the same date. In the event of a disputed bill Customer shall pay the undisputed portion within the Net Payment Period. When the last day of any Net Payment Period falls on a day other than a business day of Company, such period will be automatically extended to include the next following business day. Other than a business day of Company shall include Saturdays, Sundays, and the following holidays: New Year’s day, Lincoln’s Birthday, Washington’s Birthday, Martin Luther King’s Birthday, Good Friday, Memorial Day, Independence Day, Labor Day, Columbus Day, Veteran’s Day, Thanksgiving day, Friday following Thanksgiving day, Christmas Eve (the last day of regular work schedule prior to Christmas day), Christmas day and New Year’s Eve (the last day of regular work schedule prior to New Year’s day). Whenever a holiday falls on Sunday the following Monday will not be considered a business day. Whenever a holiday falls on a Saturday, the prior Friday will not be considered a business day.

C.   PAYMENT AND LATE PAYMENTS: Customer shall make payment to Company by wire transfer, or other acceptable means, within the Net Payment Period in immediately available U.S. funds. When a bill is paid after the last date for payment in the “net amount” shown on the bill a late payment charge equivalent to one and one half (1 1/2) percent will be assessed each month on the unpaid balance.

12.    INDEMNIFICATION

Customer shall indemnify and save harmless and defend Company from and against any and all claims, demands, damages, costs or expenses arising, growing out of or resulting in any manner after delivery of Energy to Customer or from improper or negligent construction, installation, insulation, maintenance or operation of Customer’s lines and appurtenances.


  
     

 

13.    FORCE MAJEURE

In the event of Force Majeure, Company shall notify Customer immediately by oral communication, confirmed in writing, of such occurrence, reporting the commencement time and date, estimated duration, and estimated magnitude of the reduction in Energy deliveries resulting from the Force Majeure situation. Company shall not be liable for the failure to deliver the full amount or any part of the Energy to be supplied pursuant to this EPSA for the duration of the Force Majeure. For the purpose of this provision, “Force Majeure” means an event or circumstances which prevents Company from performing its obligations under this EPSA, which is not within the reasonable control of the Company, and which, by exercise of due diligence, the Company is unable to overcome or avoid or cause to be avoided. Force Majeur e includes, but is not restricted to, fires, strikes, labor stoppages, epidemics, floods, earthquakes, lightening storms, ice, acts of God, riots, civil disturbances, civil war, invasion, insurrection, military or usurped power, war, sabotage, explosions, failure of equipment or of contractors or suppliers of materials or fuel, inability to obtain or ship material, fuel or equipment because of the effect of similar causes on suppliers or carriers, or an action or restraint by court order or public or governmental authority (so long as the Company has not applied for or assisted in the application for such court or governmental action). Force Majeure shall not include Company’s ability to sell Energy to another purchaser at a more advantageous price than that contained in this EPSA. The settlement of strikes, walkouts, lockouts, and other labor disputes shall be entirely within the discretion of the Company, and Company may make settlement at such time and on such terms and conditions as it may deem to b e advisable. Interruption by a transmission provider shall not be deemed to be an event of Force Majeure unless (i) Company shall have made arrangements with such transmission provider for the firm transmission, as defined under the transmission provider’s Open Access Transmission Tariff, of the Energy and (ii) such interruption is due to “force majeure” or “uncontrollable force” or a similar term as defined under the transmission provider’s Open Access Transmission Tariff, and (iii) no other path is available and no other remedy is available.

14.    ASSIGNMENT

This EPSA shall inure to the benefit of, and be binding upon, the respective successors and assigns of Customer and Company. No assignment of this EPSA shall be made by a Party except to a wholly owned subsidiary or successor to substantially all of that Party’s business who assumes possession and operates substantially the same facilities and business as the assignor. Notwithstanding the foregoing, either Party shall be free to assign this EPSA to any of its subsidiaries or affiliates, without the written consent of the other Party. The assignment by a Party shall not relieve the Party, without the written consent of the other Party, of any obligation to provide, or to accept and pay for, as the case may be, the services contracted for hereunder. 

15.     NOTICES

All notices to be given under this EPSA shall be in writing via First Class U.S. mail, FAX or e-mail and shall be deemed given when sent. Notices shall be addressed as set forth below, or to such other address as the party to be notified may designate from time to time.


 
     

 

Notice to Company:        

Andrew M. Serri
Vice President of Sales and Marketing
Ameren Energy Marketing Company
One Ameren Plaza
1901 Chouteau Avenue
St. Louis, MO 63103

Notice to Customer:        

Craig D. Nelson
Vice President
Central Illinois Public Service Company
One Ameren Plaza
1901 Chouteau Avenue
St. Louis, MO 63103

16.    WRITTEN MODIFICATION

The rates for service specified herein shall remain in effect for all Energy supplied by Company through December 31, 2006, and shall not be subject to change through application to the FERC pursuant to the provisions of Section 205 of the Federal Power Act prior to that time absent the agreement of the Parties. This EPSA shall not be modified except in writing by amendment, executed by both parties, making express reference to the EPSA and the specific provisions hereof modified or amended.

17.    LIMITS OF LIABILITY

IN THE EVENT OF LITIGATION UNDER THIS EPSA, THE PREVAILING PARTY SHALL BE ENTITLED TO COMPENSATION FOR ANY REASONABLE ATTORNEYS FEES AND OTHER COSTS THAT MAY BE INCURRED. UNLESS EXPRESSLY HEREIN PROVIDED, NEITHER PARTY SHALL BE LIABLE FOR ANY CONSEQUENTIAL, INCIDENTAL, PUNITIVE, EXEMPLARY OR INDIRECT DAMAGES, LOST PROFITS OR OTHER BUSINESS INTERRUPTION DAMAGES, BY STATUTE, IN TORT OR CONTRACT, UNDER ANY INDEMNITY PROVISION OR OTHERWISE. IT IS THE INTENT OF THE PARTIES THAT THE LIMITATIONS HEREIN IMPOSED ON REMEDIES AND THE MEASURE OF DAMAGES BE WITHOUT REGARD TO THE CAUSE OR CAUSES RELATED THERETO, INCLUDING THE NEGLIGENCE OF ANY PARTY, WHETHER SUCH NEGLIGENCE BE SOLE, JOINT OR CONCURRENT, OR ACTIVE OR PASSIVE.

18.     DUTY TO MITIGATE

Each Party agrees that it has a duty to mitigate damages and covenants that it will use commercially reasonable efforts to minimize any damages it may incur as a result of the other Party’s performance or non-performance of this EPSA.


 
     

 

19.    WAIVERS

Any waiver at any time by either Company or Customer of its rights with respect to a default under this EPSA or with respect to any other matter arising in connection with this EPSA shall not be deemed a waiver with respect to any subsequent default or matter. Any delay, short of the statutory period of limitation, in asserting or enforcing any right under this EPSA shall not be deemed a waiver of such right.

20.    ENTIRE AGREEMENT

This EPSA contains the entire agreement between the Parties in respect to the subject matter contained herein, and there are no other understandings or agreements between Company and Customer in respect thereof.

21.    WARRANTIES

The warranties expressly set forth in this EPSA are the sole warranties given by either Party to the other Party in connection with the sale and purchase of Energy hereunder. EXCEPT AS SET FORTH HEREIN, COMPANY EXPRESSLY NEGATES ANY OTHER REPRESENTATION OR WARRANTY, WRITTEN OR ORAL, EXPRESSED OR IMPLIED, INCLUDING, WITHOUT LIMITATION, ANY REPRESENTATION OR WARRANTY WITH RESPECT TO CONFORMITY TO MODELS OR EXAMPLES, OR MERCHANTABILITY OR FITNESS FOR ANY PARTICULAR PURPOSE.

22.    LIMITATION

This EPSA is not intended to and shall not create rights of any character whatsoever in favor of any person, corporation, association, or entity other than the parties to this EPSA, and the obligations herein assumed are solely for the use and benefit of the parties to this EPSA, their successors in interest, or assigns.

23.    SURVIVORSHIP OF OBLIGATIONS

The termination of this EPSA shall not discharge any Party from any obligation it owed to the other Party under the EPSA by reason of any transaction, loss, cost, damage, expense or liability which shall occur or arise prior to such termination. It is the intent of the Parties that any such obligation owed (whether the same shall be known or unknown as of the termination of this EPSA) shall survive the termination of this EPSA. The Parties also intend that the indemnification and limitation of liability provisions contained in this EPSA shall remain operative and in full force and effect, regardless of any termination of this EPSA, except with respect to actions or events occurring or arising after such termination is effective.


  
     

 

24.    GOVERNING LAW

The interpretation and performance of this EPSA shall be in accordance with and controlled by the laws of the State of Illinois (including any applicable orders and regulations issued by the ICC), except as to matters governed by federal statute.

25.    SAVING CLAUSE

The provisions of this EPSA shall be interpreted where possible in a manner to sustain their legality and enforcement. If at any time a provision of this EPSA is found to be unenforceable, such provision shall be removed and the rest of this EPSA shall remain intact and in effect as if the removed provision was never contained therein.
 
26.    RESOLUTION OF DISPUTES 

If a question or controversy arises between the Parties concerning the observance or performance of any of the terms, provisions or conditions contained herein or the rights or obligations of either Party under this EPSA, such question or controversy shall in the first instance be the subject of a meeting between the Parties to negotiate a resolution of such dispute. Such meeting shall be held within fifteen (15) days of a request by either Party. If within fifteen (15) days after that meeting, the Parties have not negotiated a resolution or mutually extended the period of negotiation, either Party may seek resolution of the question or controversy by arbitration, subject, however, to any prohibition thereto by any governmental law or regulation.

The Party calling for arbitration (“Initiating Party”) shall give written notice to the other Party setting forth (a) a short and plain statement of the issue(s) to be arbitrated; (b) a short and plain statement of the claim showing that the Initiating Party is entitled to relief; and (c) a statement of the relief to which the Initiating Party claims to be entitled. Such written notice including sections (a), (b) and (c) defined above shall not exceed a document length of 20 pages, double spaced utilizing a font of 12. Within twenty (20) days from the date of receipt of such notice, the other Party (“Receiving Party”) may submit its written response and give notice in the same manner required above of additional issues to be arbitrated. The Initiating Party shall have twenty (20) days to respond to any issues submitted for arbitration by the Receiving Party.

Within thirty (30) days of the date of the Initiating Party’s written notice requesting arbitration, each party shall designate a competent and disinterested person to act as that party’s designated arbitrator, with the two (2) persons designated selecting a third neutral arbitrator within twenty (20) days of their designation. In the event the first two- (2) arbitrators cannot agree on a mutually acceptable third arbitrator, they shall apply to the American Arbitration Association (“AAA”) to appoint the third arbitrator. The arbitration shall be conducted pursuant to the Federal Rules of Civil Procedure, the Federal Rules of Evidence, and the Commercial Arbitration Rules of the AAA.


  
     

 

Any decision and award of the majority of arbitrators shall be binding upon both parties. The arbitrators shall not award any indirect, special, incidental or consequential damages against either party. Judgment upon the award rendered may be entered in any court of competent jurisdiction.

27.   HEADINGS

The descriptive headings of the sections of this EPSA have been inserted for convenience of reference only and shall not modify or restrict any of the terms and provisions thereof.

IN WITNESS WHEREOF, the Parties hereto have caused this EPSA to be executed in duplicate, by its authorized officers, day and year first above written.

AMEREN ENERGY MARKETING
COMPANY
 
CENTRAL ILLINOIS PUBLIC
   SERVICE COMPANY
 
 
By
/s/ Andrew M. Serri                                       
By
/s/ Craig D. Nelson                                
  (Company Officer Signature)
 
 
(Customer Officer Signature)
 
Andrew M. Serri                                             
 
Craig D. Nelson                                     
            (Printed Name)
 
 
(Printed Name)
 
 
Vice President of Sales and Marketing            
 
Vice President                                           
            (Title)
 
(Title)


 







EX-31.1 7 ex31_1.htm EXHIBIT 31.1 CERTIFICATION OF PEO OF AMEREN Exhibit 31.1 Certification of PEO of Ameren
Exhibit 31.1


RULE 13a-14(a)/15d-14(a) CERTIFICATION
OF PRINCIPAL EXECUTIVE OFFICER OF AMEREN CORPORATION
(required by Section 302 of the Sarbanes-Oxley Act of 2002)


 I, Gary L. Rainwater, certify that:

 1.   I have reviewed this report on Form 10-Q for the quarterly period ended September 30, 2004 of Ameren Corporation;

 2.   Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circum-stances under which such statements were made, not misleading with respect to the period covered by this report;

 3.   Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 4.   The registrant’s other certifying officer and I are responsible for establishing and main-taining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

  b) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

  c) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 5.   The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


 
Date: November 9, 2004
 
 

  /s/ Gary L. Rainwater    
 Gary L. Rainwater
 Chairman, President and
 Chief Executive Officer
 (Principal Executive Officer)
EX-31.2 8 ex31_2.htm EXHIBIT 31.2 CERTIFICATION OF PFO OF AMEREN Exhibit 31.2 Certification of PFO of Ameren

Exhibit 31.2


RULE 13a-14(a)/15d-14(a) CERTIFICATION
OF PRINCIPAL FINANCIAL OFFICER OF AMEREN CORPORATION
(required by Section 302 of the Sarbanes-Oxley Act of 2002)


 I, Warner L. Baxter, certify that:

 1.   I have reviewed this report on Form 10-Q for the quarterly period ended September 30, 2004 of Ameren Corporation;

 2.   Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circum-stances under which such statements were made, not misleading with respect to the period covered by this report;

 3.   Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 4.   The registrant’s other certifying officer and I are responsible for establishing and main-taining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

  a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

    b) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

c)   Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 5.   The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

  a) All significant deficiencies and material weaknesses in the design or operation of internal control which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

  b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


 
Date: November  9, 2004
 
 

  /s/ Warner L. Baxter    
 Warner L. Baxter
 Executive Vice President and
 Chief Financial Officer
 (Principal Financial Officer)



EX-31.3 9 ex31_3.htm EXHIBIT 31.3 CERTIFICATION OF PEO OF UE Exhibit 31.3 Certification of PEO of UE

Exhibit 31.3


RULE 13a-14(a)/15d-14(a) CERTIFICATION
OF PRINCIPAL EXECUTIVE OFFICER OF UNION ELECTRIC COMPANY
(required by Section 302 of the Sarbanes-Oxley Act of 2002)


 I, Gary L. Rainwater, certify that:

 1.  I have reviewed this report on Form 10-Q for the quarterly period ended September 30, 2004 of Union Electric Company;

 2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circum-stances under which such statements were made, not misleading with respect to the period covered by this report;

 3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 4.  The registrant’s other certifying officer and I are responsible for establishing and main-taining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

  a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)   Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

c)   Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 5.  The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

    a) All significant deficiencies and material weaknesses in the design or operation of internal control which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

    b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


 
Date: November 9, 2004
 
 

  /s/ Gary L. Rainwater    
 Gary L. Rainwater
 Chairman, President and
 Chief Executive Officer
 (Principal Executive Officer)



EX-31.4 10 ex31_4.htm EXHIBIT 31.4 CERTIFICATION OF PFO OF UE Exhibit 31.4 Certification of PFO of UE

Exhibit 31.4


RULE 13a-14(a)/15d-14(a) CERTIFICATION
OF PRINCIPAL FINANCIAL OFFICER OF UNION ELECTRIC COMPANY
(required by Section 302 of the Sarbanes-Oxley Act of 2002)


 I, Warner L. Baxter, certify that:

 1.  I have reviewed this report on Form 10-Q for the quarterly period ended September 30, 2004 of Union Electric Company;

 2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circum-stances under which such statements were made, not misleading with respect to the period covered by this report;

 3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 4.  The registrant’s other certifying officer and I are responsible for establishing and main-taining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

  b) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

  c) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 5.   The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


 
Date: November 9, 2004
 
 

  /s/ Warner L. Baxter    
 Warner L. Baxter
 Executive Vice President and
 Chief Financial Officer
 (Principal Financial Officer)



EX-31.5 11 ex31_5.htm EXHIBIT 31.5 CERTIFICATION OF PEO OF CIPS Exhibit 31.5 Certification of PEO of CIPS

Exhibit 31.5

RULE 13a-14(a)/15d-14(a) CERTIFICATION
OF PRINCIPAL EXECUTIVE OFFICER OF
CENTRAL ILLINOIS PUBLIC SERVICE COMPANY
(required by Section 302 of the Sarbanes-Oxley Act of 2002)


 I, Gary L. Rainwater, certify that:

 1.  I have reviewed this report on Form 10-Q for the quarterly period ended September 30, 2004 of Central Illinois Public Service Company;

 2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circum-stances under which such statements were made, not misleading with respect to the period covered by this report;

 3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 4.  The registrant’s other certifying officer and I are responsible for establishing and main-taining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

  a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)   Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

c)   Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 5.  The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

    a) All significant deficiencies and material weaknesses in the design or operation of internal control which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

    b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


 
Date: November 9, 2004
 
 

  /s/ Gary L. Rainwater    
 Gary L. Rainwater
 Chairman and Chief Executive Officer
 (Principal Executive Officer)



EX-31.6 12 ex31_6.htm EXHIBIT 31.6 CERTIFICATION OF PFO OF CIPS Exhibit 31.6 Certification of PFO of CIPS

Exhibit 31.6


RULE 13a-14(a)/15d-14(a) CERTIFICATION
OF PRINCIPAL FINANCIAL OFFICER OF
CENTRAL ILLINOIS PUBLIC SERVICE COMPANY
(required by Section 302 of the Sarbanes-Oxley Act of 2002)


 I, Warner L. Baxter, certify that:

 1.  I have reviewed this report on Form 10-Q for the quarterly period ended September 30, 2004 of Central Illinois Public Service Company;

 2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circum-stances under which such statements were made, not misleading with respect to the period covered by this report;

 3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 4.  The registrant’s other certifying officer and I are responsible for establishing and main-taining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

  b) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

  c) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 5.  The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


 
Date: November 9, 2004
 
 

  /s/ Warner L. Baxter    
 Warner L. Baxter
 Executive Vice President and
 Chief Financial Officer
 (Principal Financial Officer)



EX-31.7 13 ex31_7.htm EXHIBIT 31.7 CERTIFICATION OF PEO OF GENCO Exhibit 31.7 Certification of PEO of Genco

Exhibit 31.7


RULE 13a-14(a)/15d-14(a) CERTIFICATION
OF PRINCIPAL EXECUTIVE OFFICER OF
AMEREN ENERGY GENERATING COMPANY
(required by Section 302 of the Sarbanes-Oxley Act of 2002)


 I, R. Alan Kelley, certify that:

 1.  I have reviewed this report on Form 10-Q for the quarterly period ended September 30, 2004 of Ameren Energy Generating Company;

 2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circum-stances under which such statements were made, not misleading with respect to the period covered by this report;

 3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 4.  The registrant’s other certifying officer and I are responsible for establishing and main-taining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

 a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

  b) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

  c) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 5.   The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

 
Date: November 9, 2004
 
 

  /s/ R. Alan Kelley    
 R. Alan Kelley
 President
 (Principal Executive Officer)



EX-31.8 14 ex31_8.htm EXHIBIT 31.8 CERTIFICATION OF PFO OF GENCO Exhibit 31.8 Certification of PFO of Genco

Exhibit 31.8


RULE 13a-14(a)/15d-14(a) CERTIFICATION
OF PRINCIPAL FINANCIAL OFFICER OF
AMEREN ENERGY GENERATING COMPANY
(required by Section 302 of the Sarbanes-Oxley Act of 2002)


 I, Warner L. Baxter, certify that:

 1.  I have reviewed this report on Form 10-Q for the quarterly period ended September 30, 2004 of Ameren Energy Generating Company;

 2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circum-stances under which such statements were made, not misleading with respect to the period covered by this report;

 3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 4.  The registrant’s other certifying officer and I are responsible for establishing and main-taining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

  b) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

  c) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 5.  The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


Date: November 9, 2004
 

  /s/ Warner L. Baxter    
 Warner L. Baxter
 Executive Vice President and
 Chief Financial Officer
 (Principal Financial Officer)
EX-31.9 15 ex31_9.htm EXHIBIT 31.9 CERTIFICATION OF PEO OF CILCORP Exhibit 31.9 Certification of PEO of CILCORP
Exhibit 31.9


RULE 13a-14(a)/15d-14(a) CERTIFICATION
OF PRINCIPAL EXECUTIVE OFFICER OF CILCORP INC.
(required by Section 302 of the Sarbanes-Oxley Act of 2002)


 I, Gary L. Rainwater, certify that:

 1.  I have reviewed this report on Form 10-Q for the quarterly period ended September 30, 2004 of CILCORP Inc.;

 2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circum-stances under which such statements were made, not misleading with respect to the period covered by this report;

 3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 4.  The registrant’s other certifying officer and I are responsible for establishing and main-taining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

  b) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

  c) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 5.  The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

  a) All significant deficiencies and material weaknesses in the design or operation of internal control which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

  b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


 
Date: November 9, 2004
 


  /s/ Gary L. Rainwater    
 Gary L. Rainwater
 Chairman, President and
 Chief Executive Officer
 (Principal Executive Officer)
EX-31.10 16 ex31_10.htm EXHIBIT 31.10 CERTIFICATION OF PFO OF CILCORP Exhibit 31.10 Certification of PFO of CILCORP

Exhibit 31.10


RULE 13a-14(a)/15d-14(a) CERTIFICATION
OF PRINCIPAL FINANCIAL OFFICER OF CILCORP INC.
(required by Section 302 of the Sarbanes-Oxley Act of 2002)


 I, Warner L. Baxter, certify that:

 1.  I have reviewed this report on Form 10-Q for the quarterly period ended September 30, 2004 of CILCORP Inc.;

 2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circum-stances under which such statements were made, not misleading with respect to the period covered by this report;

 3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 4.  The registrant’s other certifying officer and I are responsible for establishing and main-taining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

  b) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

  c) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 5.  The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


 
Date: November 9, 2004
 
 

  /s/ Warner L. Baxter    
 Warner L. Baxter
 Executive Vice President and
 Chief Financial Officer
 (Principal Financial Officer)



EX-31.11 17 ex31_11.htm EXHIBIT 31.11 CERTIFICATION OF PEO OF CILCO Exhibit 31.11 Certification of PEO of CILCO
Exhibit 31.11


RULE 13a-14(a)/15d-14(a) CERTIFICATION
OF PRINCIPAL EXECUTIVE OFFICER OF
CENTRAL ILLINOIS LIGHT COMPANY
(required by Section 302 of the Sarbanes-Oxley Act of 2002)


 I, Gary L. Rainwater, certify that:

 1.  I have reviewed this report on Form 10-Q for the quarterly period ended September 30, 2004 of Central Illinois Light Company;

 2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circum-stances under which such statements were made, not misleading with respect to the period covered by this report;

 3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 4.  The registrant’s other certifying officer and I are responsible for establishing and main-taining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

  b) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

  c) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 5.  The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


 
Date: November 9, 2004
 
 

  /s/ Gary L. Rainwater    
 Gary L. Rainwater
 Chairman and
 Chief Executive Officer
 (Principal Executive Officer)



EX-31.12 18 ex31_12.htm EXHIBIT 31.12 CERTIFICATION OF PFO OF CILCO Exhibit 31.12 Certification of PFO of CILCO

Exhibit 31.12


RULE 13a-14(a)/15d-14(a) CERTIFICATION
OF PRINCIPAL FINANCIAL OFFICER OF
CENTRAL ILLINOIS LIGHT COMPANY
(required by Section 302 of the Sarbanes-Oxley Act of 2002)


 I, Warner L. Baxter, certify that:

 1.  I have reviewed this report on Form 10-Q for the quarterly period ended September 30, 2004 of Central Illinois Light Company;

 2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circum-stances under which such statements were made, not misleading with respect to the period covered by this report;

 3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 4.  The registrant’s other certifying officer and I are responsible for establishing and main-taining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

  b) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

  c) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 5.   The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


 
Date: November 9, 2004
 
 

  /s/ Warner L. Baxter    
 Warner L. Baxter
  Executive Vice President and
  Chief Financial Officer        
  (Principal Financial Officer)

EX-32.1 19 ex32_1.htm EXHIBIT 32.1 CERTIFICATION OF PEO OF AMEREN Exhibit 32.1 Certification of PEO of Ameren

Exhibit 32.1


SECTION 1350 CERTIFICATION
OF PRINCIPAL EXECUTIVE OFFICER
OF AMEREN CORPORATION
(required by Section 906 of the
Sarbanes-Oxley Act of 2002)


In connection with the report on Form 10-Q for the quarterly period ended September 30, 2004 of Ameren Corporation (the “Company”) as filed with the Securities and Exchange Commission on the date hereof (the "Form 10-Q"), I, Gary L. Rainwater, chief executive officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1)   The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2)   The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.


Dated: November 9, 2004



/s/ Gary L. Rainwater        
Gary L. Rainwater
Chairman, President and
Chief Executive Officer
(Principal Executive Officer)




EX-32.2 20 ex32_2.htm EXHIBIT 32.2 CERTIFICATION OF PFO OF AMEREN Exhibit 32.2 Certification of PFO of Ameren

Exhibit 32.2


SECTION 1350 CERTIFICATION
OF PRINCIPAL FINANCIAL OFFICER OF
AMEREN CORPORATION
(required by Section 906 of the
Sarbanes-Oxley Act of 2002)


In connection with the report on Form 10-Q for the quarterly period ended September 30, 2004 of Ameren Corporation (the “Company”) as filed with the Securities and Exchange Commission on the date hereof (the "Form 10-Q"), I, Warner L. Baxter, chief financial officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1)   The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2)   The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.


Dated: November 9, 2004



/s/ Warner L. Baxter        
Warner L. Baxter
Executive Vice President and
Chief Financial Officer
(Principal Financial Officer)





EX-32.3 21 ex32_3.htm EXHIBIT 32.3 CERTIFICATION OF PEO OF UE Exhibit 32.3 Certification of PEO of UE

Exhibit 32.3


SECTION 1350 CERTIFICATION
OF PRINCIPAL EXECUTIVE OFFICER OF
UNION ELECTRIC COMPANY
(required by Section 906 of the
Sarbanes-Oxley Act of 2002)


In connection with the report on Form 10-Q for the quarterly period ended September 30, 2004 of Union Electric Company (the “Company”) as filed with the Securities and Exchange Commission on the date hereof (the "Form 10-Q"), I, Gary L. Rainwater, chief executive officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1)   The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2)   The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.


Dated: November 9, 2004



/s/ Gary L. Rainwater          
Gary L. Rainwater
Chairman, President and
Chief Executive Officer
(Principal Executive Officer)





EX-32.4 22 ex32_4.htm EXHIBIT 32.4 CERTIFICATION OF PFO OF UE Exhibit 32.4 Certification of PFO of UE

Exhibit 32.4


SECTION 1350 CERTIFICATION
OF PRINCIPAL FINANCIAL OFFICER OF
UNION ELECTRIC COMPANY
(required by Section 906 of the
Sarbanes-Oxley Act of 2002)


In connection with the report on Form 10-Q for the quarterly period ended September 30, 2004 of Union Electric Company (the “Company”) as filed with the Securities and Exchange Commission on the date hereof (the "Form 10-Q"), I, Warner L. Baxter, chief financial officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

    (1)

The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

    (2) The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.


Dated: November 9, 2004



  /s/ Warner L. Baxter          
Warner L. Baxter
Executive Vice President and
Chief Financial Officer
(Principal Financial Officer)





EX-32.5 23 ex32_5.htm EXHIBIT 32.5 CERTIFICATION OF PEO OF CIPS Exhibit 32.5 Certification of PEO of CIPS

Exhibit 32.5


SECTION 1350 CERTIFICATION
OF PRINCIPAL EXECUTIVE OFFICER OF
CENTRAL ILLINOIS PUBLIC SERVICE COMPANY
(required by Section 906 of the
Sarbanes-Oxley Act of 2002)


In connection with the report on Form 10-Q for the quarterly period ended September 30, 2004 of Central Illinois Public Service Company (the “Company”) as filed with the Securities and Exchange Commission on the date hereof (the "Form 10-Q"), I, Gary L. Rainwater, chief executive officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that: 

(1)   The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2)   The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.


Dated: November 9, 2004



/s/ Gary L. Rainwater             
Gary L. Rainwater
Chairman and Chief Executive Officer
(Principal Executive Officer)





EX-32.6 24 ex32_6.htm EXHIBIT 32.6 CERTIFICATION OF PFO OF CIPS Exhibit 32.6 Certification of PFO of CIPS

Exhibit 32.6


SECTION 1350 CERTIFICATION
OF PRINCIPAL FINANCIAL OFFICER OF
CENTRAL ILLINOIS PUBLIC SERVICE COMPANY
(required by Section 906 of the
Sarbanes-Oxley Act of 2002)


In connection with the report on Form 10-Q for the quarterly period ended September 30, 2004 of Central Illinois Public Service Company (the “Company”) as filed with the Securities and Exchange Commission on the date hereof (the "Form 10-Q"), I, Warner L. Baxter, chief financial officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1)   The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2)   The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.


Dated: November 9, 2004



 /s/ Warner L. Baxter        
Warner L. Baxter
Executive Vice President and
Chief Financial Officer
(Principal Financial Officer)





EX-32.7 25 ex32_7.htm EXHIBIT 32.7 CERTIFICATION OF PEO OF GENCO Exhibit 32.7 Certification of PEO of Genco

Exhibit 32.7


SECTION 1350 CERTIFICATION
OF PRINCIPAL EXECUTIVE OFFICER OF
AMEREN ENERGY GENERATING COMPANY
(required by Section 906 of the
Sarbanes-Oxley Act of 2002)


In connection with the report on Form 10-Q for the quarterly period ended September 30, 2004 of Ameren Energy Generating Company (the “Company”) as filed with the Securities and Exchange Commission on the date hereof (the "Form 10-Q"), I, R. Alan Kelley, chief executive officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that: 

(1)   The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2)   The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.


Dated: November 9, 2004



/s/ R. Alan Kelley        
R. Alan Kelley
President
(Principal Executive Officer)





EX-32.8 26 ex32_8.htm EXHIBIT 32.8 CERTIFICATION OF PFO OF GENCO Exhibit 32.8 Certification of PFO of Genco

Exhibit 32.8


SECTION 1350 CERTIFICATION
OF PRINCIPAL FINANCIAL OFFICER OF
AMEREN ENERGY GENERATING COMPANY
(required by Section 906 of the
Sarbanes-Oxley Act of 2002)


In connection with the report on Form 10-Q for the quarterly period ended September 30, 2004 of Ameren Energy Generating Company (the “Company”) as filed with the Securities and Exchange Commission on the date hereof (the "Form 10-Q"), I, Warner L. Baxter, chief financial officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1)   The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2)   The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.


Dated: November 9, 2004



/s/ Warner L. Baxter        
Warner L. Baxter
Executive Vice President and
Chief Financial Officer
(Principal Financial Officer)





EX-32.9 27 ex32_9.htm EXHIBIT 32.9 CERTIFICATION OF PEO OF CILCORP Exhibit 32.9 Certification of PEO of CILCORP

Exhibit 32.9


SECTION 1350 CERTIFICATION
OF PRINCIPAL EXECUTIVE OFFICER OF CILCORP INC.
(required by Section 906 of the
Sarbanes-Oxley Act of 2002)


In connection with the report on Form 10-Q for the quarterly period ended September 30, 2004 of CILCORP Inc. (the “Company”) as filed with the Securities and Exchange Commission on the date hereof (the "Form 10-Q"), I, Gary L. Rainwater, chief executive officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1)   The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2)   The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.


Dated: November 9, 2004



/s/ Gary L. Rainwater             
Gary L. Rainwater
Chairman, President and
Chief Executive Officer
(Principal Executive Officer)





EX-32.10 28 ex32_10.htm EXHIBIT 32.10 CERTIFICATION OF PFO OF CILCORP Exhibit 32.10 Certification of PFO of CILCORP

Exhibit 32.10


SECTION 1350 CERTIFICATION
OF PRINCIPAL FINANCIAL OFFICER OF CILCORP INC.
(required by Section 906 of the
Sarbanes-Oxley Act of 2002)


In connection with the report on Form 10-Q for the quarterly period ended September 30, 2004 of CILCORP Inc. (the “Company”) as filed with the Securities and Exchange Commission on the date hereof (the "Form 10-Q"), I, Warner L. Baxter, chief financial officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1)   The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2)   The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.


Dated: November 9, 2004



 /s/ Warner L. Baxter        
Warner L. Baxter
Executive Vice President and
Chief Financial Officer
(Principal Financial Officer)





EX-32.11 29 ex32_11.htm EXHIBIT 32.11 CERTIFICATION OF PEO OF CILCO Exhibit 32.11 Certification of PEO of CILCO

Exhibit 32.11


SECTION 1350 CERTIFICATION
OF PRINCIPAL EXECUTIVE OFFICER OF
CENTRAL ILLINOIS LIGHT COMPANY
(required by Section 906 of the
Sarbanes-Oxley Act of 2002)


In connection with the report on Form 10-Q for the quarterly period ended September 30, 2004 of Central Illinois Light Company (the “Company”) as filed with the Securities and Exchange Commission on the date hereof (the "Form 10-Q"), I, Gary L. Rainwater, chief executive officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that: 

(1)   The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2)   The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.


Dated: November 9, 2004



/s/ Gary L. Rainwater              
Gary L. Rainwater
Chairman and
Chief Executive Officer
(Principal Executive Officer)





EX-32.12 30 ex32_12.htm EXHIBIT 32.12 CERTIFICATION OF PFO OF CILCO Exhibit 32.12 Certification of PFO of CILCO

Exhibit 32.12


SECTION 1350 CERTIFICATION
OF PRINCIPAL FINANCIAL OFFICER OF
CENTRAL ILLINOIS LIGHT COMPANY
(required by Section 906 of the
Sarbanes-Oxley Act of 2002)


In connection with the report on Form 10-Q for the quarterly period ended September 30, 2004 of Central Illinois Light Company (the “Company”) as filed with the Securities and Exchange Commission on the date hereof (the "Form 10-Q"), I, Warner L. Baxter, chief financial officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1)   The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2)   The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.


Dated: November 9, 2004



/s/ Warner L. Baxter        
Warner L. Baxter
Executive Vice President and
Chief Financial Officer
(Principal Financial Officer)





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