Commission
File
Number
|
Exact
name of registrant as specified in its charter;
State
of Incorporation;
Address
and Telephone Number
|
IRS
Employer
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
|
||
(888)
789-2477
|
||
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)
677-5271
|
||
1-2732
|
Central
Illinois Light Company
|
37-0211050
|
(Illinois
Corporation)
|
||
300
Liberty Street
|
||
Peoria,
Illinois 61602
|
||
(309)
677-5271
|
||
1-3004
|
Illinois
Power Company
|
37-0344645
|
(Illinois
Corporation)
|
||
370
South Main Street
|
||
Decatur,
Illinois 62523
|
||
(217)
424-6600
|
Large
Accelerated Filer
|
Accelerated
Filer
|
Non-Accelerated
Filer
|
|
Ameren
Corporation
|
(X)
|
(
)
|
(
)
|
Union
Electric Company
|
(
)
|
(
)
|
(X)
|
Central
Illinois Public Service Company
|
(
)
|
(
)
|
(X)
|
Ameren
Energy Generating Company
|
(
)
|
(
)
|
(X)
|
CILCORP
Inc.
|
(
)
|
(
)
|
(X)
|
Central
Illinois Light Company
|
(
)
|
(
)
|
(X)
|
Illinois
Power Company
|
(
)
|
(
)
|
(X)
|
Ameren
Corporation
|
Yes
|
(
)
|
No
|
(X)
|
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)
|
Illinois
Power Company
|
Yes
|
(
)
|
No
|
(X)
|
Ameren
Corporation
|
Common
stock, $.01 par value per share – 207,601,632
|
Union
Electric Company
|
Common
stock, $5 par value per share, 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
|
Illinois
Power Company
|
Common
stock, no par value, held by Ameren
Corporation
(parent company of the registrant) –
23,000,000
|
Page
|
|
Glossary
of Terms and
Abbreviations .............................................................................................................................................................................................................................................
|
5
|
Forward-looking
Statements...............................................................................................................................................................................................................................................................
|
6
|
PART
I Financial
Information
|
|
Item
1. Financial Statements
(Unaudited)
|
|
Ameren
Corporation
|
|
Consolidated
Statement of
Income.....................................................................................................................................................................................................................
|
8
|
Consolidated
Balance
Sheet................................................................................................................................................................................................................................
|
9
|
Consolidated
Statement of Cash
Flows.............................................................................................................................................................................................................
|
10
|
Union
Electric Company
|
|
Consolidated
Statement of
Income.....................................................................................................................................................................................................................
|
11
|
Consolidated
Balance
Sheet................................................................................................................................................................................................................................
|
12
|
Consolidated
Statement of Cash
Flows.............................................................................................................................................................................................................
|
13
|
Central
Illinois Public Service Company
|
|
Statement
of
Income.............................................................................................................................................................................................................................................
|
14
|
Balance
Sheet.........................................................................................................................................................................................................................................................
|
15
|
Statement
of Cash
Flows......................................................................................................................................................................................................................................
|
16
|
Ameren
Energy Generating Company
|
|
Consolidated
Statement of
Income.....................................................................................................................................................................................................................
|
17
|
Consolidated
Balance
Sheet................................................................................................................................................................................................................................
|
18
|
Consolidated
Statement of Cash
Flows.............................................................................................................................................................................................................
|
19
|
CILCORP
Inc.
|
|
Consolidated
Statement of
Income.....................................................................................................................................................................................................................
|
20
|
Consolidated
Balance
Sheet................................................................................................................................................................................................................................
|
21
|
Consolidated
Statement of Cash
Flows.............................................................................................................................................................................................................
|
22
|
Central
Illinois Light Company
|
|
Consolidated
Statement of
Income.....................................................................................................................................................................................................................
|
23
|
Consolidated
Balance
Sheet................................................................................................................................................................................................................................
|
24
|
Consolidated
Statement of Cash
Flows.............................................................................................................................................................................................................
|
25
|
Illinois
Power Company
|
|
Consolidated
Statement of
Income.....................................................................................................................................................................................................................
|
26
|
Consolidated
Balance
Sheet................................................................................................................................................................................................................................
|
27
|
Consolidated
Statement of Cash
Flows.............................................................................................................................................................................................................
|
28
|
Combined
Notes to Financial
Statements..................................................................................................................................................................................................................
|
29
|
Item
2. Management’s Discussion and
Analysis of Financial Condition and Results of
Operations.............................................................................................................................
|
57
|
Item
3. Quantitative and Qualitative
Disclosures About Market
Risk..................................................................................................................................................................................
|
79
|
Item
4. Controls and
Procedures.................................................................................................................................................................................................................................................
|
83
|
PART
II Other Information
|
|
Item
1. Legal
Proceedings............................................................................................................................................................................................................................................................
|
84
|
Item
1A. Risk
Factors.......................................................................................................................................................................................................................................................................
|
84
|
Item
2. Unregistered Sales of
Equity Securities and Use of
Proceeds..................................................................................................................................................................................
|
86
|
Item
4. Submission of Matters to a
Vote of Security
Holders................................................................................................................................................................................................
|
87
|
Item
6.
Exhibits...............................................................................................................................................................................................................................................................................
|
88
|
Signatures..............................................................................................................................................................................................................................................................................................
|
90
|
·
|
regulatory
or legislative actions, including changes in regulatory policies
and
ratemaking determinations, such as the failure of the Illinois
governor to
enact legislation implementing the comprehensive rate relief
programs and
agreement, the enactment of alternative legislation rolling back
and
freezing electric rates at 2006 levls or similar actions that
impair the
full and timely recovery of costs in Illinois, or the enactment
of
alternative legislation taxing electric generators in
Illinois;
|
·
|
the
impact of the termination of the
JDA;
|
·
|
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 occurred
when the electric rate freeze and power supply contracts expired
in
Illinois at the end of 2006;
|
·
|
the
effects of participation in the
MISO;
|
·
|
the
availability of fuel such as coal, natural gas, and enriched
uranium used
to produce electricity; the availability of purchased power and
natural
gas for distribution; and the level and volatility of future
market prices
for such commodities, including the ability to recover the costs
for such
commodities;
|
·
|
the
effectiveness of our risk management strategies and the use of
financial
and derivative instruments;
|
·
|
prices
for power in the Midwest;
|
·
|
business
and economic conditions, including their impact on interest
rates;
|
·
|
disruptions
of the capital markets or other events that make the Ameren Companies’
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 credit rating agencies and the effects of such
actions;
|
·
|
weather
conditions and other natural
phenomena;
|
·
|
the
impact of system outages caused by severe weather conditions
or other
events;
|
·
|
generation
plant construction, installation and performance, including costs
associated with UE’s Taum Sauk pumped-storage hydroelectric plant incident
and the plant’s future operation;
|
·
|
recoverability
through insurance of costs associated with UE’s Taum Sauk pumped-storage
hydroelectric plant incident;
|
·
|
operation
of UE’s 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
power
generating companies and the expectation that more stringent
requirements,
including those related to greenhouse gases, will be introduced
over time,
which could have a negative financial
effect;
|
·
|
labor
disputes, future wage and employee benefits costs, including
changes in
returns on benefit plan assets;
|
·
|
the
inability of our counterparties and affiliates to meet their
obligations
with respect to contracts and financial
instruments;
|
·
|
the
cost and availability of transmission capacity for the energy
generated by
the Ameren Companies’ facilities or required to satisfy energy sales made
by the Ameren Companies;
|
·
|
legal
and administrative proceedings; and
|
·
|
acts
of sabotage, war, terrorism or intentionally disruptive
acts.
|
AMEREN
CORPORATION
|
||||||||||||||||
CONSOLIDATED
STATEMENT OF INCOME
|
||||||||||||||||
(Unaudited)
(In millions, except per share amounts)
|
||||||||||||||||
Three
Months Ended
June
30,
|
Six
Months Ended
June
30,
|
|||||||||||||||
2007
|
2006
|
2007
|
2006
|
|||||||||||||
Operating
Revenues:
|
||||||||||||||||
Electric
|
$ |
1,514
|
$ |
1,378
|
$ |
2,972
|
$ |
2,589
|
||||||||
Gas
|
209
|
172
|
770
|
761
|
||||||||||||
Total
operating revenues
|
1,723
|
1,550
|
3,742
|
3,350
|
||||||||||||
Operating
Expenses:
|
||||||||||||||||
Fuel
|
263
|
247
|
526
|
499
|
||||||||||||
Purchased
power
|
314
|
277
|
687
|
550
|
||||||||||||
Gas
purchased for resale
|
133
|
104
|
554
|
557
|
||||||||||||
Other
operations and maintenance
|
426
|
394
|
822
|
746
|
||||||||||||
Depreciation
and amortization
|
169
|
162
|
345
|
323
|
||||||||||||
Taxes
other than income taxes
|
96
|
90
|
198
|
203
|
||||||||||||
Total
operating expenses
|
1,401
|
1,274
|
3,132
|
2,878
|
||||||||||||
Operating
Income
|
322
|
276
|
610
|
472
|
||||||||||||
Other
Income and Expenses:
|
||||||||||||||||
Miscellaneous
income
|
20
|
11
|
34
|
16
|
||||||||||||
Miscellaneous
expense
|
(4 | ) | (1 | ) | (4 | ) | (1 | ) | ||||||||
Total
other income
|
16
|
10
|
30
|
15
|
||||||||||||
Interest
Charges
|
108
|
87
|
206
|
164
|
||||||||||||
Income
Before Income Taxes, Minority Interest
|
||||||||||||||||
and
Preferred Dividends of Subsidiaries
|
230
|
199
|
434
|
323
|
||||||||||||
Income
Taxes
|
78
|
68
|
149
|
112
|
||||||||||||
Income
Before Minority Interest and Preferred
|
||||||||||||||||
Dividends
of Subsidiaries
|
152
|
131
|
285
|
211
|
||||||||||||
Minority
Interest and Preferred Dividends of Subsidiaries
|
9
|
8
|
19
|
18
|
||||||||||||
Net
Income
|
$ |
143
|
$ |
123
|
$ |
266
|
$ |
193
|
||||||||
Earnings
per Common Share – Basic and Diluted
|
$ |
0.69
|
$ |
0.60
|
$ |
1.29
|
$ |
0.94
|
||||||||
Dividends
per Common Share
|
$ |
0.635
|
$ |
0.635
|
$ |
1.270
|
$ |
1.270
|
||||||||
Average
Common Shares Outstanding
|
207.1
|
205.4
|
206.9
|
205.1
|
AMEREN
CORPORATION
|
|||||||
CONSOLIDATED
BALANCE SHEET
|
|||||||
(Unaudited)
(In millions, except per share amounts)
|
|||||||
June
30,
|
December
31,
|
||||||
2007
|
2006
|
||||||
ASSETS
|
|||||||
Current
Assets:
|
|||||||
Cash
and cash equivalents
|
$ |
687
|
$ |
137
|
|||
Accounts
receivable – trade (less allowance for doubtful
|
|||||||
accounts
of $31 and $11, respectively)
|
562
|
418
|
|||||
Unbilled
revenue
|
304
|
309
|
|||||
Miscellaneous
accounts and notes receivable
|
222
|
160
|
|||||
Materials
and supplies
|
612
|
647
|
|||||
Other
current assets
|
178
|
203
|
|||||
Total
current assets
|
2,565
|
1,874
|
|||||
Property
and Plant, Net
|
14,538
|
14,286
|
|||||
Investments
and Other Assets:
|
|||||||
Investments
in leveraged leases
|
13
|
13
|
|||||
Nuclear
decommissioning trust fund
|
301
|
285
|
|||||
Goodwill
|
831
|
831
|
|||||
Intangible
assets
|
206
|
217
|
|||||
Other
assets
|
730
|
641
|
|||||
Regulatory
assets
|
1,347
|
1,431
|
|||||
Total
investments and other assets
|
3,428
|
3,418
|
|||||
TOTAL
ASSETS
|
$ |
20,531
|
$ |
19,578
|
|||
LIABILITIES
AND STOCKHOLDERS' EQUITY
|
|||||||
Current
Liabilities:
|
|||||||
Current
maturities of long-term debt
|
$ |
203
|
$ |
456
|
|||
Short-term
debt
|
1,619
|
612
|
|||||
Accounts
and wages payable
|
455
|
671
|
|||||
Taxes
accrued
|
120
|
58
|
|||||
Other
current liabilities
|
423
|
405
|
|||||
Total
current liabilities
|
2,820
|
2,202
|
|||||
Long-term
Debt, Net
|
5,511
|
5,285
|
|||||
Preferred
Stock of Subsidiary Subject to Mandatory
Redemption
|
18
|
18
|
|||||
Deferred
Credits and Other Liabilities:
|
|||||||
Accumulated
deferred income taxes, net
|
2,039
|
2,144
|
|||||
Accumulated
deferred investment tax credits
|
113
|
118
|
|||||
Regulatory
liabilities
|
1,216
|
1,234
|
|||||
Asset
retirement obligations
|
564
|
549
|
|||||
Accrued
pension and other postretirement benefits
|
1,040
|
1,065
|
|||||
Other
deferred credits and liabilities
|
378
|
169
|
|||||
Total
deferred credits and other liabilities
|
5,350
|
5,279
|
|||||
Preferred
Stock of Subsidiaries Not Subject to Mandatory
Redemption
|
195
|
195
|
|||||
Minority
Interest in Consolidated Subsidiaries
|
19
|
16
|
|||||
Commitments
and Contingencies (Notes 2, 8, and 9)
|
|||||||
Stockholders'
Equity:
|
|||||||
Common
stock, $.01 par value, 400.0 shares authorized –
|
|||||||
shares
outstanding of 207.0 and 206.6, respectively
|
2
|
2
|
|||||
Other
paid-in capital, principally premium on common stock
|
4,551
|
4,495
|
|||||
Retained
earnings
|
2,023
|
2,024
|
|||||
Accumulated
other comprehensive income
|
42
|
62
|
|||||
Total
stockholders’ equity
|
6,618
|
6,583
|
|||||
TOTAL
LIABILITIES AND STOCKHOLDERS' EQUITY
|
$ |
20,531
|
$ |
19,578
|
AMEREN
CORPORATION
|
|||||||
CONSOLIDATED
STATEMENT OF CASH FLOWS
|
|||||||
(Unaudited)
(In millions)
|
|||||||
Six
Months Ended
|
|||||||
June
30,
|
|||||||
2007
|
2006
|
||||||
Cash
Flows From Operating Activities:
|
|||||||
Net
income
|
$ |
266
|
$ |
193
|
|||
Adjustments
to reconcile net income to net cash
|
|||||||
provided
by operating activities:
|
|||||||
Gain
on sales of emission allowances
|
(2 | ) |
-
|
||||
Depreciation
and amortization
|
357
|
340
|
|||||
Amortization
of nuclear fuel
|
15
|
16
|
|||||
Amortization
of debt issuance costs and premium/discounts
|
10
|
7
|
|||||
Deferred
income taxes and investment tax credits, net
|
(8 | ) | (19 | ) | |||
Loss
on sale of noncore properties
|
-
|
4
|
|||||
Minority
interest
|
13
|
12
|
|||||
Other
|
7
|
1
|
|||||
Changes
in assets and liabilities:
|
|||||||
Receivables
|
(195 | ) |
168
|
||||
Materials
and supplies
|
35
|
25
|
|||||
Accounts
and wages payable
|
(62 | ) | (214 | ) | |||
Taxes
accrued
|
59
|
(33 | ) | ||||
Assets,
other
|
(69 | ) |
63
|
||||
Liabilities,
other
|
67
|
10
|
|||||
Pension
and other postretirement benefit obligations
|
50
|
46
|
|||||
Net
cash provided by operating activities
|
543
|
619
|
|||||
Cash
Flows From Investing Activities:
|
|||||||
Capital
expenditures
|
(715 | ) | (449 | ) | |||
CT
acquisitions
|
-
|
(292 | ) | ||||
Nuclear
fuel expenditures
|
(24 | ) | (25 | ) | |||
Proceeds
from sale of noncore properties
|
-
|
11
|
|||||
Purchases
of securities – nuclear decommissioning trust fund
|
(75 | ) | (53 | ) | |||
Sales
of securities – nuclear decommissioning trust fund
|
65
|
48
|
|||||
Purchases
of emission allowances
|
(9 | ) | (38 | ) | |||
Sales
of emission allowances
|
3
|
4
|
|||||
Other
|
1
|
(1 | ) | ||||
Net
cash used in investing activities
|
(754 | ) | (795 | ) | |||
Cash
Flows From Financing Activities:
|
|||||||
Dividends
on common stock
|
(263 | ) | (260 | ) | |||
Capital
issuance costs
|
(3 | ) | (2 | ) | |||
Short-term
debt, net
|
1,007
|
204
|
|||||
Dividends
paid to minority interest
|
(10 | ) | (14 | ) | |||
Redemptions,
repurchases, and maturities of long-term debt
|
(443 | ) | (86 | ) | |||
Issuances:
|
|||||||
Common
stock
|
48
|
57
|
|||||
Long-term
debt
|
425
|
232
|
|||||
Net
cash provided by financing activities
|
761
|
131
|
|||||
Net
change in cash and cash equivalents
|
550
|
(45 | ) | ||||
Cash
and cash equivalents at beginning of year
|
137
|
96
|
|||||
Cash
and cash equivalents at end of period
|
$ |
687
|
$ |
51
|
UNION
ELECTRIC COMPANY
|
||||||||||||||||
CONSOLIDATED
STATEMENT OF INCOME
|
||||||||||||||||
(Unaudited)
(In millions)
|
||||||||||||||||
Three
Months Ended
|
Six
Months Ended
|
|||||||||||||||
June
30,
|
June
30,
|
|||||||||||||||
2007
|
2006
|
2007
|
2006
|
|||||||||||||
Operating
Revenues:
|
||||||||||||||||
Electric
- excluding off-system
|
$ |
579
|
$ |
584
|
$ |
1,030
|
$ |
1,013
|
||||||||
Electric
- off-system
|
89
|
103
|
211
|
241
|
||||||||||||
Gas
|
29
|
22
|
105
|
91
|
||||||||||||
Other
|
-
|
1
|
1
|
1
|
||||||||||||
Total
operating revenues
|
697
|
710
|
1,347
|
1,346
|
||||||||||||
Operating
Expenses:
|
||||||||||||||||
Fuel
|
143
|
124
|
268
|
249
|
||||||||||||
Purchased
power
|
29
|
68
|
62
|
135
|
||||||||||||
Gas
purchased for resale
|
15
|
12
|
64
|
56
|
||||||||||||
Other
operations and maintenance
|
222
|
196
|
446
|
367
|
||||||||||||
Depreciation
and amortization
|
84
|
81
|
171
|
161
|
||||||||||||
Taxes
other than income taxes
|
60
|
59
|
117
|
118
|
||||||||||||
Total
operating expenses
|
553
|
540
|
1,128
|
1,086
|
||||||||||||
Operating
Income
|
144
|
170
|
219
|
260
|
||||||||||||
Other
Income and Expenses:
|
||||||||||||||||
Miscellaneous
income
|
12
|
8
|
20
|
12
|
||||||||||||
Miscellaneous
expense
|
(6 | ) | (2 | ) | (8 | ) | (4 | ) | ||||||||
Total
other income
|
6
|
6
|
12
|
8
|
||||||||||||
Interest
Charges
|
51
|
44
|
97
|
80
|
||||||||||||
Income
Before Income Taxes and Equity
|
||||||||||||||||
in
Income of Unconsolidated Investment
|
99
|
132
|
134
|
188
|
||||||||||||
Income
Taxes
|
30
|
50
|
41
|
69
|
||||||||||||
Income
Before Equity in Income
|
||||||||||||||||
of
Unconsolidated Investment
|
69
|
82
|
93
|
119
|
||||||||||||
Equity
in Income of Unconsolidated Investment,
|
||||||||||||||||
Net
of Taxes
|
12
|
10
|
26
|
24
|
||||||||||||
Net
Income
|
81
|
92
|
119
|
143
|
||||||||||||
Preferred
Stock Dividends
|
2
|
2
|
3
|
3
|
||||||||||||
Net
Income Available to Common Stockholder
|
$ |
79
|
$ |
90
|
$ |
116
|
$ |
140
|
UNION
ELECTRIC COMPANY
|
|||||||
CONSOLIDATED
BALANCE SHEET
|
|||||||
(Unaudited)
(In millions, except per share amounts)
|
|||||||
June
30,
|
December
31,
|
||||||
2007
|
2006
|
||||||
ASSETS
|
|||||||
Current
Assets:
|
|||||||
Cash
and cash equivalents
|
$ |
209
|
$ |
1
|
|||
Accounts
receivable – trade (less allowance for doubtful
|
|||||||
accounts
of $8 and $6, respectively)
|
220
|
145
|
|||||
Unbilled
revenue
|
157
|
120
|
|||||
Miscellaneous
accounts and notes receivable
|
164
|
128
|
|||||
Advances
to money pool
|
12
|
18
|
|||||
Accounts
receivable – affiliates
|
59
|
33
|
|||||
Materials
and supplies
|
267
|
236
|
|||||
Other
current assets
|
56
|
45
|
|||||
Total
current assets
|
1,144
|
726
|
|||||
Property
and Plant, Net
|
8,000
|
7,882
|
|||||
Investments
and Other Assets:
|
|||||||
Nuclear
decommissioning trust fund
|
301
|
285
|
|||||
Intangible
assets
|
58
|
58
|
|||||
Other
assets
|
474
|
526
|
|||||
Regulatory
assets
|
790
|
810
|
|||||
Total
investments and other assets
|
1,623
|
1,679
|
|||||
TOTAL
ASSETS
|
$ |
10,767
|
$ |
10,287
|
|||
LIABILITIES
AND STOCKHOLDERS' EQUITY
|
|||||||
Current
Liabilities:
|
|||||||
Current
maturities of long-term debt
|
$ |
152
|
$ |
5
|
|||
Short-term
debt
|
426
|
234
|
|||||
Intercompany
note payable – Ameren
|
37
|
77
|
|||||
Accounts
and wages payable
|
159
|
313
|
|||||
Accounts
payable – affiliates
|
114
|
185
|
|||||
Taxes
accrued
|
142
|
66
|
|||||
Other
current liabilities
|
229
|
191
|
|||||
Total
current liabilities
|
1,259
|
1,071
|
|||||
Long-term
Debt, Net
|
3,212
|
2,934
|
|||||
Deferred
Credits and Other Liabilities:
|
|||||||
Accumulated
deferred income taxes, net
|
1,273
|
1,293
|
|||||
Accumulated
deferred investment tax credits
|
86
|
89
|
|||||
Regulatory
liabilities
|
838
|
827
|
|||||
Asset
retirement obligations
|
504
|
491
|
|||||
Accrued
pension and other postretirement benefits
|
370
|
374
|
|||||
Other
deferred credits and liabilities
|
83
|
55
|
|||||
Total
deferred credits and other liabilities
|
3,154
|
3,129
|
|||||
Commitments
and Contingencies (Notes 2, 8 and 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
|
739
|
739
|
|||||
Retained
earnings
|
1,775
|
1,783
|
|||||
Accumulated
other comprehensive income
|
4
|
7
|
|||||
Total
stockholders' equity
|
3,142
|
3,153
|
|||||
TOTAL
LIABILITIES AND STOCKHOLDERS' EQUITY
|
$ |
10,767
|
$ |
10,287
|
UNION
ELECTRIC COMPANY
|
|||||||
CONSOLIDATED
STATEMENT OF CASH FLOWS
|
|||||||
(Unaudited)
(In millions)
|
|||||||
Six
Months Ended
|
|||||||
June
30,
|
|||||||
2007
|
2006
|
||||||
Cash
Flows From Operating Activities:
|
|||||||
Net
income
|
$ |
119
|
$ |
143
|
|||
Adjustments
to reconcile net income to net cash
|
|||||||
provided
by operating activities:
|
|||||||
Depreciation
and amortization
|
171
|
161
|
|||||
Amortization
of nuclear fuel
|
15
|
16
|
|||||
Amortization
of debt issuance costs and premium/discounts
|
3
|
3
|
|||||
Deferred
income taxes and investment tax credits, net
|
15
|
11
|
|||||
Other
|
-
|
(5 | ) | ||||
Changes
in assets and liabilities:
|
|||||||
Receivables
|
(174 | ) | (15 | ) | |||
Materials
and supplies
|
(31 | ) | (13 | ) | |||
Accounts
and wages payable
|
(136 | ) | (180 | ) | |||
Taxes
accrued
|
76
|
54
|
|||||
Assets,
other
|
55
|
30
|
|||||
Liabilities,
other
|
17
|
35
|
|||||
Pension
and other postretirement obligations
|
15
|
18
|
|||||
Net
cash provided by operating activities
|
145
|
258
|
|||||
Cash
Flows From Investing Activities:
|
|||||||
Capital
expenditures
|
(355 | ) | (222 | ) | |||
CT
acquisitions
|
-
|
(292 | ) | ||||
Nuclear
fuel expenditures
|
(24 | ) | (25 | ) | |||
Changes
in money pool advances
|
6
|
-
|
|||||
Proceeds
from intercompany note receivable – CIPS
|
-
|
67
|
|||||
Purchases
of securities – nuclear decommissioning trust fund
|
(75 | ) | (53 | ) | |||
Sales
of securities – nuclear decommissioning trust fund
|
65
|
48
|
|||||
Sales
of emission allowances
|
2
|
2
|
|||||
Net
cash used in investing activities
|
(381 | ) | (475 | ) | |||
Cash
Flows From Financing Activities:
|
|||||||
Dividends
on common stock
|
(127 | ) | (84 | ) | |||
Dividends
on preferred stock
|
(3 | ) | (3 | ) | |||
Capital
issuance costs
|
(3 | ) |
-
|
||||
Short-term
debt, net
|
192
|
284
|
|||||
Intercompany
note payable – Ameren, net
|
(40 | ) |
-
|
||||
Issuances
of long-term debt
|
425
|
-
|
|||||
Capital
contribution from parent
|
-
|
1
|
|||||
Net
cash provided by financing activities
|
444
|
198
|
|||||
Net
change in cash and cash equivalents
|
208
|
(19 | ) | ||||
Cash
and cash equivalents at beginning of year
|
1
|
20
|
|||||
Cash
and cash equivalents at end of period
|
$ |
209
|
$ |
1
|
CENTRAL
ILLINOIS PUBLIC SERVICE COMPANY
|
|||||||||||||||
STATEMENT
OF INCOME
|
|||||||||||||||
(Unaudited)
(In millions)
|
|||||||||||||||
Three
Months Ended
|
Six
Months Ended
|
||||||||||||||
June
30,
|
June
30,
|
||||||||||||||
2007
|
2006
|
2007
|
2006
|
||||||||||||
Operating
Revenues:
|
|||||||||||||||
Electric
|
$ |
193
|
$ |
181
|
$ |
404
|
$ |
341
|
|||||||
Gas
|
36
|
30
|
137
|
127
|
|||||||||||
Other
|
-
|
1
|
2
|
1
|
|||||||||||
Total
operating revenues
|
229
|
212
|
543
|
469
|
|||||||||||
Operating
Expenses:
|
|||||||||||||||
Purchased
power
|
127
|
113
|
277
|
230
|
|||||||||||
Gas
purchased for resale
|
21
|
16
|
95
|
88
|
|||||||||||
Other
operations and maintenance
|
41
|
38
|
84
|
76
|
|||||||||||
Depreciation
and amortization
|
16
|
15
|
33
|
31
|
|||||||||||
Taxes
other than income taxes
|
9
|
9
|
18
|
21
|
|||||||||||
Total
operating expenses
|
214
|
191
|
507
|
446
|
|||||||||||
Operating
Income
|
15
|
21
|
36
|
23
|
|||||||||||
Other
Income and Expenses:
|
|||||||||||||||
Miscellaneous
income
|
5
|
4
|
8
|
9
|
|||||||||||
Miscellaneous
expense
|
(1 | ) |
-
|
(1 | ) | (1 | ) | ||||||||
Total
other income
|
4
|
4
|
7
|
8
|
|||||||||||
Interest
Charges
|
10
|
8
|
18
|
15
|
|||||||||||
Income
Before Income Taxes
|
9
|
17
|
25
|
16
|
|||||||||||
Income
Taxes
|
4
|
2
|
9
|
2
|
|||||||||||
Net
Income
|
5
|
15
|
16
|
14
|
|||||||||||
Preferred
Stock Dividends
|
-
|
-
|
1
|
1
|
|||||||||||
Net
Income Available to Common Stockholder
|
$ |
5
|
$ |
15
|
$ |
15
|
$ |
13
|
CENTRAL
ILLINOIS PUBLIC SERVICE COMPANY
|
|||||||
BALANCE
SHEET
|
|||||||
(Unaudited)
(In millions)
|
|||||||
June
30,
|
December
31,
|
||||||
2007
|
2006
|
||||||
ASSETS
|
|||||||
Current
Assets:
|
|||||||
Cash
and cash equivalents
|
$ |
148
|
$ |
6
|
|||
Accounts
receivable – trade (less allowance for doubtful
|
|||||||
accounts
of $8 and $2, respectively)
|
65
|
55
|
|||||
Unbilled
revenue
|
32
|
43
|
|||||
Accounts
receivable – affiliates
|
2
|
10
|
|||||
Current
portion of intercompany note receivable – Genco
|
39
|
37
|
|||||
Current
portion of intercompany tax receivable – Genco
|
9
|
9
|
|||||
Advances
to money pool
|
-
|
1
|
|||||
Materials
and supplies
|
51
|
71
|
|||||
Other
current assets
|
43
|
46
|
|||||
Total
current assets
|
389
|
278
|
|||||
Property
and Plant, Net
|
1,160
|
1,155
|
|||||
Investments
and Other Assets:
|
|||||||
Intercompany
note receivable – Genco
|
87
|
126
|
|||||
Intercompany
tax receivable – Genco
|
111
|
115
|
|||||
Other
assets
|
29
|
27
|
|||||
Regulatory
assets
|
134
|
146
|
|||||
Total
investments and other assets
|
361
|
414
|
|||||
TOTAL
ASSETS
|
$ |
1,910
|
$ |
1,847
|
|||
LIABILITIES
AND STOCKHOLDERS' EQUITY
|
|||||||
Current
Liabilities:
|
|||||||
Short-term
debt
|
$ |
135
|
$ |
35
|
|||
Accounts
and wages payable
|
44
|
36
|
|||||
Accounts
payable – affiliates
|
39
|
81
|
|||||
Taxes
accrued
|
6
|
10
|
|||||
Other
current liabilities
|
34
|
36
|
|||||
Total
current liabilities
|
258
|
198
|
|||||
Long-term
Debt, Net
|
471
|
471
|
|||||
Deferred
Credits and Other Liabilities:
|
|||||||
Accumulated
deferred income taxes and investment tax credits, net
|
275
|
297
|
|||||
Regulatory
liabilities
|
221
|
224
|
|||||
Accrued
pension and other postretirement benefits
|
83
|
90
|
|||||
Other
deferred credits and liabilities
|
44
|
24
|
|||||
Total
deferred credits and other liabilities
|
623
|
635
|
|||||
Commitments
and Contingencies (Notes 2 and 8)
|
|||||||
Stockholders'
Equity:
|
|||||||
Common
stock, no par value, 45.0 shares authorized – 25.5 shares
outstanding
|
-
|
-
|
|||||
Other
paid-in capital
|
190
|
190
|
|||||
Preferred
stock not subject to mandatory redemption
|
50
|
50
|
|||||
Retained
earnings
|
317
|
302
|
|||||
Accumulated
other comprehensive income
|
1
|
1
|
|||||
Total
stockholders' equity
|
558
|
543
|
|||||
TOTAL
LIABILITIES AND STOCKHOLDERS' EQUITY
|
$ |
1,910
|
$ |
1,847
|
CENTRAL
ILLINOIS PUBLIC SERVICE COMPANY
|
|||||||
STATEMENT
OF CASH FLOWS
|
|||||||
(Unaudited)
(In millions)
|
|||||||
Six
Months Ended
|
|||||||
June
30,
|
|||||||
2007
|
2006
|
||||||
Cash
Flows From Operating Activities:
|
|||||||
Net
income
|
$ |
16
|
$ |
14
|
|||
Adjustments
to reconcile net income to net cash
|
|||||||
provided
by operating activities:
|
|||||||
Depreciation
and amortization
|
33
|
31
|
|||||
Amortization
of debt issuance costs and premium/discounts
|
1
|
-
|
|||||
Deferred
income taxes and investment tax credits, net
|
(10 | ) | (16 | ) | |||
Other
|
-
|
(1 | ) | ||||
Changes
in assets and liabilities:
|
|||||||
Receivables
|
13
|
39
|
|||||
Materials
and supplies
|
20
|
21
|
|||||
Accounts
and wages payable
|
(30 | ) | (8 | ) | |||
Taxes
accrued
|
(4 | ) | (19 | ) | |||
Assets,
other
|
6
|
22
|
|||||
Liabilities,
other
|
(4 | ) | (3 | ) | |||
Pension
and other postretirement obligations
|
3
|
-
|
|||||
Net
cash provided by operating activities
|
44
|
80
|
|||||
Cash
Flows From Investing Activities:
|
|||||||
Capital
expenditures
|
(39 | ) | (41 | ) | |||
Proceeds
from intercompany note receivable – Genco
|
37
|
34
|
|||||
Changes
in money pool advances
|
1
|
(17 | ) | ||||
Net
cash used in investing activities
|
(1 | ) | (24 | ) | |||
Cash
Flows From Financing Activities:
|
|||||||
Dividends
on common stock
|
-
|
(25 | ) | ||||
Dividends
on preferred stock
|
(1 | ) | (1 | ) | |||
Capital
issuance costs
|
-
|
(1 | ) | ||||
Short-term
debt, net
|
100
|
-
|
|||||
Changes
in money pool borrowings
|
-
|
(2 | ) | ||||
Redemptions,
repurchases, and maturities:
|
|||||||
Long-term
debt
|
-
|
(20 | ) | ||||
Intercompany
note payable – UE
|
-
|
(67 | ) | ||||
Issuances
of long-term debt
|
-
|
61
|
|||||
Net
cash provided by (used in) financing activities
|
99
|
(55 | ) | ||||
Net
change in cash and cash equivalents
|
142
|
1
|
|||||
Cash
and cash equivalents at beginning of year
|
6
|
-
|
|||||
Cash
and cash equivalents at end of period
|
$ |
148
|
$ |
1
|
AMEREN
ENERGY GENERATING COMPANY
|
|||||||||||||||
CONSOLIDATED
STATEMENT OF INCOME
|
|||||||||||||||
(Unaudited)
(In millions)
|
|||||||||||||||
Three
Months Ended
|
Six
Months Ended
|
||||||||||||||
June
30,
|
June
30,
|
||||||||||||||
2007
|
2006
|
2007
|
2006
|
||||||||||||
Operating
Revenues
|
$ |
185
|
$ |
238
|
$ |
428
|
$ |
485
|
|||||||
Operating
Expenses:
|
|||||||||||||||
Fuel
|
74
|
61
|
155
|
130
|
|||||||||||
Purchased
power
|
(1 | ) |
89
|
20
|
185
|
||||||||||
Other
operations and maintenance
|
49
|
47
|
83
|
79
|
|||||||||||
Depreciation
and amortization
|
18
|
17
|
36
|
35
|
|||||||||||
Taxes
other than income taxes
|
4
|
5
|
10
|
11
|
|||||||||||
Total
operating expenses
|
144
|
219
|
304
|
440
|
|||||||||||
Operating
Income
|
41
|
19
|
124
|
45
|
|||||||||||
Miscellaneous
Income
|
1
|
-
|
1
|
-
|
|||||||||||
Interest
Charges
|
14
|
15
|
28
|
30
|
|||||||||||
Income
Before Income Taxes
|
28
|
4
|
97
|
15
|
|||||||||||
Income
Taxes
|
11
|
2
|
37
|
7
|
|||||||||||
Net
Income
|
$ |
17
|
$ |
2
|
$ |
60
|
$ |
8
|
|||||||
AMEREN
ENERGY GENERATING COMPANY
|
|||||||
CONSOLIDATED
BALANCE SHEET
|
|||||||
(Unaudited)
(In millions, except shares)
|
|||||||
June
30,
|
December
31,
|
||||||
2007
|
2006
|
||||||
ASSETS
|
|||||||
Current
Assets:
|
|||||||
Cash
and cash equivalents
|
$ |
1
|
$ |
1
|
|||
Accounts
receivable – affiliates
|
100
|
96
|
|||||
Accounts
receivable – trade
|
5
|
19
|
|||||
Materials
and supplies
|
97
|
96
|
|||||
Other
current assets
|
29
|
5
|
|||||
Total
current assets
|
232
|
217
|
|||||
Property
and Plant, Net
|
1,558
|
1,539
|
|||||
Intangible
Assets
|
64
|
74
|
|||||
Other
Assets
|
18
|
20
|
|||||
TOTAL
ASSETS
|
$ |
1,872
|
$ |
1,850
|
|||
LIABILITIES
AND STOCKHOLDER'S EQUITY
|
|||||||
Current
Liabilities:
|
|||||||
Current
portion of intercompany note payable – CIPS
|
$ |
39
|
$ |
37
|
|||
Borrowings
from money pool
|
239
|
123
|
|||||
Accounts
and wages payable
|
36
|
52
|
|||||
Accounts
payable – affiliates
|
73
|
66
|
|||||
Current
portion of intercompany tax payable – CIPS
|
9
|
9
|
|||||
Taxes
accrued
|
20
|
22
|
|||||
Other
current liabilities
|
21
|
22
|
|||||
Total
current liabilities
|
437
|
331
|
|||||
Long-term
Debt, Net
|
474
|
474
|
|||||
Intercompany
Note Payable – CIPS
|
87
|
126
|
|||||
Deferred
Credits and Other Liabilities:
|
|||||||
Accumulated
deferred income taxes, net
|
146
|
165
|
|||||
Accumulated
deferred investment tax credits
|
8
|
9
|
|||||
Intercompany
tax payable – CIPS
|
111
|
115
|
|||||
Asset
retirement obligations
|
32
|
31
|
|||||
Accrued
pension and other postretirement benefits
|
40
|
34
|
|||||
Other
deferred credits and liabilities
|
31
|
2
|
|||||
Total
deferred credits and other liabilities
|
368
|
356
|
|||||
Commitments
and Contingencies (Notes 2 and 8)
|
|||||||
Stockholder's
Equity:
|
|||||||
Common
stock, no par value, 10,000 shares authorized – 2,000 shares
outstanding
|
-
|
-
|
|||||
Other
paid-in capital
|
428
|
428
|
|||||
Retained
earnings
|
103
|
156
|
|||||
Accumulated
other comprehensive loss
|
(25 | ) | (21 | ) | |||
Total
stockholder's equity
|
506
|
563
|
|||||
TOTAL
LIABILITIES AND STOCKHOLDER'S EQUITY
|
$ |
1,872
|
$ |
1,850
|
AMEREN
ENERGY GENERATING COMPANY
|
|||||||
CONSOLIDATED
STATEMENT OF CASH FLOWS
|
|||||||
(Unaudited)
(In millions)
|
|||||||
Six
Months Ended
|
|||||||
June
30,
|
|||||||
2007
|
2006
|
||||||
Cash
Flows From Operating Activities:
|
|||||||
Net
income
|
$ |
60
|
$ |
8
|
|||
Adjustments
to reconcile net income to net cash
|
|||||||
provided
by operating activities:
|
|||||||
Gain
on sales of emission allowances
|
(1 | ) |
-
|
||||
Depreciation
and amortization
|
52
|
51
|
|||||
Deferred
income taxes and investment tax credits, net
|
8
|
(8 | ) | ||||
Other
|
1
|
(1 | ) | ||||
Changes
in assets and liabilities:
|
|||||||
Receivables
|
10
|
27
|
|||||
Materials
and supplies
|
(1 | ) | (26 | ) | |||
Accounts
and wages payable
|
13
|
36
|
|||||
Taxes
accrued, net
|
(2 | ) | (23 | ) | |||
Assets,
other
|
(26 | ) |
-
|
||||
Liabilities,
other
|
(2 | ) | (4 | ) | |||
Pension
and other postretirement obligations
|
3
|
3
|
|||||
Net
cash provided by operating activities
|
115
|
63
|
|||||
Cash
Flows From Investing Activities:
|
|||||||
Capital
expenditures
|
(77 | ) | (39 | ) | |||
Purchases
of emission allowances
|
(5 | ) | (26 | ) | |||
Sales
of emission allowances
|
1
|
1
|
|||||
Net
cash used in investing activities
|
(81 | ) | (64 | ) | |||
Cash
Flows From Financing Activities:
|
|||||||
Dividends
on common stock
|
(113 | ) | (71 | ) | |||
Changes
in money pool borrowings
|
116
|
57
|
|||||
Intercompany
notes payable – CIPS
|
(37 | ) | (34 | ) | |||
Capital
contribution from parent
|
-
|
50
|
|||||
Net
cash provided by (used in) financing activities
|
(34 | ) |
2
|
||||
Net
change in cash and cash equivalents
|
-
|
1
|
|||||
Cash
and cash equivalents at beginning of year
|
1
|
-
|
|||||
Cash
and cash equivalents at end of period
|
$ |
1
|
$ |
1
|
|||
CILCORP
INC.
|
|||||||||||||||
CONSOLIDATED
STATEMENT OF INCOME
|
|||||||||||||||
(Unaudited)
(In millions)
|
|||||||||||||||
Three
Months Ended
June
30,
|
Six
Months Ended
June
30,
|
||||||||||||||
2007
|
2006
|
2007
|
2006
|
||||||||||||
Operating
Revenues:
|
|||||||||||||||
Electric
|
$ |
162
|
$ |
98
|
$ |
337
|
$ |
190
|
|||||||
Gas
|
60
|
48
|
195
|
198
|
|||||||||||
Other
|
1
|
-
|
1
|
-
|
|||||||||||
Total
operating revenues
|
223
|
146
|
533
|
388
|
|||||||||||
Operating
Expenses:
|
|||||||||||||||
Fuel
|
14
|
29
|
37
|
53
|
|||||||||||
Purchased
power
|
61
|
6
|
133
|
8
|
|||||||||||
Gas
purchased for resale
|
42
|
32
|
145
|
151
|
|||||||||||
Other
operations and maintenance
|
45
|
48
|
87
|
93
|
|||||||||||
Depreciation
and amortization
|
19
|
19
|
38
|
37
|
|||||||||||
Taxes
other than income taxes
|
6
|
4
|
14
|
13
|
|||||||||||
Total
operating expenses
|
187
|
138
|
454
|
355
|
|||||||||||
Operating
Income
|
36
|
8
|
79
|
33
|
|||||||||||
Other
Income and Expenses:
|
|||||||||||||||
Miscellaneous
income
|
-
|
1
|
2
|
1
|
|||||||||||
Miscellaneous
expense
|
(2 | ) | (1 | ) | (3 | ) | (2 | ) | |||||||
Total
other expenses
|
(2 | ) |
-
|
(1 | ) | (1 | ) | ||||||||
Interest
Charges
|
15
|
13
|
29
|
25
|
|||||||||||
Income
(Loss) Before Income Taxes and Preferred
|
|||||||||||||||
Dividends
of Subsidiaries
|
19
|
(5 | ) |
49
|
7
|
||||||||||
Income
Taxes (Benefit)
|
6
|
(6 | ) |
16
|
(3 | ) | |||||||||
Income
Before Preferred Dividends of Subsidiaries
|
13
|
1
|
33
|
10
|
|||||||||||
Preferred
Dividends of Subsidiaries
|
1
|
-
|
1
|
1
|
|||||||||||
Net
Income
|
$ |
12
|
$ |
1
|
$ |
32
|
$ |
9
|
|||||||
CILCORP
INC.
|
|||||||
CONSOLIDATED
BALANCE SHEET
|
|||||||
(Unaudited)
(In millions, except shares)
|
|||||||
June
30,
|
December
31,
|
||||||
2007
|
2006
|
||||||
ASSETS
|
|||||||
Current
Assets:
|
|||||||
Cash
and cash equivalents
|
$ |
108
|
$ |
4
|
|||
Accounts
receivable – trade (less allowance for doubtful
|
|||||||
accounts
of $5 and $1, respectively)
|
49
|
47
|
|||||
Unbilled
revenue
|
35
|
45
|
|||||
Accounts
receivable – affiliates
|
30
|
10
|
|||||
Advances
to money pool
|
-
|
42
|
|||||
Materials
and supplies
|
79
|
93
|
|||||
Other
current assets
|
40
|
42
|
|||||
Total
current assets
|
341
|
283
|
|||||
Property
and Plant, Net
|
1,357
|
1,277
|
|||||
Investments
and Other Assets:
|
|||||||
Goodwill
|
542
|
542
|
|||||
Intangible
assets
|
45
|
48
|
|||||
Other
assets
|
19
|
16
|
|||||
Regulatory
assets
|
56
|
75
|
|||||
Total
investments and other assets
|
662
|
681
|
|||||
TOTAL
ASSETS
|
$ |
2,360
|
$ |
2,241
|
|||
LIABILITIES
AND STOCKHOLDER'S EQUITY
|
|||||||
Current
Liabilities:
|
|||||||
Current
maturities of long-term debt
|
$ |
-
|
$ |
50
|
|||
Short-term
debt
|
465
|
215
|
|||||
Intercompany
note payable – Ameren
|
-
|
73
|
|||||
Accounts
and wages payable
|
40
|
54
|
|||||
Accounts
payable – affiliates
|
63
|
60
|
|||||
Taxes
accrued
|
3
|
3
|
|||||
Other
current liabilities
|
48
|
58
|
|||||
Total
current liabilities
|
619
|
513
|
|||||
Long-term
Debt, Net
|
539
|
542
|
|||||
Preferred
Stock of Subsidiary Subject to Mandatory
Redemption
|
18
|
18
|
|||||
Deferred
Credits and Other Liabilities:
|
|||||||
Accumulated
deferred income taxes, net
|
183
|
201
|
|||||
Accumulated
deferred investment tax credits
|
7
|
7
|
|||||
Regulatory
liabilities
|
67
|
73
|
|||||
Accrued
pension and other postretirement benefits
|
151
|
171
|
|||||
Other
deferred credits and liabilities
|
55
|
26
|
|||||
Total
deferred credits and other liabilities
|
463
|
478
|
|||||
Preferred
Stock of Subsidiary Not Subject to Mandatory
Redemption
|
19
|
19
|
|||||
Commitments
and Contingencies (Notes 2 and 8)
|
|||||||
Stockholder's
Equity:
|
|||||||
Common
stock, no par value, 10,000 shares authorized – 1,000 shares
outstanding
|
-
|
-
|
|||||
Other
paid-in capital
|
627
|
627
|
|||||
Retained
earnings
|
43
|
11
|
|||||
Accumulated
other comprehensive income
|
32
|
33
|
|||||
Total
stockholder's equity
|
702
|
671
|
|||||
TOTAL
LIABILITIES AND STOCKHOLDER'S EQUITY
|
$ |
2,360
|
$ |
2,241
|
|||
CILCORP
INC.
|
|||||||
CONSOLIDATED
STATEMENT OF CASH FLOWS
|
|||||||
(Unaudited)
(In millions)
|
|||||||
Six
Months Ended
|
|||||||
June
30,
|
|||||||
2007
|
2006
|
||||||
Cash
Flows From Operating Activities:
|
|||||||
Net
income
|
$ |
32
|
$ |
9
|
|||
Adjustments
to reconcile net income to net cash
|
|||||||
provided
by operating activities:
|
|||||||
Depreciation
and amortization
|
38
|
50
|
|||||
Amortization
of debt issuance costs and premium/discounts
|
1
|
-
|
|||||
Deferred
income taxes and investment tax credits
|
(3 | ) | (4 | ) | |||
Loss
on sale of noncore properties
|
-
|
4
|
|||||
Other
|
-
|
(1 | ) | ||||
Changes
in assets and liabilities:
|
|||||||
Receivables
|
(12 | ) |
55
|
||||
Materials
and supplies
|
14
|
20
|
|||||
Accounts
and wages payable
|
3
|
(20 | ) | ||||
Taxes
accrued
|
(3 | ) | (13 | ) | |||
Assets,
other
|
(2 | ) |
20
|
||||
Liabilities,
other
|
(7 | ) | (9 | ) | |||
Pension
and postretirement benefit obligations
|
1
|
1
|
|||||
Net
cash provided by operating activities
|
62
|
112
|
|||||
Cash
Flows From Investing Activities:
|
|||||||
Capital
expenditures
|
(127 | ) | (48 | ) | |||
Proceeds
from note receivable – Resources Company
|
-
|
42
|
|||||
Proceeds
from sale of noncore properties
|
-
|
11
|
|||||
Changes
in money pool advances
|
42
|
-
|
|||||
Purchases
of emission allowances
|
-
|
(12 | ) | ||||
Sales
of emission allowances
|
-
|
1
|
|||||
Net
cash used in investing activities
|
(85 | ) | (6 | ) | |||
Cash
Flows From Financing Activities:
|
|||||||
Dividends
on common stock
|
-
|
(50 | ) | ||||
Capital
issuance costs
|
-
|
(1 | ) | ||||
Short-term
debt, net
|
250
|
-
|
|||||
Changes
in money pool borrowings
|
-
|
(89 | ) | ||||
Intercompany
note payable – Ameren, net
|
(73 | ) | (30 | ) | |||
Redemptions,
repurchases, and maturities of long-term debt
|
(50 | ) | (12 | ) | |||
Issuances
of long-term debt
|
-
|
96
|
|||||
Net
cash provided by (used in) financing activities
|
127
|
(86 | ) | ||||
Net
change in cash and cash equivalents
|
104
|
20
|
|||||
Cash
and cash equivalents at beginning of year
|
4
|
3
|
|||||
Cash
and cash equivalents at end of period
|
$ |
108
|
$ |
23
|
|||
CENTRAL
ILLINOIS LIGHT COMPANY
|
|||||||||||||||
CONSOLIDATED
STATEMENT OF INCOME
|
|||||||||||||||
(Unaudited)
(In millions)
|
|||||||||||||||
Three
Months Ended
June
30,
|
Six
Months Ended
June
30,
|
||||||||||||||
2007
|
2006
|
2007
|
2006
|
||||||||||||
Operating
Revenues:
|
|||||||||||||||
Electric
|
$ |
162
|
$ |
98
|
$ |
337
|
$ |
190
|
|||||||
Gas
|
60
|
48
|
195
|
198
|
|||||||||||
Other
|
1
|
-
|
1
|
-
|
|||||||||||
Total
operating revenues
|
223
|
146
|
533
|
388
|
|||||||||||
Operating
Expenses:
|
|||||||||||||||
Fuel
|
12
|
25
|
34
|
48
|
|||||||||||
Purchased
power
|
61
|
6
|
133
|
8
|
|||||||||||
Gas
purchased for resale
|
42
|
32
|
145
|
151
|
|||||||||||
Other
operations and maintenance
|
46
|
52
|
87
|
93
|
|||||||||||
Depreciation
and amortization
|
18
|
17
|
36
|
34
|
|||||||||||
Taxes
other than income taxes
|
5
|
4
|
13
|
13
|
|||||||||||
Total
operating expenses
|
184
|
136
|
448
|
347
|
|||||||||||
Operating
Income
|
39
|
10
|
85
|
41
|
|||||||||||
Other
Income and Expenses:
|
|||||||||||||||
Miscellaneous
income
|
1
|
-
|
2
|
-
|
|||||||||||
Miscellaneous
expense
|
(2 | ) | (1 | ) | (3 | ) | (2 | ) | |||||||
Total
other expenses
|
(1 | ) | (1 | ) | (1 | ) | (2 | ) | |||||||
Interest
Charges
|
5
|
4
|
11
|
8
|
|||||||||||
Income
Before Income Taxes
|
33
|
5
|
73
|
31
|
|||||||||||
Income
Taxes (Benefit)
|
12
|
(3 | ) |
26
|
6
|
||||||||||
Net
Income
|
21
|
8
|
47
|
25
|
|||||||||||
Preferred
Stock Dividends
|
1
|
1
|
1
|
1
|
|||||||||||
Net
Income Available to Common Stockholder
|
$ |
20
|
$ |
7
|
$ |
46
|
$ |
24
|
|||||||
CENTRAL
ILLINOIS LIGHT COMPANY
|
||||||||
CONSOLIDATED
BALANCE SHEET
|
||||||||
(Unaudited)
(In millions)
|
||||||||
June
30,
|
December
31
|
|||||||
2007
|
2006
|
|||||||
ASSETS
|
||||||||
Current
Assets:
|
||||||||
Cash
and cash equivalents
|
$ |
95
|
$ |
3
|
||||
Accounts
receivable – trade (less allowance for doubtful
|
||||||||
accounts
of $5 and $1, respectively)
|
49
|
47
|
||||||
Unbilled
revenue
|
35
|
45
|
||||||
Accounts
receivable – affiliates
|
27
|
9
|
||||||
Advances
to money pool
|
-
|
42
|
||||||
Materials
and supplies
|
79
|
93
|
||||||
Other
current assets
|
32
|
32
|
||||||
Total
current assets
|
317
|
271
|
||||||
Property
and Plant, Net
|
1,356
|
1,275
|
||||||
Intangible
Assets
|
2
|
2
|
||||||
Other
Assets
|
22
|
18
|
||||||
Regulatory
Assets
|
56
|
75
|
||||||
TOTAL
ASSETS
|
$ |
1,753
|
$ |
1,641
|
||||
LIABILITIES
AND STOCKHOLDERS' EQUITY
|
||||||||
Current
Liabilities:
|
||||||||
Current
maturities of long-term debt
|
$ |
-
|
$ |
50
|
||||
Short-term
debt
|
290
|
165
|
||||||
Accounts
and wages payable
|
40
|
54
|
||||||
Accounts
payable – affiliates
|
63
|
47
|
||||||
Taxes
accrued
|
3
|
3
|
||||||
Other
current liabilities
|
39
|
47
|
||||||
Total
current liabilities
|
435
|
366
|
||||||
Long-term
Debt, Net
|
148
|
148
|
||||||
Preferred
Stock Subject to Mandatory Redemption
|
18
|
18
|
||||||
Deferred
Credits and Other Liabilities:
|
||||||||
Accumulated
deferred income taxes, net
|
148
|
166
|
||||||
Accumulated
deferred investment tax credits
|
7
|
7
|
||||||
Regulatory
liabilities
|
198
|
206
|
||||||
Accrued
pension and other postretirement benefits
|
151
|
171
|
||||||
Other
deferred credits and liabilities
|
55
|
24
|
||||||
Total
deferred credits and other liabilities
|
559
|
574
|
||||||
Commitments
and Contingencies (Notes 2 and 8)
|
||||||||
Stockholders'
Equity:
|
||||||||
Common
stock, no par value, 20.0 shares authorized – 13.6 shares
outstanding
|
-
|
-
|
||||||
Preferred
stock not subject to mandatory redemption
|
19
|
19
|
||||||
Other
paid-in capital
|
429
|
415
|
||||||
Retained
earnings
|
145
|
99
|
||||||
Accumulated
other comprehensive income
|
-
|
2
|
||||||
Total
stockholders' equity
|
593
|
535
|
||||||
TOTAL
LIABILITIES AND STOCKHOLDERS' EQUITY
|
$ |
1,753
|
$ |
1,641
|
||||
CENTRAL
ILLINOIS LIGHT COMPANY
|
||||||||
CONSOLIDATED
STATEMENT OF CASH FLOWS
|
||||||||
(Unaudited)
(In millions)
|
||||||||
Six
Months Ended
|
||||||||
June
30,
|
||||||||
2007
|
2006
|
|||||||
Cash
Flows From Operating Activities:
|
||||||||
Net
income
|
$ |
47
|
$ |
25
|
||||
Adjustments
to reconcile net income to net cash
|
||||||||
provided
by operating activities:
|
||||||||
Depreciation
and amortization
|
37
|
40
|
||||||
Amortization
of debt issuance costs and premium/discounts
|
1
|
-
|
||||||
Deferred
income taxes and investment tax credits
|
(3 | ) | (3 | ) | ||||
Loss
on sale of noncore properties
|
-
|
6
|
||||||
Other
|
-
|
(1 | ) | |||||
Changes
in assets and liabilities:
|
||||||||
Receivables
|
(10 | ) |
53
|
|||||
Materials
and supplies
|
14
|
22
|
||||||
Accounts
and wages payable
|
16
|
(20 | ) | |||||
Taxes
accrued
|
(3 | ) | (17 | ) | ||||
Assets,
other
|
(7 | ) |
15
|
|||||
Liabilities,
other
|
(4 | ) | (5 | ) | ||||
Pension
and postretirement benefit obligations
|
1
|
4
|
||||||
Net
cash provided by operating activities
|
89
|
119
|
||||||
Cash
Flows From Investing Activities:
|
||||||||
Capital
expenditures
|
(127 | ) | (48 | ) | ||||
Proceeds
from sale of noncore properties
|
-
|
11
|
||||||
Changes
in money pool advances
|
42
|
-
|
||||||
Purchases
of emission allowances
|
-
|
(12 | ) | |||||
Sales
of emission allowances
|
-
|
1
|
||||||
Net
cash used in investing activities
|
(85 | ) | (48 | ) | ||||
Cash
Flows From Financing Activities:
|
||||||||
Dividends
on common stock
|
-
|
(50 | ) | |||||
Dividends
on preferred stock
|
(1 | ) | (1 | ) | ||||
Capital
issuance costs
|
-
|
(1 | ) | |||||
Short-term
debt, net
|
125
|
-
|
||||||
Changes
in money pool borrowings
|
-
|
(95 | ) | |||||
Redemptions,
repurchases, and maturities of long-term debt
|
(50 | ) |
-
|
|||||
Issuances
of long-term debt
|
-
|
96
|
||||||
Capital
contribution from parent
|
14
|
-
|
||||||
Net
cash provided by (used in) financing activities
|
88
|
(51 | ) | |||||
Net
change in cash and cash equivalents
|
92
|
20
|
||||||
Cash
and cash equivalents at beginning of year
|
3
|
2
|
||||||
Cash
and cash equivalents at end of period
|
$ |
95
|
$ |
22
|
||||
ILLINOIS
POWER COMPANY
|
|||||||||||||||
CONSOLIDATED
STATEMENT OF INCOME
|
|||||||||||||||
(Unaudited)
(In millions)
|
|||||||||||||||
Three
Months Ended
|
Six
Months Ended
|
||||||||||||||
June
30,
|
June
30,
|
||||||||||||||
2007
|
2006
|
2007
|
2006
|
||||||||||||
Operating
Revenues:
|
|||||||||||||||
Electric
|
$ |
280
|
$ |
271
|
$ |
552
|
$ |
513
|
|||||||
Gas
|
85
|
67
|
326
|
322
|
|||||||||||
Other
|
-
|
1
|
2
|
1
|
|||||||||||
Total
operating revenues
|
365
|
339
|
880
|
836
|
|||||||||||
Operating
Expenses:
|
|||||||||||||||
Purchased
power
|
178
|
171
|
367
|
348
|
|||||||||||
Gas
purchased for resale
|
56
|
36
|
241
|
237
|
|||||||||||
Other
operations and maintenance
|
63
|
61
|
122
|
120
|
|||||||||||
Depreciation
and amortization
|
19
|
18
|
40
|
37
|
|||||||||||
Amortization
of regulatory assets
|
4
|
-
|
8
|
-
|
|||||||||||
Taxes
other than income taxes
|
16
|
16
|
37
|
38
|
|||||||||||
Total
operating expenses
|
336
|
302
|
815
|
780
|
|||||||||||
Operating
Income
|
29
|
37
|
65
|
56
|
|||||||||||
Other
Income and Expenses:
|
|||||||||||||||
Miscellaneous
income
|
3
|
1
|
5
|
2
|
|||||||||||
Miscellaneous
expense
|
-
|
(1 | ) | (1 | ) | (2 | ) | ||||||||
Total
other income
|
3
|
-
|
4
|
-
|
|||||||||||
Interest
Charges
|
20
|
12
|
36
|
24
|
|||||||||||
Income
Before Income Taxes
|
12
|
25
|
33
|
32
|
|||||||||||
Income
Taxes
|
5
|
9
|
13
|
12
|
|||||||||||
Net
Income
|
7
|
16
|
20
|
20
|
|||||||||||
Preferred
Stock Dividends
|
-
|
-
|
1
|
1
|
|||||||||||
Net
Income Available to Common Stockholder
|
$ |
7
|
$ |
16
|
$ |
19
|
$ |
19
|
|||||||
ILLINOIS
POWER COMPANY
|
|||||||
CONSOLIDATED
BALANCE SHEET
|
|||||||
(Unaudited)
(In millions)
|
|||||||
June
30,
|
December
31,
|
||||||
2007
|
2006
|
||||||
ASSETS
|
|||||||
Current
Assets:
|
|||||||
Cash
and cash equivalents
|
$ |
143
|
$ |
-
|
|||
Accounts
receivable - trade (less allowance for doubtful
|
|||||||
accounts
of $11 and $3, respectively)
|
124
|
105
|
|||||
Unbilled
revenue
|
78
|
101
|
|||||
Accounts
receivable – affiliates
|
-
|
1
|
|||||
Materials
and supplies
|
93
|
122
|
|||||
Other
current assets
|
38
|
27
|
|||||
Total
current assets
|
476
|
356
|
|||||
Property
and Plant, Net
|
2,169
|
2,134
|
|||||
Investments
and Other Assets:
|
|||||||
Investment
in IP SPT
|
9
|
8
|
|||||
Goodwill
|
214
|
214
|
|||||
Other
assets
|
51
|
62
|
|||||
Regulatory
assets
|
368
|
401
|
|||||
Total
investments and other assets
|
642
|
685
|
|||||
TOTAL
ASSETS
|
$ |
3,287
|
$ |
3,175
|
|||
LIABILITIES
AND STOCKHOLDERS’ EQUITY
|
|||||||
Current
Liabilities:
|
|||||||
Current
maturities of long-term debt to IP SPT
|
$ |
51
|
$ |
51
|
|||
Short-term
debt
|
325
|
75
|
|||||
Borrowings
from money pool
|
-
|
43
|
|||||
Accounts
and wages payable
|
76
|
119
|
|||||
Accounts
payable – affiliates
|
51
|
67
|
|||||
Taxes
accrued
|
5
|
7
|
|||||
Other
current liabilities
|
65
|
72
|
|||||
Total
current liabilities
|
573
|
434
|
|||||
Long-term
Debt, Net
|
768
|
772
|
|||||
Long-term
Debt to IP SPT
|
47
|
92
|
|||||
Deferred
Credits and Other Liabilities:
|
|||||||
Regulatory
liabilities
|
90
|
110
|
|||||
Accrued
pension and other postretirement benefits
|
214
|
230
|
|||||
Accumulated
deferred income taxes
|
132
|
138
|
|||||
Other
deferred credits and other noncurrent liabilities
|
98
|
53
|
|||||
Total
deferred credits and other liabilities
|
534
|
531
|
|||||
Commitments
and Contingencies (Notes 2 and 8)
|
|||||||
Stockholders’
Equity:
|
|||||||
Common
stock, no par value, 100.0 shares authorized – 23.0 shares
outstanding
|
-
|
-
|
|||||
Other
paid-in-capital
|
1,194
|
1,194
|
|||||
Preferred
stock not subject to mandatory redemption
|
46
|
46
|
|||||
Retained
earnings
|
120
|
101
|
|||||
Accumulated
other comprehensive income
|
5
|
5
|
|||||
Total
stockholders’ equity
|
1,365
|
1,346
|
|||||
TOTAL
LIABILITIES AND STOCKHOLDERS’ EQUITY
|
$ |
3,287
|
$ |
3,175
|
|||
ILLINOIS
POWER COMPANY
|
|||||||
CONSOLIDATED
STATEMENT OF CASH FLOWS
|
|||||||
(Unaudited)
(In millions)
|
|||||||
Six
Months Ended
|
|||||||
June
30,
|
|||||||
2007
|
2006
|
||||||
Cash
Flows From Operating Activities:
|
|||||||
Net
income
|
$ |
20
|
$ |
20
|
|||
Adjustments
to reconcile net income to net cash
|
|||||||
provided
by operating activities:
|
|||||||
Depreciation
and amortization
|
42
|
15
|
|||||
Amortization
of debt issuance costs and premium/discounts
|
4
|
2
|
|||||
Deferred
income taxes
|
6
|
20
|
|||||
Changes
in assets and liabilities:
|
|||||||
Receivables
|
5
|
66
|
|||||
Materials
and supplies
|
29
|
31
|
|||||
Accounts
and wages payable
|
(40 | ) | (62 | ) | |||
Assets,
other
|
(7 | ) |
12
|
||||
Liabilities,
other
|
2
|
(24 | ) | ||||
Pension
and other postretirement benefit obligations
|
12
|
5
|
|||||
Net
cash provided by operating activities
|
73
|
85
|
|||||
Cash
Flows From Investing Activities:
|
|||||||
Capital
expenditures
|
(92 | ) | (82 | ) | |||
Other
|
(1 | ) |
-
|
||||
Net
cash used in investing activities
|
(93 | ) | (82 | ) | |||
Cash
Flows From Financing Activities:
|
|||||||
Dividends
on preferred stock
|
(1 | ) | (1 | ) | |||
Capital
issuance costs
|
-
|
(1 | ) | ||||
Short-term
debt, net
|
250
|
-
|
|||||
Changes
in money pool borrowings, net
|
(43 | ) | (21 | ) | |||
Redemptions,
repurchases and maturities of long-term debt
|
(43 | ) | (46 | ) | |||
Issuance
of long-term debt
|
-
|
75
|
|||||
Overfunding
of TFNs
|
-
|
(8 | ) | ||||
Net
cash provided by (used in) financing activities
|
163
|
(2 | ) | ||||
Net
change in cash and cash equivalents
|
143
|
1
|
|||||
Cash
and cash equivalents at beginning of year
|
-
|
-
|
|||||
Cash
and cash equivalents at end of period
|
$ |
143
|
$ |
1
|
|||
·
|
UE,
or Union Electric Company, also known as AmerenUE, operates a
rate-regulated electric generation, transmission and distribution
business, and a rate-regulated natural gas transmission and distribution
business in Missouri.
|
·
|
CIPS,
or Central Illinois Public Service Company, also known as AmerenCIPS,
operates a rate-regulated electric and natural gas transmission
and
distribution business in Illinois.
|
·
|
Genco,
or Ameren Energy Generating Company, operates a non-rate-regulated
electric generation business in Illinois and
Missouri.
|
·
|
CILCO,
or Central Illinois Light Company, also known as AmerenCILCO, is
a
subsidiary of CILCORP (a holding company). It operates a rate-regulated
electric and natural gas transmission and distribution business
and a
non-rate-regulated electric generation business (through its subsidiary
AERG), all in Illinois.
|
·
|
IP,
or Illinois Power Company, also known as AmerenIP, operates a
rate-regulated electric and natural gas transmission and distribution
business in Illinois.
|
Three
Months
|
Six
Months
|
||||||||||||||
2007
|
2006
|
2007
|
2006
|
||||||||||||
Operating
revenues
|
$ |
109
|
$ |
88
|
$ |
206
|
$ |
184
|
|||||||
Operating
income
|
51
|
42
|
105
|
98
|
|||||||||||
Net
income
|
32
|
26
|
66
|
60
|
Performance
Share Units
|
Restricted
Shares
|
|||||||||||||
Shares
|
Weighted-average Fair Value Per Unit |
Shares
|
Weighted-average
Fair Value Per Share
|
|||||||||||
Nonvested
at January 1,
2007
|
338,516
|
$ |
56.07
|
377,776
|
$ |
45.79
|
||||||||
Granted(a)
|
357,573
|
59.60
|
-
|
-
|
||||||||||
Dividends
|
-
|
-
|
7,849
|
49.56
|
||||||||||
Forfeitures
|
(9,667 | ) |
56.31
|
(5,841 | ) |
46.47
|
||||||||
Vested(b)
|
(11,566 | ) |
59.30
|
(70,391 | ) |
43.84
|
||||||||
Nonvested
at June 30,
2007
|
674,856
|
$ |
57.88
|
309,393
|
$ |
46.23
|
(a)
|
Includes
performance share units (share units) granted to certain executive
and
non-executive officers and other eligible employees in February
2007 under
the 2006 Plan.
|
(b)
|
Share
units vested due to attainment of retirement eligibility by certain
employees. Actual shares issued for retirement-eligible employees
will
vary depending on actual performance over the three-year measurement
period.
|
Three
Months
|
Six
Months
|
||||||||||||||
2007
|
2006
|
2007
|
2006
|
||||||||||||
Ameren(a)
|
$ |
13
|
$ |
14
|
$ |
20
|
$ |
25
|
|||||||
UE
|
-
|
-
|
(3
|
) | (2 | ) | |||||||||
Genco
|
8
|
7
|
15
|
15
|
|||||||||||
CILCORP(b)
|
1
|
6
|
3
|
11
|
|||||||||||
CILCO
|
(1 | ) |
3
|
-
|
6
|
(a)
|
Includes
amounts for Ameren registrant and nonregistrant subsidiaries and
intercompany eliminations.
|
(b)
|
Includes
allowances consumed that were recorded through purchase
accounting.
|
Three
Months
|
Six
Months
|
||||||||||||||
2007
|
2006
|
2007
|
2006
|
||||||||||||
Ameren
|
$ |
40
|
$ |
39
|
$ |
82
|
$ |
85
|
|||||||
UE
|
28
|
27
|
50
|
52
|
|||||||||||
CIPS
|
3
|
3
|
8
|
9
|
|||||||||||
CILCORP
|
3
|
2
|
7
|
6
|
|||||||||||
CILCO
|
3
|
2
|
7
|
6
|
|||||||||||
IP
|
6
|
7
|
17
|
18
|
·
|
Acceptance
without rate adjustment of the expiration of UE’s cost-based power supply
contract with EEI, which expired in December
2005.
|
·
|
Allowance
of the full cost of certain CTs purchased or built in the past
few years
to be included in UE’s rate base.
|
·
|
Establishment
of a regulatory tracking mechanism, through the use of a regulatory
liability account, for gains on sales of SO2
emission
allowances , net of SO2
premiums
incurred under the terms of coal procurement contracts, plus any
SO2
discounts received under such contracts. These deferred amounts
will
be addressed as part of the fuel expense calculation in UE’s next rate
case. The MoPSC allowed an annual base level of SO2
emission
allowance sales of up to $5 million, which UE can recognize in
its
statement of income.
|
·
|
Approval
of a regulatory tracking mechanism for pension and postretirement
benefit
costs.
|
·
|
Change
of income tax method associated with cost of property removal,
net of
salvage, to the normalization method of accounting, which reduced
income
tax expense in the calculation of UE’s electric rates and for financial
reporting purposes.
|
·
|
Establishment
of off-system sales base level of $230 million used in determining
UE’s revenue requirement.
|
·
|
Extension
of UE’s Callaway nuclear plant and fossil generation plant lives used
in
calculating depreciation expense for electric rates and financial
reporting purposes.
|
·
|
MoPSC
staff directed to review a possible loss in capacity sales as a
result of
the breach of the upper reservoir of the Taum Sauk pumped-storage
hydroelectric facility.
|
·
|
Establishment
of a requirement to fund low-income energy assistance and energy
conservation programs; half of such funding will be recoverable
through
rates to customers.
|
·
|
Denial
of UE’s request to implement a fuel and purchased power cost recovery
mechanism.
|
·
|
UE
agreed not to file a natural gas delivery rate case before March
15, 2010.
This agreement does not prevent UE from filing to recover infrastructure
costs through a statutory infrastructure system replacement surcharge
(ISRS) during this three-year rate moratorium. The return on equity
to be
used by UE for purposes of any future ISRS tariff filing is
10.0%.
|
·
|
Authorization
for UE to transition from four PGA rates to a single PGA rate for
all its
gas customers.
|
Total
Relief/Assistance to Ameren
Illinois
Customers
|
Ameren
Subsidiaries’ Funding(a)
|
Estimated
Ameren
Earnings Per Share
Impact(b)
|
|||||||||
2007
|
$ |
253,000,000
|
$ |
86,000,000
|
$ |
0.26
|
|||||
2008
|
132,000,000
|
37,000,000
|
0.11
|
||||||||
2009
|
97,000,000
|
25,000,000
|
0.07
|
||||||||
2010
|
6,000,000
|
2,000,000
|
0.01
|
||||||||
Total
|
$ |
488,000,000
|
$ |
150,000,000
|
$ |
0.45
|
(a)
|
Includes
a $4.5 million contribution in 2007 towards funding of a newly-created
IPA.
|
(b)
|
Includes
estimated cost of proposed forgiveness of outstanding customer
late
payment fees.
|
Period
|
Volume
|
June
1, 2008 – December 31, 2008
|
400
MW
|
January
1, 2009 – May 31, 2009
|
400
MW
|
June
1, 2009 – December 31, 2009
|
800
MW
|
January
1, 2010 – May 31, 2010
|
800
MW
|
June
1, 2010 – December 31, 2010
|
1,000
MW
|
January
1, 2011 – December 31, 2011
|
1,000
MW
|
January
1, 2012 – December 31, 2012
|
1,000
MW
|
$1.15
Billion Credit Facility(a)
|
Ameren
(Parent)
|
UE
|
Genco
|
Ameren
Total
|
|||||||||||
June
30, 2007:
|
|||||||||||||||
Average
daily borrowings outstanding during 2007
|
$ |
180
|
$ |
496
|
$ |
-
|
$ |
676
|
|||||||
Outstanding
short-term debt at period end
|
350
|
426
|
-
|
776
|
|||||||||||
Weighted-average
interest rate during 2007
|
5.82 | % | 5.72 | % |
-
|
5.75 | % | ||||||||
Peak
short-term borrowings during 2007
|
$ |
350
|
$ |
506
|
-
|
$ |
856
|
||||||||
Peak
interest rate during 2007
|
8.25 | % | 5.92 | % |
-
|
8.25 | % |
(a)
|
Includes
commercial paper programs at Ameren and UE supported by this
credit
facility.
|
2007
$500 Million Credit Facility
|
CIPS
|
CILCORP
(Parent)
|
CILCO
(Parent)
|
IP
|
AERG
|
Total
|
|||||||||||||||||
June
30, 2007:
|
|||||||||||||||||||||||
Average
daily borrowings outstanding during 2007
|
$ |
-
|
$ |
125
|
$ |
-
|
$ |
149
|
$ |
90
|
$ |
364
|
|||||||||||
Outstanding
short-term debt at period end
|
-
|
125
|
-
|
200
|
100
|
425
|
|||||||||||||||||
Weighted-average
interest rate during 2007
|
-
|
6.91 | % |
-
|
6.54 | % | 6.85 | % | 6.74 | % | |||||||||||||
Peak
short-term borrowings during 2007
|
$ |
-
|
$ |
125
|
$ |
-
|
$ |
200
|
$ |
100
|
$ |
425
|
|||||||||||
Peak
interest rate during 2007
|
-
|
7.04 | % |
-
|
6.64 | % | 7.02 | % | 7.04 | % | |||||||||||||
2006
$500 Million Credit Facility
|
CIPS
|
CILCORP
(Parent)
|
CILCO
(Parent)
|
IP
|
AERG
|
Total
|
|||||||||||||||||
June
30, 2007:
|
|||||||||||||||||||||||
Average
daily borrowings outstanding during 2007
|
$ |
78
|
$ |
44
|
$ |
45
|
$ |
50
|
$ |
78
|
$ |
295
|
|||||||||||
Outstanding
short-term debt at period end
|
135
|
50
|
75
|
125
|
115
|
500
|
|||||||||||||||||
Weighted-average
interest rate during 2007
|
6.48 | % | 6.79 | % | 6.11 | % | 6.55 | % | 6.85 | % | 6.58 | % | |||||||||||
Peak
short-term borrowings during 2007
|
$ |
135
|
$ |
50
|
$ |
75
|
$ |
125
|
$ |
115
|
$ |
500
|
|||||||||||
Peak
interest rate during 2007
|
6.64 | % | 7.04 | % | 6.47 | % | 6.64 | % | 8.25 | % | 8.25 | % |
Required
Interest
Coverage
Ratio(a)(b)
|
Actual
Interest
Coverage
Ratio
|
Bonds
Issuable(c)(d)
|
Required
Dividend
Coverage
Ratio(e)
|
Actual
Dividend
Coverage
Ratio
|
Preferred
Stock
Issuable
|
||||||||||
UE
|
≥2.0
|
3.9
|
$ |
1.982
|
≥2.5
|
43.9
|
$ |
1,405
|
|||||||
CIPS
|
≥2.0
|
3.8
|
178
|
≥1.5
|
2.1
|
211
|
|||||||||
CILCO
|
≥2.0(f)
|
11.3
|
84
|
≥2.5
|
36.5
|
370(g)
|
|||||||||
IP
|
≥2.0
|
3.3
|
258
|
≥1.5
|
1.8
|
205
|
(a) | Coverage required on the annual interest charges on mortgage bonds outstanding and to be issued. |
(b) | Coverage is not required in certain cases when additional mortgage bonds are issued on the basis of retired bonds. |
(c)
|
Amount
of bonds issuable based on either meeting required coverage
ratios or
unfunded property additions, whichever is more restrictive.
In addition to
these tests, UE, CIPS, CILCO and IP have the ability to issue
bonds based
upon retired bond capacity of $17 million, $3 million, $175
million,
and $914 million, respectively, for which no earnings coverage
test
is required.
|
(d)
|
Amounts
are net of future bonding capacity restrictions agreed to by
CIPS, CILCO
and IP under the 2007 $500 million credit facility and the
2006 $500
million credit facility entered into by these companies. See
Note 3 –
Credit Facilities and Liquidity for further
discussion.
|
(e)
|
Coverage
required on the annual interest charges on all long-term debt
(CIPS-only)
and the annual dividend on preferred stock outstanding and
to be issued,
as required in the respective company’s articles of incorporation. For
CILCO, this ratio must be met for a period of 12 consecutive
calendar
months within the 15 months immediately preceding the
issuance.
|
(f)
|
In
lieu of meeting the interest coverage ratio requirement, CILCO
may attempt
to meet an earnings requirement of at least 12% of the principal
amount of
all mortgage bonds outstanding and to be issued. For the three
months and
six months ended June 30, 2007, CILCO had earnings equivalent
to at least
43% of the principal amount of all mortgage bonds
outstanding.
|
(g)
|
See
Note 3 – Credit Facilities and Liquidity for a discussion regarding
a
restriction on the issuance of preferred stock by CILCO under
the
2007 500 million credit facility and the 2006 $500 million credit
facility.
|
Required
Interest
Coverage
Ratio
|
Actual
Interest
Coverage
Ratio
|
Required
Debt–to-
Capital
Ratio
|
Actual
Debt–to-
Capital
Ratio
|
|
Genco
(a)
|
≥1.75(b)
|
5.9
|
≤60%
|
52%
|
CILCORP(c)
|
≥2.2
|
3.3
|
≤67%
|
29%
|
(a)
|
Interest
coverage ratio relates to covenants regarding certain dividend,
principal
and interest payments on certain subordinated intercompany borrowings.
The
debt-to-capital ratio relates to a debt incurrence covenant,
which
requires an interest coverage ratio of 2.5 for the most recently
ended
four fiscal quarters.
|
(b)
|
Ratio
excludes amounts payable under Genco’s intercompany note to CIPS and must
be met for both the prior four fiscal quarters and for the four
succeeding
six-month periods.
|
(c)
|
CILCORP
must maintain the required interest coverage ratio and debt-to-capital
ratio in order to make any payment of dividends or intercompany
loans to
affiliates other than to its direct or indirect
subsidiaries.
|
Three
Months
|
Six
Months
|
||||||||||||||
2007
|
2006
|
2007
|
2006
|
||||||||||||
Ameren:(a)
|
|||||||||||||||
Miscellaneous
income:
|
|||||||||||||||
Interest
and dividend
income
|
$ |
14
|
$ |
8
|
$ |
25
|
$ |
11
|
|||||||
Allowance
for equity funds used
during construction
|
-
|
-
|
-
|
1
|
|||||||||||
Other
|
6
|
3
|
9
|
4
|
|||||||||||
Total
miscellaneous
income
|
$ |
20
|
$ |
11
|
$ |
34
|
$ |
16
|
|||||||
Miscellaneous
expense:
|
|||||||||||||||
Other
|
$ | (4 | ) | $ | (1 | ) | $ | (4 | ) | $ | (1 | ) | |||
Total
miscellaneous
expense
|
$ | (4 | ) | $ | (1 | ) | $ | (4 | ) | $ | (1 | ) | |||
UE:
|
|||||||||||||||
Miscellaneous
income:
|
|||||||||||||||
Interest
and dividend
income
|
$ |
8
|
$ |
8
|
$ |
15
|
$ |
10
|
|||||||
Allowance
for equity funds used
during construction
|
-
|
-
|
-
|
1
|
|||||||||||
Other
|
4
|
-
|
5
|
1
|
|||||||||||
Total
miscellaneous
income
|
$ |
12
|
$ |
8
|
$ |
20
|
$ |
12
|
|||||||
Miscellaneous
expense:
|
|||||||||||||||
Other
|
$ | (6 | ) | $ | (2 | ) | $ | (8 | ) | $ | (4 | ) | |||
Total
miscellaneous
expense
|
$ | (6 | ) | $ | (2 | ) | $ | (8 | ) | $ | (4 | ) | |||
CIPS:
|
|||||||||||||||
Miscellaneous
income:
|
|||||||||||||||
Interest
and dividend
income
|
$ |
4
|
$ |
4
|
$ |
8
|
$ |
8
|
|||||||
Other
|
1
|
-
|
-
|
1
|
|||||||||||
Total
miscellaneous
income
|
$ |
5
|
$ |
4
|
$ |
8
|
$ |
9
|
|||||||
Miscellaneous
expense:
|
|||||||||||||||
Other
|
$ | (1 | ) | $ |
-
|
$ | (1 | ) | $ | (1 | ) | ||||
Total
miscellaneous
expense
|
$ | (1 | ) | $ |
-
|
$ | (1 | ) | $ | (1 | ) |
Three
Months
|
Six
Months
|
||||||||||||||
2007
|
2006
|
2007
|
2006
|
||||||||||||
Genco:
|
|||||||||||||||
Miscellaneous
expense:
|
|||||||||||||||
Other
|
$ |
1
|
$ |
-
|
$ |
1
|
$ |
-
|
|||||||
Total
miscellaneous
expense
|
$ |
1
|
$ |
-
|
$ |
1
|
$ |
-
|
|||||||
CILCORP:
|
|||||||||||||||
Miscellaneous
income:
|
|||||||||||||||
Interest
and dividend
income
|
$ |
-
|
$ |
1
|
$ |
2
|
$ |
1
|
|||||||
Total
miscellaneous
income
|
$ |
-
|
$ |
1
|
$ |
2
|
$ |
1
|
|||||||
Miscellaneous
expense:
|
|||||||||||||||
Other
|
$ | (2 | ) | $ | (1 | ) | $ | (3 | ) | $ | (2 | ) | |||
Total
miscellaneous
expense
|
$ | (2 | ) | $ | (1 | ) | $ | (3 | ) | $ | (2 | ) | |||
CILCO:
|
|||||||||||||||
Miscellaneous
income:
|
|||||||||||||||
Interest and
dividend
income
|
$ |
1
|
$ |
-
|
$ |
2
|
$ |
-
|
|||||||
Total
miscellaneous
income
|
$ |
1
|
$ |
-
|
$ |
2
|
$ |
-
|
|||||||
Miscellaneous
expense:
|
|||||||||||||||
Other
|
$ | (2 | ) | $ | (1 | ) | $ | (3 | ) | $ | (2 | ) | |||
Total
miscellaneous
expense
|
$ | (2 | ) | $ | (1 | ) | $ | (3 | ) | $ | (2 | ) | |||
IP:
|
|||||||||||||||
Miscellaneous
income:
|
|||||||||||||||
Interest
and dividend
income
|
$ |
2
|
$ |
1
|
$ |
3
|
$ |
1
|
|||||||
Other
|
1
|
-
|
2
|
1
|
|||||||||||
Total
miscellaneous
income
|
$ |
3
|
$ |
1
|
$ |
5
|
$ |
2
|
|||||||
Miscellaneous
expense:
|
|||||||||||||||
Other
|
$ |
-
|
$ | (1 | ) | $ | (1 | ) | $ | (2 | ) | ||||
Total
miscellaneous
expense
|
$ |
-
|
$ | (1 | ) | $ | (1 | ) | $ | (2 | ) |
(a)
|
Includes
amounts for Ameren registrant and nonregistrant subsidiaries
and
intercompany eliminations.
|
Three
Months
|
Six
Months
|
||||||||||||||
Gains
( Losses)
|
2007
|
2006
|
2007
|
2006
|
|||||||||||
Ameren
|
$ |
8
|
$ |
1
|
$ |
13
|
$ | (1 | ) | ||||||
UE
|
(4 | ) |
-
|
(2 | ) |
2
|
|||||||||
Genco
|
-
|
-
|
-
|
1
|
|||||||||||
IP
|
-
|
(1 | ) |
-
|
(5 | ) |
Ameren(a)
|
UE
|
CIPS
|
Genco
|
CILCORP/
CILCO
|
IP
|
||||||||||||||||||
Derivative
instruments carrying value:
|
|||||||||||||||||||||||
Other
assets
|
$ |
83
|
$ |
9
|
$ |
1
|
$ |
-
|
$ |
5
|
$ |
-
|
|||||||||||
Other
deferred credits and
liabilities
|
14
|
4
|
-
|
2
|
1
|
-
|
|||||||||||||||||
Gains
(losses) deferred in Accumulated OCI:
|
|||||||||||||||||||||||
Power
forwards(b)
|
55
|
7
|
-
|
-
|
-
|
-
|
|||||||||||||||||
Interest
rate swaps(c)
|
3
|
-
|
-
|
3
|
-
|
-
|
|||||||||||||||||
Gas
swaps and futures
contracts(d)
|
3
|
-
|
1
|
-
|
4
|
-
|
|||||||||||||||||
SO2
futures
contracts
|
(1 | ) |
-
|
-
|
(1 | ) |
-
|
-
|
(a)
|
Includes
amounts for Ameren registrant and nonregistrant subsidiaries
and
intercompany eliminations.
|
(b)
|
Represents
the mark-to-market value for the hedged portion of electricity
price
exposure for periods of up to four years, including $38 million
over the
next year.
|
(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
gains associated with natural gas swaps and futures contracts.
The swaps
are a partial hedge of our natural gas requirements through March
2011.
|
Three
Months
|
Six
Months
|
||||||||||||||
Gains
(Losses)
|
2007
|
2006
|
2007
|
2006
|
|||||||||||
SO2
options and
swaps:
|
|||||||||||||||
Ameren
|
$ |
2
|
$ | (2 | ) | $ |
6
|
$ | (3 | ) | |||||
UE
|
1
|
(1 | ) |
5
|
(2 | ) | |||||||||
Genco
|
1
|
(1 | ) |
1
|
(5 | ) | |||||||||
Coal
options:
|
|||||||||||||||
Ameren
|
1
|
(1 | ) |
2
|
(1 | ) | |||||||||
UE
|
1
|
(1 | ) |
2
|
(1 | ) | |||||||||
Heating
oil options:
|
|||||||||||||||
Ameren
|
-
|
-
|
3
|
-
|
|||||||||||
Nonhedge
power swaps and forwards:
|
|||||||||||||||
Ameren
|
(5 | ) |
-
|
(4 | ) |
-
|
|||||||||
UE
|
(4 | ) |
-
|
(4 | ) |
-
|
|||||||||
Nonhedge
gas futures:
|
|||||||||||||||
Ameren
|
2
|
-
|
2
|
-
|
|||||||||||
UE
|
2
|
-
|
2
|
-
|
Three
Months
|
Six
Months
|
|||
2007
|
2006
|
2007
|
2006
|
|
Genco
sales to
Marketing
Company(a)
|
-
|
5,296
|
-
|
10,887
|
Marketing
Company
sales
to CIPS(a)
|
-
|
2,997
|
-
|
6,076
|
Genco
sales to
Marketing
Company(b)
|
3,838
|
-
|
7,957
|
-
|
AERG
sales to
Marketing
Company(b)
|
1,154
|
-
|
2,642
|
-
|
Marketing
Company
sales
to CIPS(c)
|
562
|
-
|
1,181
|
-
|
Marketing
Company
sales
to CILCO(c)
|
285
|
-
|
573
|
-
|
Marketing
Company
sales
to IP(c)
|
874
|
-
|
1,700
|
-
|
(a)
|
These
agreements expired or terminated on December 31,
2006.
|
(b)
|
In
December 2006, Genco and Marketing Company, and AERG and Marketing
Company, entered into new power supply agreements whereby Genco
and AERG
sell and Marketing Company purchases all the capacity available
from
Genco’s and AERG’s generation fleets and such amount of associated energy
commencing on January 1, 2007.
|
(c)
|
In
accordance with the January 2006 ICC order, discussed in Note
2 – Rate and
Regulatory Matters, an auction was held in September 2006 to
procure power
for CIPS, CILCO and IP after their previous power supply contracts
expired
on December 31, 2006. Through the auction, Marketing Company
contracted
with CIPS, CILCO and IP to provide power for their customers.
See also
Note 3 – Rate and Regulatory Matters under Part II, Item 8 of the Form
10-K for further details of the power procurement auction in
Illinois. See
Note 2 – Rate and Regulatory Matters for a discussion of potential future
changes in the Illinois power procurement process as a result
of the
electric settlement agreement reached among key stakeholders
in July
2007.
|
Three
Months
|
Six
Months
|
|
UE
sales to Genco
|
2,639
|
5,434
|
Genco
sales to UE
|
1,111
|
1,717
|
Three
Months
|
Six
Months
|
|
UE
|
$25
|
$58
|
Genco
|
5
|
17
|
Total
|
$30
|
$75
|
Three
Months
|
Six
Months
|
||||||||||
Agreement
|
UE
|
CIPS
|
Genco
|
CILCORP(a)
|
IP
|
UE
|
CIPS
|
Genco
|
CILCORP(a)
|
IP
|
Operating
Revenues:
|
|||||||||||||||||||||||||||||||||||||||||
Genco
and AERG power supply agreements
|
2007
|
$ | (b) | $ | (b) | $ |
182
|
$ |
62
|
$ | (b) | $ | (b) | $ | (b) | $ |
393
|
$ |
134
|
$ | (b) | ||||||||||||||||||||
with
Marketing Company
|
|||||||||||||||||||||||||||||||||||||||||
Ancillary
service agreement with CIPS, CILCO and IP
|
2007
|
4
|
(b)
|
(b)
|
(b)
|
(b)
|
8
|
(b)
|
(b)
|
(b)
|
(b)
|
||||||||||||||||||||||||||||||
|
|||||||||||||||||||||||||||||||||||||||||
Power
supply agreement with Marketing Company -
|
|||||||||||||||||||||||||||||||||||||||||
expired
December 31, 2006
|
2006
|
(b)
|
(b)
|
194
|
1
|
(b)
|
(b)
|
(b)
|
389
|
5
|
(b)
|
||||||||||||||||||||||||||||||
|
|||||||||||||||||||||||||||||||||||||||||
UE
and Genco gas
|
2007
|
(c)
|
(b)
|
(b)
|
(b)
|
(b)
|
(c)
|
(b)
|
(b)
|
(b)
|
(b)
|
||||||||||||||||||||||||||||||
transportation
agreement
|
2006
|
(c)
|
(b)
|
(b)
|
(b)
|
(b)
|
(c)
|
(b)
|
(b)
|
(b)
|
(b)
|
||||||||||||||||||||||||||||||
JDA
– terminated
December
31, 2006
|
2006
|
49
|
(b)
|
27
|
(b)
|
(b)
|
121
|
(b)
|
46
|
(b)
|
(b)
|
||||||||||||||||||||||||||||||
Total
Operating Revenues
|
2007 | $ | 4 | $ |
(b)
|
$ | 182 | $ |
62
|
$ |
(b)
|
$ | 8 | $ |
(b)
|
$ | 393 | $ |
134
|
$ |
(b)
|
||||||||||||||||||||
2006
|
49
|
(b)
|
221
|
1
|
(b)
|
121
|
(b)
|
435
|
5
|
(b)
|
|||||||||||||||||||||||||||||||
Fuel
and Purchased Power:
|
|||||||||||||||||||||||||||||||||||||||||
CIPS,
CILCO and IP agreements with Marketing
|
2007
|
$ | (b) | $ |
36
|
$ | (b) | $ |
19
|
$ |
57
|
$ | (b) | $ |
78
|
$ | (b) | $ |
38
|
$ |
112
|
||||||||||||||||||||
Company
(auction)
|
|||||||||||||||||||||||||||||||||||||||||
Ancillary
service agreement with UE
|
2007
|
(b)
|
2
|
(b)
|
(c)
|
2
|
(b)
|
3
|
(b)
|
1
|
4
|
||||||||||||||||||||||||||||||
Ancillary
service agreement with Marketing Company
|
2007
|
(b)
|
1
|
(b)
|
(c)
|
1
|
(b)
|
2
|
(b)
|
1
|
2
|
||||||||||||||||||||||||||||||
|
|||||||||||||||||||||||||||||||||||||||||
JDA
– terminated
December
31, 2006
|
2006
|
27
|
(b)
|
49
|
(b)
|
(b)
|
46
|
(b)
|
121
|
(b)
|
(b)
|
||||||||||||||||||||||||||||||
Power
supply agreement with Marketing Company -
|
|||||||||||||||||||||||||||||||||||||||||
expired
December 31, 2006
|
2006
|
(b)
|
111
|
(b)
|
(c)
|
(b)
|
(b)
|
219
|
(b)
|
(c)
|
(b)
|
||||||||||||||||||||||||||||||
|
|||||||||||||||||||||||||||||||||||||||||
Executory
tolling agreement
|
2007
|
(b)
|
(b)
|
(b)
|
8
|
(b)
|
(b)
|
(b)
|
(b)
|
20
|
(b)
|
||||||||||||||||||||||||||||||
with
Medina Valley
|
2006
|
(b)
|
(b)
|
(b)
|
7
|
(b)
|
(b)
|
(b)
|
(b)
|
20
|
(b)
|
||||||||||||||||||||||||||||||
UE and Genco gas | 2007 |
(b)
|
(b)
|
(c)
|
(b) |
(b)
|
(b)
|
(b)
|
(c)
|
(b)
|
(b)
|
||||||||||||||||||||||||||||||
transportation
agreement
|
2006 |
(b)
|
(b)
|
(c)
|
(b) |
(b)
|
(b)
|
(b)
|
(c)
|
(b) |
(b)
|
||||||||||||||||||||||||||||||
Total
Fuel and Purchased
|
2007 |
$
(b)
|
$ |
39
|
$ |
(c)
|
$ | 27 | $ |
60
|
$ (b)
|
$ |
83
|
$
(c)
|
$ | 60 | $ |
118
|
|||||||||||||||||||||||
Power | 2006 |
27
|
111
|
49
|
7
|
(b)
|
46
|
219
|
121
|
20
|
(b)
|
Three
Months
|
Six
Months
|
Agreement
|
UE
|
CIPS
|
Genco
|
CILCORP(a) |
IP
|
UE
|
CIPS
|
Genco
|
CILCORP(a) |
IP
|
|||||||||||||||||||||||||||||||
Other
Operating Expense:
|
|||||||||||||||||||||||||||||||||||||||||
Ameren
Services support
|
2007
|
$ |
32
|
$ |
11
|
$ |
6
|
$ |
12
|
$ |
17
|
$ |
68
|
$ |
23
|
$ |
12
|
$ |
25
|
$ |
36
|
||||||||||||||||||||
services
agreement
|
2006
|
36
|
13
|
6
|
13
|
19
|
69
|
24
|
11
|
25
|
36
|
||||||||||||||||||||||||||||||
Ameren
Energy support
|
2007
|
2
|
(b)
|
(c)
|
(b)
|
(b)
|
5
|
(b)
|
(c)
|
(b)
|
(b)
|
||||||||||||||||||||||||||||||
services
agreement
|
2006
|
2
|
(b)
|
(c)
|
(b)
|
(b)
|
4
|
(b)
|
1
|
(b)
|
(b)
|
||||||||||||||||||||||||||||||
AFS
support services
|
2007
|
1
|
1
|
(c)
|
(c)
|
1
|
3
|
1
|
1
|
1
|
1
|
||||||||||||||||||||||||||||||
agreement |
2006
|
1
|
1
|
(c)
|
1
|
(c)
|
2
|
1
|
1
|
1
|
1
|
||||||||||||||||||||||||||||||
Insurance
premiums
|
2007
|
5
|
(b)
|
1
|
1
|
(b)
|
9
|
(b)
|
2
|
1
|
(b)
|
||||||||||||||||||||||||||||||
Total
Other Operating
|
2007
|
$ |
40
|
$ |
12
|
$ |
7
|
$ |
13
|
$ |
18
|
$ |
85
|
$ |
24
|
$ |
15
|
$ |
27
|
$ |
37
|
||||||||||||||||||||
Expenses |
2006
|
39
|
14
|
6
|
14
|
19
|
75
|
25
|
13
|
26
|
37
|
||||||||||||||||||||||||||||||
Interest
expense (income) from money pool borrowings
|
2007
|
$ |
-
|
$ | (c) | $ |
2
|
$ | (c) | $ | (c) | $ |
-
|
$ | (c) | $ |
4
|
$ | (c) | $ | (c) | ||||||||||||||||||||
(advances)
|
2006
|
(c)
|
(1) |
3
|
1
|
(c)
|
(c)
|
(1) |
5
|
3
|
1
|
(a)
|
Amounts
represent CILCORP and CILCO
activity.
|
(b)
|
Not
applicable.
|
(c) | Amount less than $1 million. |
Type
and Source of Coverage
|
Maximum
Coverages
|
Maximum
Assessments for Single Incidents
|
|||||
Public
liability:
|
|||||||
American
Nuclear
Insurers
|
300
|
-
|
|||||
Pool
participation
|
10,461 | (a) | 101 | (b) | |||
$ | 10,761 | (c) | $ |
101
|
|||
Nuclear
worker liability:
|
|||||||
American
Nuclear
Insurers
|
$ | 300 | (d) | $ |
4
|
||
Property
damage:
|
|||||||
Nuclear
Electric Insurance
Ltd.
|
$ | 2,750 | (e) | $ |
24
|
||
Replacement
power:
|
|||||||
Nuclear
Electric Insurance
Ltd.
|
$ | 490 | (f) | $ |
9
|
(a)
|
Provided
through mandatory participation in an industry-wide retrospective
premium
assessment program.
|
(b)
|
Retrospective
premium under the Price-Anderson liability provisions of the
Atomic Energy
Act of 1954, as amended. This is subject to retrospective assessment
with respect to a covered loss in excess of $300 million from
an incident
at any licensed U.S. commercial reactor, payable at $15 million
per year.
|
(c)
|
Limit
of liability for each incident under Price-Anderson. This limit
is subject
to change to account for the effects of inflation and changes
in the
number of licensed reactors.
|
(d)
|
Industry
limit for potential liability for worker tort claims filed for
bodily
injury caused by a nuclear energy accident. Effective January
1, 1998,
this program was modified to provide coverage to all workers
whose
nuclear-related employment began on or after the commencement
date of
reactor operations.
|
(e)
|
Provides
for $500 million in property damage and decontamination, excess
property
insurance, and premature decommissioning coverage up to $2.25 billion
for losses in excess of the $500 million primary
coverage.
|
(f)
|
Provides
the replacement power cost insurance in the event of a prolonged
accidental outage at a nuclear plant. 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.
|
2007
|
2008
|
2009
|
2010
|
2011
|
Thereafter(a)
|
||||||||||||||||||
Ameren(b)
|
$ |
351
|
$ |
495
|
$ |
343
|
$ |
227
|
$ |
200
|
$ |
1,961
|
|||||||||||
UE
|
41
|
71
|
51
|
32
|
26
|
56
|
|||||||||||||||||
CIPS
|
64
|
110
|
78
|
55
|
39
|
69
|
|||||||||||||||||
Genco
|
15
|
19
|
8
|
8
|
8
|
13
|
|||||||||||||||||
CILCORP/CILCO
|
88
|
127
|
84
|
47
|
56
|
839 | (c) | ||||||||||||||||
IP
|
137
|
161
|
119
|
84
|
70
|
983 | (c) |
(a)
|
Commitments
for natural gas are until 2017.
|
(b)
|
Includes
amounts for Ameren registrant and nonregistrant subsidiaries
and
intercompany eliminations.
|
(c)
|
Commitments
for natural gas purchases for CILCO and IP include projected
synthetic
natural gas purchases pursuant to a 20-year supply contract beginning
in
April 2011.
|
2007
|
2008
|
2009
|
2010
|
2011
|
Thereafter(a)
|
||||||||||||||||||
Ameren/UE
|
$ |
51
|
$ |
81
|
$ |
37
|
$ |
113
|
$ |
33
|
$ |
139
|
(a)
|
Commitments
for nuclear fuel are until 2020.
|
2007
|
2008
– 2011
|
2012
- 2016
|
Total
|
|
UE(a)
|
$
110
|
$ 630-830
|
$ 910-1,180
|
$ 1,650-2,120
|
Genco
|
110
|
820-1,060
|
180-
260
|
1,110-1,430
|
CILCO
(AERG)
|
100
|
185-240
|
95-
140
|
380-480
|
EEI
|
10
|
185-240
|
165-
220
|
360-470
|
Ameren
|
$
330
|
$ 1,820-2,370
|
$ 1,350-1,800
|
$ 3,500-4,500
|
(a)
|
UE’s
expenditures are expected to be recoverable in rates over
time.
|
SO2(a)
|
NOx(b)
|
Book
Value
|
|
UE
|
1.633
|
21,994
|
$ 58
|
Genco
|
0.637
|
14,746
|
64
|
CILCO
(AERG)
|
0.304
|
3,419
|
2
|
EEI
|
0.300
|
4,690
|
9
|
Ameren
|
2.874
|
44,849
|
206(c)
|
(a)
|
Vintages
are from 2007 to 2016. Each company possesses additional allowances
for
use in periods beyond 2016. Units are in millions of SO2
allowances (currently one allowance equals one ton
emitted).
|
(b)
|
Vintages
are from 2007 to 2008. Units are in NOx allowances (one
allowance equals one ton emitted).
|
(c)
|
Includes
value assigned to AERG and EEI allowances as a result of purchase
accounting of $73 million.
|
·
|
at
least 2% by June 1, 2008;
|
·
|
at
least 4% by June 1, 2009, increasing by at least 1% each year
thereafter
through June 1, 2015; and
|
·
|
increasing
by at least 1.5% each year after June 1, 2015 to at least 25%
by June 1,
2025.
|
Specifically
Named as Defendant
|
|||||||
Total(a)
|
Ameren
|
UE
|
CIPS
|
Genco
|
CILCO
|
IP
|
|
Filed
|
334
|
31
|
185
|
141
|
2
|
45
|
159
|
Settled
|
112
|
-
|
57
|
47
|
-
|
17
|
57
|
Dismissed
|
151
|
27
|
98
|
51
|
2
|
9
|
69
|
Pending
|
71
|
4
|
30
|
43
|
-
|
19
|
33
|
(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.
|
Three
Months
|
Six
Months
|
||||||||||||||
2007
|
2006
|
2007
|
2006
|
||||||||||||
Ameren:(a)
|
|||||||||||||||
Net
income
|
$ |
143
|
$ |
123
|
$ |
266
|
$ |
193
|
|||||||
Unrealized
gain (loss) on derivative hedging instruments, net of taxes
(benefit)
of $12, $5, $(3) and $(5), respectively
|
23
|
9
|
(5 | ) | (8 | ) | |||||||||
Reclassification
adjustments for (gain) included in net income, net of
taxes
of $2, $-, $9 and $2, respectively
|
(2 | ) | (1 | ) | (15 | ) | (4 | ) | |||||||
Adjustment
to pension and benefit obligation, net of taxes (benefit) of
$(1),
$-, $(2) and $-, respectively
|
(2 | ) |
-
|
-
|
-
|
||||||||||
Total
comprehensive income, net
of taxes
|
$ |
162
|
$ |
131
|
$ |
246
|
$ |
181
|
|||||||
UE:
|
|||||||||||||||
Net
income
|
$ |
81
|
$ |
92
|
$ |
119
|
$ |
143
|
|||||||
Unrealized
gain (loss) on derivative hedging instruments, net of taxes
(benefit)
of $2, $(1), $(1) and $(3), respectively
|
4
|
(1 | ) | (1 | ) | (5 | ) | ||||||||
Reclassification
adjustments for (gain) loss included in net income, net of
taxes
(benefit) of $(1) , $-, $1 and $-, respectively
|
1
|
1
|
(2 | ) |
1
|
||||||||||
Total
comprehensive income, net of taxes
|
$ |
86
|
$ |
92
|
$ |
116
|
$ |
139
|
Three
Months
|
Six
Months
|
||||||||||||||
2007
|
2006
|
2007
|
2006
|
||||||||||||
CIPS:
|
|||||||||||||||
Net
income
|
$ |
5
|
$ |
15
|
$ |
16
|
$ |
14
|
|||||||
Unrealized
(loss) on derivative hedging instruments, net of taxes (benefit)
of
$-, $(1), $- and $(3), respectively
|
(1 | ) | (1 | ) |
-
|
(4 | ) | ||||||||
Reclassification
adjustments for (gain) included in net income, net of
taxes
of $-, $-, $- and $1, respectively
|
-
|
-
|
-
|
(1 | ) | ||||||||||
Total
comprehensive income, net
of taxes
|
$ |
4
|
$ |
14
|
$ |
16
|
$ |
9
|
|||||||
Genco:
|
|||||||||||||||
Net
income
|
$ |
17
|
$ |
2
|
$ |
60
|
$ |
8
|
|||||||
Unrealized
(loss) on derivative hedging instruments, net of taxes (benefit)
of
$-, $-, $(1) and $-, respectively
|
-
|
-
|
(2 | ) | (1 | ) | |||||||||
Reclassification
adjustments for loss included in net income, net of taxes
of
$-, $-, $- and $-, respectively
|
-
|
-
|
-
|
1
|
|||||||||||
Adjustment
to pension and benefit obligation, net of taxes (benefit) of
$(2),
$-, $(2) and $-, respectively
|
(3 | ) |
-
|
(2 | ) |
-
|
|||||||||
Total
comprehensive income, net of taxes
|
$ |
14
|
$ |
2
|
$ |
56
|
$ |
8
|
|||||||
CILCORP:
|
|||||||||||||||
Net
income
|
$ |
12
|
$ |
1
|
$ |
32
|
$ |
9
|
|||||||
Unrealized
gain (loss) on derivative hedging instruments, net of taxes
(benefit)
of $(2), $(2), $- and $(10), respectively
|
(2 | ) | (3 | ) |
1
|
(15 | ) | ||||||||
Reclassification
adjustments for (gain) loss included in net income, net of
taxes
(benefit) of $(1), $-, $1 and $-, respectively
|
1
|
-
|
(2 | ) |
-
|
||||||||||
Adjustment
to pension and benefit obligation, net of taxes of $(1), $-,
$-
and
$-, respectively
|
(1 | ) |
-
|
-
|
-
|
||||||||||
Total
comprehensive income
(loss), net of taxes
|
$ |
10
|
$ | (2 | ) | $ |
31
|
$ | (6 | ) | |||||
CILCO:
|
|||||||||||||||
Net
income
|
$ |
21
|
$ |
8
|
$ |
47
|
$ |
25
|
|||||||
Unrealized
gain (loss) on derivative hedging instruments, net of taxes
(benefit)
of $(2), $(2), $- and $(10), respectively
|
(2 | ) | (3 | ) |
1
|
(15 | ) | ||||||||
Reclassification
adjustments for (gain) included in net income, net of
taxes
of $-, $-, $1 and $-, respectively
|
-
|
-
|
(3 | ) |
-
|
||||||||||
Total
comprehensive income, net of taxes
|
$ |
19
|
$ |
5
|
$ |
45
|
$ |
10
|
|||||||
IP:
|
|||||||||||||||
Net
income
|
$ |
7
|
$ |
16
|
$ |
20
|
$ |
20
|
|||||||
Unrealized
gain on derivative hedging instruments, net of taxes of $-, $1,
$-
and $3, respectively
|
-
|
1
|
-
|
4
|
|||||||||||
Reclassification
adjustments for (gain) included in net income, net of
taxes
of $-, $1, $- and $3, respectively
|
-
|
(1 | ) |
-
|
(4 | ) | |||||||||
Total
comprehensive income, net of taxes
|
$ |
7
|
$ |
16
|
$ |
20
|
$ |
20
|
(a)
|
Includes
amounts for Ameren registrant and nonregistrant subsidiaries
and
intercompany eliminations.
|
Pension
Benefits(a)
|
Postretirement
Benefits(a)
|
||||||||||||||||||||||||||||||
Three
Months
|
Six
Months
|
Three
Months
|
Six
Months
|
||||||||||||||||||||||||||||
2007
|
2006
|
2007
|
2006
|
2007
|
2006
|
2007
|
2006
|
||||||||||||||||||||||||
Service
cost
|
$ |
15
|
$ |
15
|
$ |
31
|
$ |
31
|
$ |
4
|
$ |
5
|
$ |
10
|
$ |
11
|
|||||||||||||||
Interest
cost
|
45
|
43
|
90
|
86
|
17
|
15
|
36
|
33
|
|||||||||||||||||||||||
Expected
return on plan assets
|
(51 | ) | (49 | ) | (103 | ) | (98 | ) | (13 | ) | (11 | ) | (26 | ) | (23 | ) | |||||||||||||||
Amortization
of:
|
|||||||||||||||||||||||||||||||
Transition
obligation
|
-
|
-
|
-
|
-
|
1
|
1
|
1
|
1
|
|||||||||||||||||||||||
Prior
service cost
(benefit)
|
3
|
3
|
6
|
5
|
(2 | ) | (2 | ) | (4 | ) | (3 | ) | |||||||||||||||||||
Actuarial
loss
|
5
|
10
|
11
|
21
|
5
|
7
|
12
|
17
|
|||||||||||||||||||||||
Net
periodic benefit cost
|
$ |
17
|
$ |
22
|
$ |
35
|
$ |
45
|
$ |
12
|
$ |
15
|
$ |
29
|
$ |
36
|
(a)
|
Includes
amounts for Ameren registrant and nonregistrant
subsidiaries.
|
Pension
Costs
|
Postretirement
Costs
|
||||||||||||||||||||||||||||||
Three
Months
|
Six
Months
|
Three
Months
|
Six
Months
|
||||||||||||||||||||||||||||
2007
|
2006
|
2007
|
2006
|
2007
|
2006
|
2007
|
2006
|
||||||||||||||||||||||||
Ameren
|
$ |
17
|
$ |
22
|
$ |
35
|
$ |
45
|
$ |
12
|
$ |
15
|
$ |
29
|
$ |
36
|
|||||||||||||||
UE
|
10
|
13
|
20
|
26
|
6
|
8
|
15
|
19
|
|||||||||||||||||||||||
CIPS
|
2
|
3
|
4
|
6
|
1
|
2
|
3
|
4
|
|||||||||||||||||||||||
Genco
|
1
|
1
|
2
|
3
|
1
|
1
|
2
|
2
|
|||||||||||||||||||||||
CILCORP
|
2
|
3
|
5
|
6
|
1
|
1
|
3
|
4
|
|||||||||||||||||||||||
IP
|
1
|
2
|
3
|
4
|
3
|
3
|
6
|
7
|
|||||||||||||||||||||||
EEI
|
1
|
-
|
1
|
-
|
-
|
-
|
-
|
-
|
(a)
|
Includes
amounts for Ameren registrant and nonregistrant
subsidiaries.
|
Three
Months
|
Missouri
Regulated
|
Illinois
Regulated
|
Non-rate-regulated
Generation
|
Other
|
Intersegment
Eliminations
|
Consolidated
|
|||||||||||||||||
2007:
|
|||||||||||||||||||||||
External
revenues
|
$ |
686
|
$ |
747
|
$ |
290
|
$ |
-
|
$ |
-
|
$ |
1,723
|
|||||||||||
Intersegment
revenues
|
11
|
6
|
124
|
10
|
(151 | ) |
-
|
||||||||||||||||
Net
income(a)
|
66
|
19
|
56
|
2
|
-
|
143
|
|||||||||||||||||
2006:
|
|||||||||||||||||||||||
External
revenues
|
$ |
652
|
$ |
681
|
$ |
208
|
$ |
9
|
$ |
-
|
$ |
1,550
|
|||||||||||
Intersegment
revenues
|
58
|
6
|
191
|
6
|
(261 | ) |
-
|
||||||||||||||||
Net
income(a)
|
78
|
33
|
13
|
(1 | ) |
-
|
123
|
||||||||||||||||
Six
Months
|
|||||||||||||||||||||||
2007:
|
|||||||||||||||||||||||
External
revenues
|
$ |
1,324
|
$ |
1,801
|
$ |
608
|
$ |
9
|
$ |
-
|
$ |
3,742
|
|||||||||||
Intersegment
revenues
|
23
|
13
|
257
|
20
|
(313 | ) |
-
|
||||||||||||||||
Net
income(a)
|
89
|
48
|
126
|
3
|
-
|
266
|
|||||||||||||||||
2006:
|
|||||||||||||||||||||||
External
revenues
|
$ |
1,210
|
$ |
1,665
|
$ |
447
|
$ |
28
|
$ |
-
|
$ |
3,350
|
|||||||||||
Intersegment
revenues
|
136
|
8
|
382
|
18
|
(544 | ) |
-
|
||||||||||||||||
Net
income (loss)(a)
|
113
|
42
|
40
|
(2 | ) |
-
|
193
|
||||||||||||||||
As
of June 30, 2007:
|
|||||||||||||||||||||||
Total
assets
|
$ |
10,738
|
$ |
6,370
|
$ |
3,838
|
$ |
1,064
|
$ | (1,479 | ) | $ |
20,531
|
||||||||||
As
of December 31, 2006:
|
|||||||||||||||||||||||
Total
assets
|
10,251
|
6,226
|
3,612
|
1,161
|
(1,672 | ) |
19,578
|
(a)
|
Represents
net income available to common shareholders; 100% of CILCO’s preferred
stock dividends are included in the Illinois Regulated
segment.
|
Three
Months
|
Missouri
Regulated
|
Other
(a)
|
Consolidated
UE
|
||||||||
2007:
|
|||||||||||
Revenues
|
$ |
697
|
$ |
-
|
$ |
697
|
|||||
Net
income(b)
|
66
|
13
|
79
|
||||||||
2006:
|
|||||||||||
Revenues
|
$ |
710
|
$ |
-
|
$ |
710
|
|||||
Net
income(b)
|
78
|
12
|
90
|
||||||||
Six
Months
|
|||||||||||
2007:
|
|||||||||||
Revenues
|
$ |
1,347
|
$ |
-
|
$ |
1,347
|
|||||
Net
income(b)
|
89
|
27
|
116
|
||||||||
2006:
|
|||||||||||
Revenues
|
$ |
1,346
|
$ |
-
|
$ |
1,346
|
|||||
Net
income(b)
|
113
|
27
|
140
|
||||||||
As
of June 30, 2007:
|
|||||||||||
Total
assets
|
$ |
10,738
|
$ |
29
|
$ |
10,767
|
|||||
As
of December 31, 2006:
|
|||||||||||
Total
assets
|
10,251
|
36
|
10,287
|
(a)
|
Includes
40% interest in EEI and other non-rate-regulated
activities.
|
(b)
|
Represents
net income available to the common shareholder
(Ameren).
|
Three
Months
|
Illinois
Regulated
|
Non-rate-regulated
Generation
|
CILCORP
Other
|
Intersegment
Eliminations
|
Consolidated
CILCORP
|
||||||||||||||
2007:
|
|||||||||||||||||||
External
revenues
|
$ |
161
|
$ |
62
|
$ |
-
|
$ |
-
|
$ |
223
|
|||||||||
Intersegment
revenues
|
-
|
1
|
-
|
(1 | ) |
-
|
|||||||||||||
Net
income(a)
|
7
|
5
|
-
|
-
|
12
|
||||||||||||||
2006:
|
|||||||||||||||||||
External
revenues
|
$ |
137
|
$ |
9
|
$ |
-
|
$ |
-
|
$ |
146
|
|||||||||
Intersegment
revenues
|
-
|
44
|
-
|
(44 | ) |
-
|
|||||||||||||
Net
income(a)
|
3
|
1
|
(3 | ) |
-
|
1
|
|||||||||||||
Six
Months
|
|||||||||||||||||||
2007:
|
|||||||||||||||||||
External
revenues
|
$ |
395
|
$ |
138
|
$ |
-
|
$ |
-
|
$ |
533
|
|||||||||
Intersegment
revenues
|
-
|
2
|
-
|
(2 | ) |
-
|
|||||||||||||
Net
income(a)
|
14
|
18
|
-
|
-
|
32
|
||||||||||||||
2006:
|
|||||||||||||||||||
External
revenues
|
$ |
370
|
$ |
18
|
$ |
-
|
$ |
-
|
$ |
388
|
|||||||||
Intersegment
revenues
|
-
|
85
|
-
|
(85 | ) |
-
|
|||||||||||||
Net
income(a)
|
11
|
1
|
(3 | ) |
-
|
9
|
|||||||||||||
As
of June 30, 2007:
|
|||||||||||||||||||
Total
assets(b)
|
$ |
1,174
|
$ |
1,376
|
$ |
4
|
$ | (194 | ) | $ |
2,360
|
||||||||
As
of December 31, 2006:
|
|||||||||||||||||||
Total
assets(b)
|
1,208
|
1,246
|
4
|
(217 | ) |
2,241
|
(a)
|
Represents
net income available to the common shareholder (Ameren); 100%
of CILCO’s
preferred stock dividends are included in the Illinois Regulated
segment.
|
(b)
|
Total
assets for Illinois Regulated include an allocation of goodwill
and other
purchase accounting amounts related to CILCO that are recorded
at CILCORP
(parent company).
|
Three
Months
|
Illinois
Regulated
|
Non-rate-regulated
Generation
|
CILCO
Other
|
Intersegment
Eliminations
|
Consolidated
CILCO
|
||||||||||||||
2007:
|
|||||||||||||||||||
External
revenues
|
$ |
161
|
$ |
62
|
$ |
-
|
$ |
-
|
$ |
223
|
|||||||||
Intersegment
revenues
|
-
|
1
|
-
|
(1 | ) |
-
|
|||||||||||||
Net
income(a)
|
7
|
13
|
-
|
-
|
20
|
||||||||||||||
2006:
|
|||||||||||||||||||
External
revenues
|
$ |
137
|
$ |
9
|
$ |
-
|
$ |
-
|
$ |
146
|
|||||||||
Intersegment
revenues
|
-
|
44
|
-
|
(44 | ) |
-
|
|||||||||||||
Net
income(a)
|
3
|
7
|
(3 | ) |
-
|
7
|
|||||||||||||
Six
Months
|
|||||||||||||||||||
2007:
|
|||||||||||||||||||
External
revenues
|
$ |
395
|
$ |
138
|
$ |
-
|
$ |
-
|
$ |
533
|
|||||||||
Intersegment
revenues
|
-
|
2
|
-
|
(2 | ) |
-
|
|||||||||||||
Net
income(a)
|
14
|
32
|
-
|
-
|
46
|
||||||||||||||
2006:
|
|||||||||||||||||||
External
revenues
|
$ |
370
|
$ |
18
|
$ |
-
|
$ |
-
|
$ |
388
|
|||||||||
Intersegment
revenues
|
-
|
85
|
-
|
(85 | ) |
-
|
|||||||||||||
Net
income(a)
|
11
|
16
|
(3 | ) |
-
|
24
|
|||||||||||||
As
of June 30, 2007:
|
|||||||||||||||||||
Total
assets
|
$ |
985
|
$ |
768
|
$ |
1
|
$ | (1 | ) | $ |
1,753
|
||||||||
As
of December 31, 2006:
|
|||||||||||||||||||
Total
assets
|
1,020
|
642
|
1
|
(22 | ) |
1,641
|
(a)
|
Represents
net income available to the common shareholder (CILCORP); 100%
of CILCO’s
preferred stock dividends are included in the Illinois Regulated
segment.
|
·
|
UE
operates a rate-regulated electric generation, transmission
and
distribution business, and a rate-regulated natural gas transmission
and
distribution business in Missouri.
|
·
|
CIPS
operates a rate-regulated electric and natural gas transmission
and
distribution business in Illinois.
|
·
|
Genco
operates a non-rate-regulated electric generation
business.
|
·
|
CILCO,
a subsidiary of CILCORP (a holding company), operates a rate-regulated
electric and natural gas transmission and distribution business
and a
non-rate-regulated electric generation business (through its
subsidiary,
AERG) in Illinois.
|
·
|
IP
operates a rate-regulated electric and natural gas transmission
and
distribution business in Illinois.
|
·
|
higher
margins in the Non-rate-regulated Generation segment due to
the
replacement of below-market
|
|
power
sales contracts, which expired in 2006, with higher-priced
contracts;
|
·
|
favorable
weather conditions;
|
·
|
the
absence of costs in the current year periods that were incurred
in the
second quarter of the prior year related to the reservoir breach
at UE’s
Taum Sauk plant (5 cents per
share);
|
·
|
higher
delivery service rates on Illinois Regulated
sales;
|
·
|
the
lack of FERC fees related to UE’s Osage hydroelectric plant in the current
year period that were incurred in the prior year period and
the
capitalization of fees, pursuant to a MoPSC order, in the current
year
period; and
|
·
|
lower
emission allowance costs and other
factors.
|
·
|
the
cost of UE’s Callaway nuclear plant refueling and maintenance outage in
the second quarter of 2007 exceeding the cost of the unplanned
outage at
the Callaway plant in the second quarter of 2006 (9 cents per
share);
|
·
|
increased
fuel and transportation prices (5 cents per share and 8
cents per share,
respectively);
|
·
|
higher
labor and employee benefit costs (2 cents per share and
8 cents per share,
respectively);
|
·
|
increased
bad debt reserves (3 cents per share and 5 cents per
share, respectively);
|
·
|
increased
depreciation expense (2 cents per share and 7 cents per
share,
respectively); and
|
·
|
higher
financing costs (4 cents per share and 8 cents per share,
respectively).
|
Three
Months
|
Six
Months
|
||||||||||||||
2007
|
2006
|
2007
|
2006
|
||||||||||||
Net
income (loss):
|
|||||||||||||||
UE(a)
|
$ |
79
|
$ |
90
|
$ |
116
|
$ |
140
|
|||||||
CIPS
|
5
|
15
|
15
|
13
|
|||||||||||
Genco
|
17
|
2
|
60
|
8
|
|||||||||||
CILCORP
|
12
|
1
|
32
|
9
|
|||||||||||
IP
|
7
|
16
|
19
|
19
|
|||||||||||
Other(b)
|
23
|
(1 | ) |
24
|
4
|
||||||||||
Ameren
net income
|
$ |
143
|
$ |
123
|
$ |
266
|
$ |
193
|
(a)
|
Includes
earnings from a non-rate-regulated 40% interest in
EEI.
|
(b)
|
Includes
earnings from non-rate-regulated operations and a 40% interest
in EEI held
by Development Company, corporate general and administrative
expenses, and
intercompany eliminations.
|
Missouri
Regulated
|
Illinois
Regulated
|
Non-rate-regulated
Generation
|
Other
/ Intersegment
Eliminations
|
Total
|
|||||||||||||||
Three
Months 2007:
|
|||||||||||||||||||
Electric
margin
|
$ |
494
|
$ |
207
|
$ |
251
|
$ | (15 | ) | $ |
937
|
||||||||
Gas
margin
|
14
|
64
|
-
|
(2 | ) |
76
|
|||||||||||||
Other
revenues
|
(1 | ) | (1 | ) |
-
|
2
|
-
|
||||||||||||
Other
operations and
maintenance
|
(223 | ) | (130 | ) | (92 | ) |
19
|
(426 | ) | ||||||||||
Depreciation
and
amortization
|
(84 | ) | (53 | ) | (27 | ) | (5 | ) | (169 | ) | |||||||||
Taxes
other than income
taxes
|
(60 | ) | (30 | ) | (6 | ) |
-
|
(96 | ) | ||||||||||
Other
income and
(expenses)
|
9
|
6
|
1
|
-
|
16
|
||||||||||||||
Interest
expense
|
(51 | ) | (32 | ) | (28 | ) |
3
|
(108 | ) | ||||||||||
Income
taxes
|
(30 | ) | (11 | ) | (37 | ) |
-
|
(78 | ) | ||||||||||
Minority
interest and preferred dividends
|
(2 | ) | (1 | ) | (6 | ) |
-
|
(9 | ) | ||||||||||
Net
income
|
$ |
66
|
$ |
19
|
$ |
56
|
$ |
2
|
$ |
143
|
|||||||||
Three
Months 2006:
|
|||||||||||||||||||
Electric
margin
|
$ |
496
|
$ |
209
|
$ |
165
|
$ | (16 | ) |
854
|
|||||||||
Gas
margin
|
10
|
60
|
-
|
(2 | ) |
68
|
|||||||||||||
Other
revenues
|
-
|
(1 | ) |
-
|
1
|
-
|
|||||||||||||
Other
operations and
maintenance
|
(196 | ) | (124 | ) | (82 | ) |
8
|
(394 | ) | ||||||||||
Depreciation
and
amortization
|
(81 | ) | (48 | ) | (27 | ) | (6 | ) | (162 | ) | |||||||||
Taxes
other than income
taxes
|
(59 | ) | (27 | ) | (6 | ) |
2
|
(90 | ) | ||||||||||
Other
income and
(expenses)
|
7
|
4
|
1
|
(2 | ) |
10
|
|||||||||||||
Interest
expense
|
(44 | ) | (22 | ) | (26 | ) |
5
|
(87 | ) | ||||||||||
Income
taxes
|
(52 | ) | (17 | ) | (7 | ) |
8
|
(68 | ) | ||||||||||
Minority
interest and preferred dividends
|
(3 | ) | (1 | ) | (5 | ) |
1
|
(8 | ) | ||||||||||
Net
income
|
$ |
78
|
$ |
33
|
$ |
13
|
$ | (1 | ) | $ |
123
|
||||||||
Six
Months 2007:
|
|||||||||||||||||||
Electric
margin
|
$ |
909
|
$ |
379
|
$ |
501
|
$ | (30 | ) | $ |
1,759
|
||||||||
Gas
margin
|
41
|
179
|
-
|
(4 | ) |
216
|
|||||||||||||
Other
revenues
|
-
|
1
|
-
|
(1 | ) |
-
|
|||||||||||||
Other
operations and
maintenance
|
(446 | ) | (256 | ) | (160 | ) |
40
|
(822 | ) | ||||||||||
Depreciation
and
amortization
|
(171 | ) | (108 | ) | (54 | ) | (12 | ) | (345 | ) | |||||||||
Taxes
other than income
taxes
|
(117 | ) | (66 | ) | (14 | ) | (1 | ) | (198 | ) | |||||||||
Other
income and
(expenses)
|
16
|
10
|
2
|
2
|
30
|
||||||||||||||
Interest
expense
|
(97 | ) | (61 | ) | (53 | ) |
5
|
(206 | ) | ||||||||||
Income
taxes
|
(43 | ) | (27 | ) | (83 | ) |
4
|
(149 | ) | ||||||||||
Minority
interest and preferred dividends
|
(3 | ) | (3 | ) | (13 | ) |
-
|
(19 | ) | ||||||||||
Net
income
|
$ |
89
|
$ |
48
|
$ |
126
|
$ |
3
|
$ |
266
|
|||||||||
Six
Months 2006:
|
|||||||||||||||||||
Electric
margin
|
$ |
870
|
$ |
349
|
$ |
349
|
$ | (28 | ) |
1,540
|
|||||||||
Gas
margin
|
35
|
170
|
-
|
(1 | ) |
204
|
|||||||||||||
Other
revenues
|
1
|
(1 | ) |
-
|
-
|
-
|
|||||||||||||
Other
operations and
maintenance
|
(367 | ) | (248 | ) | (151 | ) |
20
|
(746 | ) | ||||||||||
Depreciation
and
amortization
|
(161 | ) | (95 | ) | (53 | ) | (14 | ) | (323 | ) | |||||||||
Taxes
other than income
taxes
|
(118 | ) | (70 | ) | (14 | ) | (1 | ) | (203 | ) | |||||||||
Other
income and
(expenses)
|
9
|
6
|
1
|
(1 | ) |
15
|
|||||||||||||
Interest
expense
|
(80 | ) | (45 | ) | (51 | ) |
12
|
(164 | ) | ||||||||||
Income
taxes
|
(72 | ) | (21 | ) | (29 | ) |
10
|
(112 | ) | ||||||||||
Minority
interest and preferred dividends
|
(4 | ) | (3 | ) | (12 | ) |
1
|
(18 | ) | ||||||||||
Net
income
|
$ |
113
|
$ |
42
|
$ |
40
|
$ | (2 | ) | $ |
193
|
Three
Months
|
Ameren(a)
|
UE
|
CIPS
|
Genco
|
CILCORP
|
CILCO
|
IP
|
||||||||||||||||||||
Electric
revenue change:
|
|||||||||||||||||||||||||||
Effect
of weather (estimate)
|
$ |
28
|
$ |
14
|
$ |
6
|
$ |
-
|
$ |
2
|
$ |
2
|
$ |
6
|
|||||||||||||
Interchange
revenues- affiliated(b)
|
-
|
(49 | ) |
-
|
(28 | ) |
-
|
-
|
-
|
||||||||||||||||||
Interchange
revenues- other
|
31
|
31
|
-
|
-
|
-
|
-
|
-
|
||||||||||||||||||||
Other
(estimate)
|
77
|
(15 | ) |
6
|
(25 | ) |
62
|
62
|
3
|
||||||||||||||||||
Total
|
$ |
136
|
$ | (19 | ) | $ |
12
|
$ | (53 | ) | $ |
64
|
$ |
64
|
$ |
9
|
|||||||||||
Fuel
and purchased power change:
|
|||||||||||||||||||||||||||
Fuel:
|
|||||||||||||||||||||||||||
Generation
and
other
|
$ |
2
|
$ |
3
|
$ |
-
|
$ | (14 | ) | $ |
11
|
$ |
12
|
$ |
-
|
||||||||||||
Emission
allowance
costs
|
6
|
2
|
-
|
1
|
5
|
2
|
-
|
||||||||||||||||||||
Price
|
(24 | ) | (24 | ) |
-
|
-
|
(1 | ) | (1 | ) |
-
|
||||||||||||||||
Purchased
power
|
(37 | ) |
39
|
(14 | ) |
90
|
(55 | ) | (55 | ) | (7 | ) | |||||||||||||||
Total
fuel and purchased power change
|
$ | (53 | ) | $ |
20
|
$ | (14 | ) | $ |
77
|
$ | (40 | ) | $ | (42 | ) | $ | (7 | ) | ||||||||
Net
change in electric margins
|
$ |
83
|
$ |
1
|
$ | (2 | ) | $ |
24
|
$ |
24
|
$ |
22
|
$ |
2
|
||||||||||||
Net
change in gas margins
|
$ |
8
|
$ |
4
|
$ |
1
|
$ |
-
|
$ |
2
|
$ |
2
|
$ | (2 | ) | ||||||||||||
Six
Months
|
|||||||||||||||||||||||||||
Electric
revenue change:
|
|||||||||||||||||||||||||||
Effect
of weather (estimate)
|
$ |
46
|
$ |
21
|
$ |
11
|
$ |
-
|
$ |
6
|
$ |
6
|
$ |
8
|
|||||||||||||
Interchange
revenues- affiliated(b)
|
-
|
(121 | ) |
-
|
(46 | ) |
-
|
-
|
-
|
||||||||||||||||||
Interchange
revenues- other
|
92
|
92
|
-
|
-
|
-
|
-
|
-
|
||||||||||||||||||||
Other
(estimate)
|
245
|
(5 | ) |
52
|
(11 | ) |
141
|
141
|
31
|
||||||||||||||||||
Total
|
$ |
383
|
$ | (13 | ) | $ |
63
|
$ | (57 | ) | $ |
147
|
$ |
147
|
$ |
39
|
|||||||||||
Fuel
and purchased power change:
|
|||||||||||||||||||||||||||
Fuel:
|
|||||||||||||||||||||||||||
Generation
and
other
|
$ | (7 | ) | $ |
11
|
$ |
-
|
$ | (29 | ) | $ |
13
|
$ |
14
|
$ |
-
|
|||||||||||
Emission
allowance
costs
|
22
|
5
|
-
|
6
|
9
|
6
|
-
|
||||||||||||||||||||
Price
|
(42 | ) | (35 | ) |
-
|
(2 | ) | (6 | ) | (6 | ) |
-
|
|||||||||||||||
Purchased
power
|
(137 | ) |
73
|
(47 | ) |
165
|
(125 | ) | (125 | ) | (19 | ) | |||||||||||||||
Total
fuel and purchased power change
|
$ | (164 | ) | $ |
54
|
$ | (47 | ) | $ |
140
|
$ | (109 | ) | $ | (111 | ) | $ | (19 | ) | ||||||||
Net
change in electric margins
|
$ |
219
|
$ |
41
|
$ |
16
|
$ |
83
|
$ |
38
|
$ |
36
|
$ |
20
|
|||||||||||||
Net
change in gas margins
|
$ |
12
|
$ |
6
|
$ |
3
|
$ |
-
|
$ |
3
|
$ |
3
|
$ |
-
|
(a)
|
Includes
amounts for Ameren registrant and nonregistrant subsidiaries
and
intercompany eliminations.
|
(b)
|
Includes
revenues from sales transferred between UE and Genco under
the former JDA,
which terminated on December 31,
2006.
|
·
|
Non-rate-regulated
Generation selling more power at market-based prices in the
second quarter
and first six months of 2007 compared with sales under below
market-based
power supply agreements, which expired on December 31,
2006;
|
·
|
Illinois
electric delivery service rate increases which commenced January
2,
2007;
|
·
|
emission
allowance costs were $6 million and $22 million lower, for
the three
months and six months ended June 30, 2007,
respectively;
|
·
|
favorable
weather conditions increased electric margins by $13 million
and $22
million for the three months and six months ended June 30,
2007;
|
·
|
MISO
costs were $8 million lower for the quarter compared with the
same period
in 2006;
|
·
|
return
to normal rainfall levels, which increased hydroelectric
generation;
|
·
|
the
lack of $6 million in fees levied by FERC in the first quarter
of 2006
upon completion of its cost study for generation benefits provided
to UE’s
Osage hydroelectric plant and the subsequent May 2007 MoPSC
rate order
that directed AmerenUE to transfer $4 million of the total
fees to an
asset account, which will be amortized over 25
years;
|
·
|
UE’s
electric rate increase that went into effect June 4, 2007;
and
|
·
|
storm-related
outages in the second quarter of 2006 that decreased interchange
margin by
$3 million.
|
·
|
an
11% increase in coal and related transportation prices for
both the second
quarter and the first six months of
2007;
|
·
|
MISO
costs were $13 million higher for the six months ended June
30, 2007,
compared with the same period in 2006. Costs related to participation
in
the MISO Day Two Energy Market were higher for the year because
of a March
2007 FERC order that reallocated costs related to participation
in the
MISO Day Two Energy Market among market participants retroactive
to
2005;
|
·
|
elimination
of bundled power and delivery service tariffs in Illinois Regulated
operations; and
|
·
|
reduced
power plant availability, primarily at UE’s and AERG’s
plants.
|
·
|
an
increase in margins on interchange sales primarily because
of the
termination of the JDA on December 31, 2006. This termination
of the JDA
provided UE with the ability to sell its excess power, originally
obligated under the JDA at cost, in the spot market at higher
market
prices;
|
·
|
the
lack of $6 million in fees levied by FERC in the first quarter
of 2006
upon completion of its cost study for generation benefits provided
to UE’s
Osage hydroelectric plant and the subsequent June 2007 MoPSC
rate order,
which directed UE to transfer $4 million of the total fees
to an asset
account, which will be amortized over 25
years;
|
·
|
return
to normal rainfall levels, which increased hydroelectric
generation;
|
·
|
increased
electric rates as approved by the MoPSC effective June 4,
2007;
|
·
|
favorable
weather conditions which increased electric margin by $10 million
and $13
million for the three months and six months ended June 30,
2007,
respectively;
|
·
|
MISO
costs, excluding the March 2007 FERC order, discussed below,
were $4
million lower for the second quarter and $17 million lower
for the six
months ended June 30, 2007, compared to the same periods in
2006;
and
|
·
|
spring
storm-related outages in the second quarter of 2006, which
reduced 2006
electric margins by $3 million.
|
·
|
reduced
power plant availability because of planned maintenance
activities;
|
·
|
the
38-day planned refueling and maintenance outage at the Callaway
nuclear
plant in the second quarter of 2007, which was offset by the
unplanned
outage that occurred at the Callaway nuclear plant during the
second
quarter of 2006;
|
·
|
a
14% increase in coal and related transportation prices;
and
|
·
|
MISO
costs were $11 million higher for the six months ended June
30, 2007,
compared to the same period in 2006, due to the March 2007
FERC
order.
|
Three
Months
|
Six
Months
|
||||||
CILCO
(Illinois Regulated)
|
$ | (1 | ) | $ | (5 | ) | |
CILCO
(AERG)
|
23
|
41
|
|||||
Total
change in electric margin
|
$ |
22
|
$ |
36
|
·
|
selling
power at market-based prices in the second quarter of 2007
compared with
selling power at below-market prices pursuant to cost-based
power supply
agreements, which expired on December 31,
2006;
|
·
|
increased
power plant availability due to reduced planned outages this
year;
|
·
|
reduced
emission allowance costs; and
|
·
|
lower
MISO costs totaling $9 million for the six months ended June
30, 2007,
compared to the first half of 2006, as a result of the March
2007 FERC
order.
|
·
|
the
loss of margins on sales supplied with power acquired through
the JDA;
and
|
·
|
a
2% increase in coal and related transportation prices for the
six months
ended June 30, 2007 compared to the first half of
2006.
|
·
|
selling
power at market-based prices in the second quarter of 2007
compared with
sales under cost-based power supply agreements, which expired
on December
31, 2006; and
|
·
|
reduced
emission costs for both the second quarter and six months ended
June 30,
2007, compared to the same prior year
periods.
|
·
|
a
16% increase in coal and related transportation prices for
the six months
ended June 30, 2007, compared to the first half of 2006;
and
|
·
|
reduced
plant availability because of planned extensive maintenance
activities,
which commenced in February 2007.
|
Net
Cash Provided By
Operating
Activities
|
Net
Cash Used In
Investing
Activities
|
Net
Cash Provided By
(Used
In) Financing Activities
|
|||||||||||||||||||||||||||||||||
2007
|
2006
|
Variance
|
2007
|
2006
|
Variance
|
2007
|
2006
|
Variance
|
|||||||||||||||||||||||||||
Ameren(a)
|
$ |
543
|
$ |
619
|
$ | (76 | ) | $ | (754 | ) | $ | (795 | ) | $ |
41
|
$ |
761
|
$ |
131
|
$ |
630
|
||||||||||||||
UE
|
145
|
258
|
(113 | ) | (381 | ) | (475 | ) |
94
|
444
|
198
|
246
|
|||||||||||||||||||||||
CIPS
|
44
|
80
|
(36 | ) | (1 | ) | (24 | ) |
23
|
99
|
(55 | ) |
154
|
||||||||||||||||||||||
Genco
|
115
|
63
|
52
|
(81 | ) | (64 | ) | (17 | ) | (34 | ) |
2
|
(36 | ) | |||||||||||||||||||||
CILCORP
|
62
|
112
|
(50 | ) | (85 | ) | (6 | ) | (79 | ) |
127
|
(86 | ) |
213
|
|||||||||||||||||||||
CILCO
|
89
|
119
|
(30 | ) | (85 | ) | (48 | ) | (37 | ) |
88
|
(51 | ) |
139
|
|||||||||||||||||||||
IP
|
73
|
85
|
(12 | ) | (93 | ) | (82 | ) | (11 | ) |
163
|
(2 | ) |
165
|
(a)
|
Includes
amounts for Ameren registrant and nonregistrant subsidiaries
and
intercompany eliminations.
|
Credit
Facility
|
Expiration
|
Amount
Committed
|
Amount
Available
|
|||||
Ameren,
UE and Genco:
|
||||||||
Multiyear
revolving(a)
|
July
2010
|
$ |
1,150
|
$ |
369
|
|||
CIPS,
CILCORP, CILCO, IP and AERG:
|
||||||||
2007
Multiyear revolving(b)
|
January
2010
|
500
|
75
|
|||||
2006
Multiyear revolving(c)
|
January
2010
|
500
|
-
|
(a)
|
Ameren
Companies may access this credit facility through intercompany
borrowing
arrangements. The maximum amount available to Ameren, UE and
Genco is
$1.15 billion,
$500
million and $150 million,
respectively.
|
(b)
|
The
maximum amount available to each borrower at June 30, 2007,
including for
the issuance of letters of credit, was limited as follows:
CILCORP
- $125 million, IP - $200 million and AERG - $100 million. CIPS
and
CILCO have the option of permanently reducing their ability
to borrow
under the 2006 $500 million credit facility and shifting such
capacity, up
to the same limits, to the 2007 $500 million credit facility.
In July
2007, CILCO shifted $75 million of its sublimit under the 2006
$500
million credit facility to this
facility.
|
(c)
|
The
maximum amount available to each borrower at June 30, 2007,
including for
issuance of letters of credit, was limited as follows: CIPS
- $135
million, CILCORP - $50 million, CILCO - $150 million, IP -
$150 million
and AERG - $200 million. In July 2007, CILCO shifted $75 million
of its
capacity under this facility to the 2007 $500 million credit
facility.
Accordingly, as of July 31, 2007, CILCO had a sublimit of $75
million
under this facility and a $75 million sublimit under the 2007
credit
facility.
|
Six
Months
|
||||||||
Month
Issued, Redeemed,
Repurchased
or Matured
|
2007
|
2006
|
||||||
Issuances
|
||||||||
Long-term
debt
|
||||||||
UE:
|
||||||||
6.40%
Senior secured notes due
2017
|
June
|
$ |
425
|
$ |
-
|
|||
CIPS:
|
||||||||
6.70%
Senior secured notes due
2036
|
June
|
-
|
61
|
Six
Months
|
||||||||
Month
Issued, Redeemed,
Repurchased
or Matured
|
2007
|
2006
|
||||||
CILCO:
|
||||||||
6.20%
Senior secured notes due
2016
|
June
|
-
|
54
|
|||||
6.70%
Senior secured notes due
2036
|
June
|
-
|
42
|
|||||
IP:
|
||||||||
6.25%
Senior secured notes due
2016
|
June
|
-
|
75
|
|||||
Total
Ameren long-term debt issuances
|
$ |
425
|
$ |
232
|
||||
Common
stock
|
||||||||
Ameren:
|
||||||||
DRPlus
and
401(k)
|
Various
|
$ |
48
|
$ |
57
|
|||
Total
common stock issuances
|
$ |
48
|
$ |
57
|
||||
Total
Ameren long-term debt and common stock issuances
|
$ |
473
|
$ |
289
|
||||
Redemptions,
Repurchases and Maturities
|
||||||||
Long-term
debt
|
||||||||
Ameren:
|
||||||||
2002
5.70% notes due
2007
|
February
|
$ |
100
|
$ |
-
|
|||
Senior
notes due
2007
|
May
|
250
|
-
|
|||||
CIPS:
|
||||||||
7.05%
First mortgage bonds due
2006
|
June
|
-
|
20
|
|||||
CILCORP:
|
||||||||
9.375%
Senior notes due
2029
|
March/April
|
-
|
12
|
|||||
CILCO:
|
||||||||
7.50%
First mortgage bonds due
2007
|
January
|
50
|
-
|
|||||
IP:
|
||||||||
Note
payable to IP
SPT:
|
||||||||
5.65%
Series due
2008
|
Various
|
43
|
-
|
|||||
5.54%
Series due
2007
|
Various
|
-
|
54
|
|||||
Total
Ameren long-term debt redemptions, repurchases and
maturities
|
$ |
443
|
$ |
86
|
Effective
Date
|
Authorized
Amount
|
Issued
|
Available
|
|||||||||
Ameren
|
June
2004
|
$ |
2,000
|
$ |
459
|
$ |
1,541
|
|||||
UE
|
October
2005
|
1,000
|
685
|
315
|
||||||||
CIPS
|
May
2001
|
250
|
211
|
39
|
Six
Months
|
|||||||
2007
|
2006
|
||||||
UE
|
$ |
127
|
$ |
84
|
|||
CIPS
|
-
|
25
|
|||||
Genco
|
113
|
71
|
|||||
CILCORP(a)
|
-
|
50
|
|||||
Nonregistrants
|
23
|
30
|
|||||
Dividends
paid by Ameren
|
$ |
263
|
$ |
260
|
(a)
|
CILCO
paid to CILCORP dividends of $50 million for the six months ended
June 30, 2006.
|
Moody’s
|
S&P
|
Fitch
|
|
Ameren:
|
|||
Issuer/corporate
credit rating
|
Baa2
|
BBB-
|
BBB+
|
Unsecured
debt
|
Baa2
|
BB+
|
BBB+
|
Commercial
paper
|
P-2
|
A-3
|
F2
|
UE:
|
|||
Issuer/corporate
credit rating
|
Baa1
|
BBB-
|
A-
|
Secured
debt
|
A3
|
BBB-
|
A+
|
Commercial
paper
|
P-2
|
A-3
|
F2
|
CIPS:
|
|||
Issuer/corporate
credit rating
|
Ba1
|
BB
|
BB+
|
Secured
debt
|
Baa3
|
BBB-
|
BBB
|
Genco:
|
|||
Issuer/corporate
credit rating
|
-
|
BBB-
|
BBB+
|
Unsecured
debt
|
Baa2
|
BBB-
|
BBB+
|
CILCORP:
|
|||
Issuer/corporate
credit rating
|
-
|
BB
|
BB+
|
Unsecured
debt
|
Ba2
|
B+
|
BB+
|
CILCO:
|
|||
Issuer/corporate
credit rating
|
Ba1
|
BB
|
BB+
|
Secured
debt
|
Baa2
|
BBB-
|
BBB
|
IP:
|
|||
Issuer/corporate
credit rating
|
Ba1
|
BB
|
BB+
|
Secured
debt
|
Baa3
|
BBB-
|
BBB
|
·
|
In
2006, electric rate freezes or adjustment moratoriums and power
supply
contracts expired in Ameren’s regulatory jurisdictions. At the end of
2006, electric rates for Ameren’s operating subsidiaries had been fixed or
declining for periods ranging from 15 years to 25
years.
|
·
|
Average
residential electric rates for CIPS, CILCO and IP increased
significantly
following the expiration of a rate freeze at the end of 2006.
Electric
rates rose because of the increased cost of power purchased
on behalf of
the Ameren Illinois Utilities’ customers and an increase in electric
delivery service rates. Illinois average residential rates
were expected
to increase in 2007 by approximately 40% to 55% over 2006 rates
with the
overall increase for electric heat customers expected to be
even higher.
Due to the magnitude of these increases, a comprehensive customer
rate
relief and customer assistance program and agreement was reached
with key
stakeholders in Illinois that would provide approximately $1
billion of
funding for rate relief for certain electric customers in Illinois,
including approximately $488 million to customers of the Ameren
Illinois
Utilities. This agreement was reached in order to avoid rate
rollback and
freeze legislation, or a tax on power generation enabling legislation
necessary for the agreement to become effective was passed
by the Illinois
General Assembly in late July 2007 but must be signed by the
governor of
Illinois to become law.
|
·
|
Pursuant
to the rate relief program, the Ameren Illinois Utilities,
Genco and AERG
agreed to make aggregate contributions of $150 million over
a four-year
period, with
$60
million coming from the Ameren Illinois Utilities (CIPS - $21
million;
CILCO - $11 million; IP - $28 million), $62 million from Genco
and $28
million from AERG. To fund these contributions, the Ameren
Illinois
Utilities, Genco and AERG would need to increase their respective
short-term or long-term borrowings.
|
·
|
Under
the rate relief program, the Ameren Illinois Utilities would
continue to
have the right to file new electric delivery service rate cases
with the
ICC at the utilities’ discretion. As a result of low returns on equity
expected in 2007, the Ameren Illinois Utilities plan to file
additional
delivery service rate cases by the end of
2007.
|
·
|
The
redesign of all-electric customers’ rates is the subject of an ongoing
case with the ICC designed to reduce seasonal fluctuations
for residential
customers who use large amounts of electricity while allowing
utilities to
fully recover costs. However, the redesign is expected to result
in
revenue changes between quarterly reporting
periods.
|
·
|
The
agreement provides that if legislation is enacted in Illinois
before
August 1, 2011, freezing or reducing retail electric rates
or imposing or
authorizing a new tax, special assessment or fee on the generation
of
electricity, then the remaining commitments would expire and
any funds set
aside in support of the funding commitments would be refunded
to the
contributing utilities and electric
generators.
|
·
|
As
part of the agreement, the current reverse auction used for
power
procurement in Illinois would be discontinued immediately and
replaced
with a new power procurement process. In 2008, utilities would
contract
for necessary baseload, intermediate and peaking power requirements
through a request-for-proposal process, subject to ICC review
and
approval. Existing supply contracts from the September 2006
reverse
auction would remain in place.
|
·
|
As
part of the rate relief program, the Ameren Illinois Utilities
entered
into financial contracts with Marketing Company (for the benefit
of Genco
and AERG), to lock-in prices for 400 to 1,000 megawatts annually
of their
baseload power requirements from 2008 through 2012 at
|
|
relevant
market prices. These contracts are not effectiveuntil enactment
of
enabling legislation by the Illinois governor. If the legislation
is
enacted into law after August 10, 2007, then new market prices
will be set
when the legislation is enacted. These financial swap contracts
expose
Genco and AERG to changes in market prices, which could materially
impact
Genco’s, CILCORP’s, and CILCO’s results of operations, financial position,
or liquidity if the market prices of power exceed the locked-in
prices.
|
·
|
See
Note 2 – Rate and Regulatory Matters to our financial statements under
Part I, Item 1, of this report for a further discussion of
Illinois rate
matters.
|
·
|
The
MoPSC issued an order granting UE a $43 million increase in
base rates for
electric service with new electric rates effective June 4,
2007. The MoPSC
also approved a stipulation and agreement authorizing an increase
in UE’s
annual natural gas delivery revenues of $6 million, effective
April 1,
2007. UE agreed not to file a natural gas delivery rate case
before March
15, 2010. With increasing fuel and purchased power costs, and
lacking a
fuel and purchased power cost recovery mechanism, coupled with
increased
capital and operations and maintenance expenditures targeted
at enhanced
distribution system reliability, UE expects to be entering
a period where
more frequent rate cases will be
necessary.
|
·
|
Very
volatile power prices in the Midwest affect the amount of revenues
Ameren,
UE, Genco and CILCO (through AERG) can generate by marketing
power into
the wholesale and spot markets and influence the cost of power
purchased
in the spot markets.
|
·
|
In
2006, the Non-rate-regulated Generation segment generated 30
million
megawatthours of power (Genco - 15 million, AERG - 7 million,
EEI - 8
million). Power previously supplied by Genco to CIPS (through
Marketing
Company) and by AERG to CILCO was subject to below-market-priced contracts
that expired on December 31, 2006. All but 5 million megawatthours
of
Genco’s pre-2006 wholesale and retail electric power supply agreements
also expired during 2006. In 2007, an additional 1 million
megawatthours
of these contracts will expire and another 2 million contracted
megawatthours will expire in 2008. These agreements had an
average
embedded selling price of $36 per megawatthour, which is below
current
market prices. In 2006, Genco also sold 2.1 million net megawatthours
of
power in the spot market at an average market price of $38
per
megawatthour. In 2006, AERG’s power was sold principally to CILCO, at an
average price of $32 per megawatthour. In addition, AERG sold
1.5 million
net megawatthours of power in the spot market at an average
price of $37
per megawatthour in 2006. The Non-rate-regulated Generation
segment
expects to generate 32 million megawatthours of power in 2007
(Genco – 17
million,
AERG
– 7 million, EEI – 8 million).
|
·
|
The
marketing strategy for Non-rate-regulated Generation is to
optimize
generation output in a low risk manner to minimize earnings
and cash flow
volatility, while capitalizing on its low-cost generation fleet
to provide
for solid, sustainable returns. Through a mix of physical and
financial
sales contracts and the Illinois 2006 power procurement auction
and
including expected contracts associated with the Illinois settlement
agreement referenced above, the Non-rate-regulated Generation
segment has
sold approximately 90% of its expected 2007 generation output
for the
remainder of 2007 (fiscal year 2008 - 70%, or 23 million megawatthours;
fiscal year 2009 - 50%, or 17 million megawatthours) at an
average price
of $51 per megawatthour. Expected sales in 2007 include an
estimated 7.6
million megawatthours of power sold through the Illinois power
procurement
auction at about $65 per megawatthour (2008 – 6.8 million, 2009 – 4.3
million).
|
·
|
We
expect continued economic growth in our service territory to
benefit
energy demand in 2007 and beyond, but higher energy prices
could result in
reduced demand from customers, especially in
Illinois.
|
·
|
UE,
Genco and CILCO are seeking to raise the equivalent availability
and
capacity factors of their power plants through greater investments
and a
process improvement program and
investment.
|
·
|
In
2006, 85% of Ameren's electric generation (UE - 77%, Genco
- 97%,
CILCO - 99%) was supplied by its coal-fired power plants. About
93% of the coal used by these plants (UE - 97%, Genco - 87%,
CILCO - 69%)
was delivered by railroads from the Powder River Basin in
Wyoming.
In the past, deliveries from the Powder River Basin have
been restricted
because of rail maintenance, weather and derailments. As of June 30,
2007, coal inventories for UE, Genco, AERG and EEI were adequate,
and
consistent with historical levels. Disruptions in coal deliveries
could cause UE, Genco, AERG and EEI to pursue a strategy
that could
include reducing sales of power during low-margin periods,
buying
higher-cost fuels to generate required electricity, and purchasing
power
from other sources.
|
·
|
Ameren’s
coal and related transportation costs are expected to increase
15% to 20%
in 2007 over 2006 and 5% to 10% in 2008. Ameren’s nuclear fuel costs are
also expected to rise over the next few years. In addition,
power
generation from higher-cost, gas-fired plants is expected to
increase in
the next few years. See Item 3 - Quantitative and Qualitative
Disclosures
about Market Risk in Part I of this report for information
about the
percentage of fuel and transportation requirements that are
price-hedged
for 2007 through 2011.
|
·
|
In
Illinois, Ameren and IP will also experience higher year-over-year
purchased power expenses as the amortization of certain favorable
purchase
accounting adjustments associated with the IP acquisition was
completed in
2006.
|
·
|
In
July 2005, a new law was enacted that enables the MoPSC to put in
place fuel, purchased power, and environmental cost recovery
mechanisms
for Missouri’s utilities. In UE’s electric rate order issued by the MoPSC
in May 2007, the MoPSC denied UE’s request to implement a fuel and
purchased power cost recovery mechanism and an environmental
cost recovery
mechanism. UE may request the use of these mechanisms in future
rate
cases.
|
·
|
In
2007, Ameren expects to reduce levels of emission allowance
sales in order
to retain remaining allowances for future environmental compliance
needs.
|
·
|
In
December 2005, there was a breach of the upper reservoir at
UE’s Taum Sauk
pumped-storage hydroelectric facility. This resulted in significant
flooding in the local area, which damaged a state park. In
February 2007,
UE submitted plans and an environmental report to FERC to rebuild
the
upper reservoir at its Taum Sauk plant, assuming successful
resolution of
outstanding issues with authorities of the state of Missouri.
Should the
decision be made to rebuild the Taum Sauk plant, UE would expect
it to be
out of service through at least the middle of 2009, if not
longer. UE has
accepted responsibility for the effects of the incident. At
this time, UE
believes that substantially all of the damage and liabilities
(but not
penalties or lost electric margins) caused by the breach, including
rebuilding the plant, will be covered by insurance. Under UE’s insurance
policies, all claims by or against UE are subject to review
by its
insurance carriers. As a result of this breach, UE is engaged
in
litigation initiated by certain private parties and by state
authorities.
The Taum Sauk incident is also under investigation at the MoPSC.
We are
unable to determine the impact the breach may have on Ameren’s and UE’s
results of operations, financial position, or liquidity beyond
those
amounts already recognized. See Note 2 – Rate and Regulatory Matters and
Note 8 - Commitments and Contingencies to our financial statements
under
Part I, Item 1, of this report for a further discussion of
Taum Sauk
matters.
|
·
|
UE’s
Callaway nuclear plant’s next scheduled refueling and maintenance outage
is in the fall of 2008. During an outage, which occurs every
18 months,
maintenance and purchased power costs increase, and the amount
of excess
power available for sale decreases, versus non-outage
years.
|
·
|
Over
the next few years, we expect rising employee benefit costs
as well as
higher insurance and security costs associated with additional
measures we
have taken, or may need to take, at UE’s Callaway nuclear plant and at our
other facilities. Insurance premiums may also increase as a
result of the
Taum Sauk incident, among other
things.
|
·
|
Bad
debts may increase due to rising electric
rates.
|
·
|
We
are currently undertaking cost reduction and control initiatives
associated with the strategic sourcing of purchases and streamlining
of
all aspects of our business.
|
·
|
The
EPA has issued more stringent emission limits on all coal-fired
power
plants. Between 2007 and 2016, Ameren expects that certain
Ameren
Companies will be required to invest between $3.5 billion and
$4.5 billion
to retrofit their power plants with pollution control equipment.
These
investments will also result in decreased plant availability
during
construction and significantly higher ongoing operating expenses.
Approximately 50% of this investment will be in Ameren’s regulated UE
operations, and it is therefore expected to be recoverable
from
ratepayers. The recoverability of amounts expended in non-rate-regulated
operations will depend on whether market prices for power adjust
as a
result of this increased
investment.
|
·
|
Ameren
will provide a report on how it is responding to rising regulatory,
competitive, and public pressure to significantly reduce carbon
dioxide
and other emissions from current and proposed power plant operations.
The
report will include Ameren’s climate change strategy and activities,
current greenhouse gas emissions, and analysis with respect
to plausible
future greenhouse gas scenarios. Ameren will publish this report
on its
Web site by December 15, 2007. Investments to control carbon
emissions at
Ameren’s coal-fired plants would significantly increase future capital
expenditures.
|
·
|
UE
continues to evaluate its longer-term needs for new baseload
and peaking
electric generation capacity. At this time, UE does not expect
to require
new baseload generation capacity until at least 2018. However,
due to the
significant time required to plan, acquire permits for and
build a
baseload power plant, UE is actively studying future plant
alternatives,
including those that would use coal or nuclear fuel. In 2007,
UE signed an
agreement with UniStar Nuclear to assist UE in the preparation
of a
combined construction and operating license application (COLA)
for filing
with the NRC. A COLA describes how a nuclear plant would be
designed,
constructed and operated. In addition, UE has also signed contracts
for
certain long lead-time equipment. Preparing a COLA and entering
into these
contracts does not mean a decision has been made to build a
nuclear plant.
They are only the first steps in the regulatory licensing and
procurement
process. UE and UniStar Nuclear must submit the
COLA
|
|
to
the NRC in 2008 to be eligible for incentives available
under provisions
of the 2005 Energy Policy
Act.
|
·
|
Over
the next few years, we expect to make significant investments
in our
electric and gas infrastructure to improve overall system reliability
in
addition to addressing environmental compliance requirements.
We are
projecting higher labor and material costs for these capital
expenditures.
|
·
|
Severe
storms in 2006 and early 2007 resulted in electric outages
for more than
1.5 million customers and an increased focus on alternatives
for improving
reliability during severe storms. UE, CIPS, CILCO and IP are
studying
alternatives to improve system reliability, which could result
in
increased investment in system infrastructure or higher maintenance
expenses. UE announced in July 2007 plans to spend $300 million
over three
years for underground cabling and reliability improvement,
$135 million
($45 million per year) for tree-trimming, and $84 million over
three years
(approximately $28 million per year) for circuit and device
inspection and
repair. We would expect any additional costs or investments
to be
recovered in rates.
|
·
|
The
MoPSC has initiated a rulemaking process to develop reliability
rules
applicable to Missouri investor-owned utilities that address
three focus
areas: vegetation management, infrastructure inspection, and
reliability.
The MoPSC’s proposed vegetation management and infrastructure inspection
rules were published in the Missouri Register in July 2007,
and a public
hearing on these rules is scheduled for August 15, 2007. The
MoPSC’s
proposed reliability rules have not yet been published in the
Missouri
Register. The ultimate cost of the rules is subject to their
final terms,
but could be material. UE anticipates that most of such costs
would
ultimately be recoverable in rates.
|
·
|
In
2006, Ameren realized gains on sales of noncore properties,
including
leveraged leases. The net benefit of these sales to Ameren
in 2006 was 16
cents per share. Ameren continues to pursue the sale of its
interests in
its remaining three leveraged lease assets. Ameren does not
expect to
achieve similar sales levels of noncore properties in
2007.
|
·
|
As
a result of the termination of the JDA on December 31, 2006,
UE and Genco
no longer have the obligation to provide power to each other.
UE is able
to sell any excess power it has at market prices, which we
believe will
most likely be higher than the prices paid to it by Genco.
Genco will no
longer receive the margins on sales that it made, which were
fulfilled
with power from UE. The electric rate order issued in May 2007
by the
MoPSC incorporated the net decrease in UE’s revenue requirement from
increased margins expected to result from the termination of
the JDA. See
Note 7 – Related Party Transactions to our financial statements under
Part
I, Item 1, of this report for a discussion of the effects of
terminating
the JDA.
|
Interest
Expense
|
Net
Income(a)
|
||||||
Ameren
|
$ |
24
|
$ |
(15)
|
|||
UE
|
9
|
(6)
|
|||||
CIPS
|
2
|
(1)
|
|||||
Genco
|
2
|
(1)
|
|||||
CILCORP
|
5
|
(3)
|
|||||
CILCO
|
3
|
(2)
|
|||||
IP
|
7
|
(4)
|
(a)
|
Calculations
are based on an effective tax rate of
38%.
|
Net
Income
|
|||
Ameren
|
$ |
(25)
|
|
UE
|
(10)
|
||
Genco
|
(10)
|
||
CILCO
(AERG)
|
(3)
|
||
EEI
|
(2)
|
a)
|
Calculations
are based on an effective tax rate of
38%
|
2007
|
2008
|
2009
–
2011
|
|||||||||
Ameren:
|
|||||||||||
Coal
|
100%
|
95%
|
40%
|
||||||||
Coal
transportation
|
100
|
95
|
46
|
||||||||
Nuclear
fuel
|
100
|
91
|
52
|
||||||||
Natural
gas for generation
|
55
|
12
|
-
|
||||||||
Natural
gas for distribution(a)
|
(a)
|
31
|
9
|
||||||||
Purchased
power for Illinois Regulated(b)
|
100
|
81
|
21
|
||||||||
UE:
|
|
||||||||||
Coal
|
100%
|
94%
|
41%
|
||||||||
Coal
transportation
|
100
|
97
|
61
|
||||||||
Nuclear
fuel
|
100
|
91
|
52
|
||||||||
Natural
gas for generation
|
36
|
8
|
-
|
||||||||
Natural
gas for distribution(a)
|
(a)
|
32
|
5
|
||||||||
CIPS:
|
|
||||||||||
Natural
gas for distribution(a)
|
(a)
|
32%
|
13%
|
||||||||
Purchased
power(b)
|
100%
|
81
|
21
|
||||||||
Genco:
|
|
||||||||||
Coal
|
100%
|
95%
|
38%
|
||||||||
Coal
transportation
|
100
|
97
|
45
|
||||||||
Natural
gas for generation
|
100
|
15
|
-
|
||||||||
CILCORP/CILCO:
|
|||||||||||
Coal
(AERG)
|
99%
|
96%
|
41%
|
||||||||
Coal
transportation (AERG)
|
100
|
71
|
23
|
||||||||
Natural
gas for distribution(a)
|
(a)
|
24
|
7
|
||||||||
Purchased
power(b)
|
100
|
81
|
21
|
||||||||
IP:
|
|||||||||||
Natural
gas for distribution(a)
|
(a)
|
35%
|
9%
|
||||||||
Purchased
power(b)
|
100%
|
81
|
21
|
2007
|
2008
|
2009
–
2011
|
|||||||||
EEI:
|
|||||||||||
Coal
|
100%
|
97%
|
42%
|
||||||||
Coal
transportation
|
100
|
100
|
-
|
(a)
|
The
year 2007 is non-applicable for this table. The year 2008 represents
November 2007 through March 2008. This continues each successive
year
through March 2011.
|
(b)
|
Represents
the percentage of purchased power price-hedged for fixed-price
residential
and small commercial customers with less than 1 megawatt of
demand as part
of the Illinois power procurement auction held in early September
2006. Excluded from the percent hedged amount is purchased power
for
fixed-price large commercial and industrial customers with
1 megawatt of
demand or higher. Nearly all of these customers chose a third-party
supplier. However, regardless of whether customers choose a
third-party
supplier, the purchased power needed to serve this load is
100%
price-hedged through May 31, 2008, due to the Illinois auction. Also
excluded from the percent hedged amount is purchased power
to serve large
service real-time pricing customers. See Note 2 – Rate and Regulatory
Matters and Note 8 – Commitments and Contingencies to our financial
statements under Part I, Item 1, of this report for a discussion
of this
matter.
|
Coal
|
Transportation
|
||||||||||||||
Fuel
Expense
|
Net
Income(a)
|
Fuel
Expense
|
Net
Income(a)
|
||||||||||||
Ameren(b)
|
$ |
12
|
$ | (8 | ) | $ |
14
|
$ | (9 | ) | |||||
UE
|
6
|
(4 | ) |
5
|
(3 | ) | |||||||||
Genco
|
4
|
(2 | ) |
4
|
(2 | ) | |||||||||
CILCORP
|
2
|
(1 | ) |
2
|
(1 | ) | |||||||||
CILCO
(AERG)
|
2
|
(1 | ) |
2
|
(1 | ) | |||||||||
EEI
|
1
|
(1 | ) |
4
|
(2 | ) |
(a)
|
Calculations
are based on an effective tax rate of
38%.
|
(b)
|
Includes
amounts for Ameren registrant and nonregistrant
subsidiaries.
|
Ameren(a)
|
UE
|
CIPS
|
Genco(b)
|
CILCORP/
CILCO
|
IP
|
|||||||||||||||||||
Three
Months
|
||||||||||||||||||||||||
Fair
value of contracts at beginning of period, net
|
$ |
31
|
$ |
-
|
$ |
3
|
$ | (1 | ) | $ |
6
|
$ |
-
|
|||||||||||
Contracts
realized or otherwise settled during the period
|
(5 | ) | (2 | ) | (1 | ) |
-
|
(2 | ) |
-
|
||||||||||||||
Changes
in fair values attributable to changes in valuation technique
and
assumptions
|
-
|
-
|
-
|
-
|
-
|
-
|
||||||||||||||||||
Fair
value of new contracts entered into during the period
|
22
|
(2 | ) |
-
|
-
|
-
|
-
|
|||||||||||||||||
Other
changes in fair value
|
21
|
9
|
(1 | ) | (1 | ) |
-
|
-
|
||||||||||||||||
Fair
value of contracts outstanding at end of period, net
|
$ |
69
|
$ |
5
|
$ |
1
|
$ | (2 | ) | $ |
4
|
$ |
-
|
|||||||||||
Six
Months
|
||||||||||||||||||||||||
Fair
value of contracts at beginning of period, net
|
$ |
98
|
$ |
12
|
$ |
2
|
$ | (1 | ) | $ |
6
|
$ |
2
|
|||||||||||
Contracts
realized or otherwise settled during the period
|
(22 | ) | (6 | ) | (1 | ) |
-
|
(4 | ) |
-
|
||||||||||||||
Changes
in fair values attributable to changes in valuation technique
and
assumptions
|
-
|
-
|
-
|
-
|
-
|
-
|
||||||||||||||||||
Fair
value of new contracts entered into during the period
|
20
|
(3 | ) |
-
|
-
|
-
|
-
|
|||||||||||||||||
Other
changes in fair value
|
(27 | ) |
2
|
-
|
(1 | ) |
2
|
(2 | ) | |||||||||||||||
Fair
value of contracts outstanding at end of period, net
|
$ |
69
|
$ |
5
|
$ |
1
|
$ | (2 | ) | $ |
4
|
$ |
-
|
(a)
|
Includes
amounts for Ameren registrant and nonregistrant subsidiaries
and
intercompany eliminations.
|
(b)
|
In
conjunction with the new power supply agreement between Marketing
Company
and Genco that went into effect January 1, 2007, the mark-to-market
value
of hedges entered into during 2006 for Genco was transferred
from Genco to
Marketing Company.
|
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
|
||||||||||||||
Ameren:
|
|||||||||||||||||||
Prices
actively
quoted
|
$ |
8
|
$ |
-
|
$ |
-
|
$ |
-
|
$ |
8
|
|||||||||
Prices
provided by other external sources(a)
|
1
|
-
|
-
|
-
|
1
|
||||||||||||||
Prices
based on models and other valuation methods(b)
|
41
|
19
|
-
|
-
|
60
|
||||||||||||||
Total
|
$ |
50
|
$ |
19
|
$ |
-
|
$ |
-
|
$ |
69
|
|||||||||
UE:
|
|||||||||||||||||||
Prices
actively
quoted
|
$ |
2
|
$ |
-
|
$ |
-
|
$ |
-
|
$ |
2
|
|||||||||
Prices
provided by other external sources(a)
|
-
|
-
|
-
|
-
|
-
|
||||||||||||||
Prices
based on models and other valuation methods(b)
|
2
|
1
|
-
|
-
|
3
|
||||||||||||||
Total
|
$ |
4
|
$ |
1
|
$ |
-
|
$ |
-
|
$ |
5
|
|||||||||
CIPS:
|
|||||||||||||||||||
Prices
actively
quoted
|
$ |
-
|
$ |
-
|
$ |
-
|
$ |
-
|
$ |
-
|
|||||||||
Prices
provided by other external sources(a)
|
1
|
-
|
-
|
-
|
1
|
||||||||||||||
Prices
based on models and other valuation methods(b)
|
-
|
-
|
-
|
-
|
-
|
||||||||||||||
Total
|
$ |
1
|
$ |
-
|
$ |
-
|
$ |
-
|
$ |
1
|
|||||||||
Genco:
|
|||||||||||||||||||
Prices
actively
quoted
|
$ | (1 | ) | $ | (1 | ) | $ |
-
|
$ |
-
|
$ | (2 | ) | ||||||
Prices
provided by other external sources(a)
|
-
|
-
|
-
|
-
|
-
|
||||||||||||||
Prices
based on models and other valuation methods(b)
|
-
|
-
|
-
|
-
|
-
|
||||||||||||||
Total
|
$ | (1 | ) | $ | (1 | ) | $ |
-
|
$ |
-
|
$ | (2 | ) | ||||||
CILCORP/CILCO:
|
|||||||||||||||||||
Prices
actively
quoted
|
$ |
1
|
$ |
-
|
$ |
-
|
$ |
-
|
$ |
1
|
|||||||||
Prices
provided by other external sources(a)
|
3
|
-
|
-
|
-
|
3
|
||||||||||||||
Prices
based on models and other valuation methods(b)
|
-
|
-
|
-
|
-
|
-
|
||||||||||||||
Total
|
$ |
4
|
$ |
-
|
$ |
-
|
$ |
-
|
$ |
4
|
|||||||||
IP:
|
|||||||||||||||||||
Prices
actively
quoted
|
$ |
-
|
$ |
-
|
$ |
-
|
$ |
-
|
$ |
-
|
|||||||||
Prices
provided by other external sources(a)
|
-
|
-
|
-
|
-
|
-
|
||||||||||||||
Prices
based on models and other valuation methods(b)
|
-
|
-
|
-
|
-
|
-
|
||||||||||||||
Total
|
$ |
-
|
$ |
-
|
$ |
-
|
$ |
-
|
$ |
-
|
(a)
|
Principally
fixed price for floating over-the-counter power swaps, power
forwards and
fixed price for floating over-the-counter natural gas
swaps.
|
(b)
|
Principally
coal and SO2
option values
based on a Black-Scholes model that includes information from
external
sources and our estimates. Also includes interruptible power
forward and
option contract values based on our
estimates.
|
(a)
|
Evaluation
of Disclosure Controls and
Procedures
|
(b)
|
Change
in Internal Controls
|
·
|
uncertainty
as to the implementation of the new power procurement process
in Illinois
for 2008 and 2009, including ICC review and approval requirements,
the
role of the IPA, and the ability of the Ameren Illinois Utilities
to
lease, or invest in, generation
facilities;
|
·
|
the
increase in short-term or long-term borrowings by the Ameren
Illinois
Utilities, Genco and AERG to fund contributions under the program
and
agreement;
|
·
|
the
failure by the electric generators that are party to the agreement
to
perform in a timely manner under their respective funding agreements,
which permits the Ameren Illinois Utilities to seek reimbursement
for a
portion of the rate relief that will be provided to certain
of their
electric customers;
|
·
|
the
exposure of Genco and AERG to changes in market prices as a
result of the
financial swap contracts that Marketing Company (on behalf
of Genco and
AERG) entered into with the Ameren Illinois Utilities;
and
|
·
|
the
extent to which Genco and AERG will be successful in making
future sales
to supply a portion of Illinois' total electric demand through
the revised
power procurement mechanism.
|
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
|
||||||||||||
April
1 – April 30,
2007
|
600
|
$ |
50.88
|
-
|
-
|
|||||||||||
May
1 – May 31,
2007
|
-
|
-
|
-
|
-
|
||||||||||||
June
1 – June 30,
2007
|
-
|
-
|
-
|
-
|
||||||||||||
Total
|
600
|
$ |
50.88
|
-
|
-
|
(a)
|
These
shares of Ameren common stock were purchased by Ameren in open-market
transactions in satisfaction of Ameren’s obligation upon the exercise by
employees of options issued under Ameren’s Long-term Incentive Plan of
1998, as amended. Ameren does not have any publicly announced
equity
securities repurchase plans or
programs.
|
Item
(1)
|
Election
of 12 directors (comprising Ameren’s full Board of Directors) to serve
until the next annual meeting of shareholders in
2008.
|
Name
|
For
|
Withheld
|
Broker
Non-Votes(a)
|
Stephen
F. Brauer
|
172,744,706
|
3,380,682
|
-
|
Susan
S. Elliott
|
172,623,835
|
3,501,553
|
-
|
Gayle
P. W. Jackson
|
172,735,245
|
3,390,143
|
-
|
James
C. Johnson
|
172,735,312
|
3,390,076
|
-
|
Richard
A. Liddy
|
172,062,753
|
4,062,635
|
-
|
Gordon
R. Lohman
|
172,404,949
|
3,720,439
|
-
|
Charles
W. Mueller
|
172,537,140
|
3,588,248
|
-
|
Douglas
R. Oberhelman
|
171,969,174
|
4,156,214
|
-
|
Gary
L. Rainwater
|
172,095,957
|
4,029,431
|
-
|
Harvey
Saligman
|
172,438,721
|
3,686,667
|
-
|
Patrick
T. Stokes
|
172,621,903
|
3,503,485
|
-
|
Jack
D. Woodard
|
172,727,233
|
3,398,155
|
-
|
(a)
|
Broker
shares included in the quorum but not voting on the
item.
|
Item
(2)
|
Ameren
proposal regarding ratification of the appointment of
PricewaterhouseCoopers LLP as Ameren’s independent registered public
accountants for the fiscal year ending December 31,
2007.
|
For
|
Against
|
Abstain
|
Broker
Non-Votes(a)
|
173,027,701
|
1,298,461
|
1,799,226
|
-
|
(a)
|
Broker
shares included in the quorum but not voting on the
item.
|
Item
(3)
|
Shareholder
proposal requesting a report on releases from UE’s Callaway nuclear
plant.
|
For
|
Against
|
Abstain
|
Broker
Non-Votes(a)
|
10,401,287
|
106,900,549
|
12,280,634
|
46,542,918
|
(a)
|
Broker
shares included in the quorum but not voting on the
item.
|
Exhibit
Designation
|
Registrant(s)
|
Nature
of Exhibit
|
Previously
Filed as Exhibit to:
|
Instruments
Defining Rights of Securities Holders, Including
Indentures
|
|||
4.1
|
Ameren
UE
|
UE
Company Order dated June 15, 2007,
establishing
the 6.40% Senior Secured Notes
due
2017 (including the global note)
|
June
15, 2007 Form 8-K, Exhibits
4.2
and 4.3, File No. 1-2967
|
4.2
|
Ameren
UE
|
Supplemental
Indenture dated June 1, 2007
by
and between UE and The Bank of New
York,
as Trustee under the Indenture of
Mortgage
and Deed of Trust dated June 15,
1937,
as amended, relating to the First
Mortgage
Bonds, Senior Notes Series KK
securing
the 6.40% Senior Notes due 2017
|
June
15, 2007 Form 8-K, Exhibit
4.5,
File No. 1-2967
|
Statement
re: Computation of Ratios
|
|||
12.1
|
Ameren
|
Ameren’s
Statement of Computation of Ratio
of
Earnings to Fixed Charges
|
|
12.2
|
UE
|
UE’s
Statement of Computation of Ratio of
Earnings
to Fixed Charges and Combined
Fixed
Charges and Preferred Stock Dividend
Requirements
|
|
12.3
|
CIPS
|
CIPS’
Statement of Computation of Ratio of
Earnings
to Fixed Charges and Combined
Fixed
Charges and Preferred Stock Dividend
Requirements
|
|
12.4
|
Genco
|
Genco’s
Statement of Computation of Ratio
of
Earnings to Fixed Charges
|
|
12.5
|
CILCORP
|
CILCORP’s
Statement of Computation of
Ratio
of Earnings to Fixed Charges
|
|
12.6
|
CILCO
|
CILCO’s
Statement of Computation of Ratio
of
Earnings to Fixed Charges and Combined
Fixed
Charges and Preferred Stock Dividend
Requirements
|
|
12.7
|
IP
|
IP’s
Statement of Computation of Ratio of
Earnings
to Fixed Charges and Combined
Fixed
Charges and Preferred Stock Dividend
Requirements
|
Exhibit
Designation
|
Registrant(s)
|
Nature
of Exhibit
|
Previously
Filed as Exhibit to:
|
Rule 13a-14(a) / 15d-14(a) Certifications | |||
31.1
|
Ameren |
Rule
13a-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
|
Rule
13a-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
|
|
31.13
|
IP
|
Rule
13a-14(a)/15d-14(a) Certification of
Principal
Executive Officer of IP
|
|
31.14
|
IP
|
Rule
13a-14(a)/15d-14(a) Certification of
Principal
Financial Officer of IP
|
|
Section
1350 Certifications
|
|||
32.1
|
Ameren
|
Section
1350 Certification of Principal
Executive
Officer and Principal Financial
Officer
of Ameren
|
|
32.2
|
UE
|
Section
1350 Certification of Principal
Executive
Officer
and Principal Financial
Officer
of UE
|
|
32.3
|
CIPS
|
Section
1350 Certification of Principal
Executive
Officer and Principal Financial
Officer
of CIPS
|
|
32.4
|
Genco
|
Section
1350 Certification of Principal
Executive
Officer and Principal Financial
Officer
of Genco
|
|
32.5
|
CILCORP
|
Section
1350 Certification of Principal
Executive
Officer and Principal Financial
Officer
of CILCORP
|
|
32.6
|
CILCO
|
Section
1350 Certification of Principal
Executive
Officer and Principal Financial
Officer
of CILCO
|
|
32.7
|
IP
|
Section
1350 Certification of Principal
Executive
Officer and Principal Financial
Officer
of IP
|