Commission
|
Registrant,
State of Incorporation,
|
I.R.S.
Employer
|
||
File
Number
|
Address
of Principal Executive Offices, and Telephone Number
|
Identification
No.
|
||
1-3525
|
AMERICAN
ELECTRIC POWER COMPANY, INC. (A New York Corporation)
|
13-4922640
|
||
0-18135
|
AEP
GENERATING COMPANY (An Ohio Corporation)
|
31-1033833
|
||
0-346
|
AEP
TEXAS CENTRAL COMPANY (A Texas Corporation)
|
74-0550600
|
||
0-340
|
AEP
TEXAS NORTH COMPANY (A Texas Corporation)
|
75-0646790
|
||
1-3457
|
APPALACHIAN
POWER COMPANY (A Virginia Corporation)
|
54-0124790
|
||
1-2680
|
COLUMBUS
SOUTHERN POWER COMPANY (An Ohio Corporation)
|
31-4154203
|
||
1-3570
|
INDIANA
MICHIGAN POWER COMPANY (An Indiana Corporation)
|
35-0410455
|
||
1-6858
|
KENTUCKY
POWER COMPANY (A Kentucky Corporation)
|
61-0247775
|
||
1-6543
|
OHIO
POWER COMPANY (An Ohio Corporation)
|
31-4271000
|
||
0-343
|
PUBLIC
SERVICE COMPANY OF OKLAHOMA (An Oklahoma Corporation)
|
73-0410895
|
||
1-3146
|
SOUTHWESTERN
ELECTRIC POWER COMPANY (A Delaware Corporation)
|
72-0323455
|
||
All
Registrants
|
1
Riverside Plaza, Columbus, Ohio 43215-2373
|
|||
Telephone
(614) 716-1000
|
Indicate
by check mark whether the registrants (1) have filed all reports
required
to be filed by Section 13 or 15(d) of the Securities Exchange Act
of 1934
during the preceding 12 months (or for such shorter period that
the
registrants were required to file such reports), and (2) have been
subject
to such filing requirements for the past 90 days.
|
|
Yes
X
|
NO
___
|
Indicate
by check mark whether American Electric Power Company, Inc. is
an
accelerated filer (as defined in Rule 12b-2 of the Exchange
Act).
|
|
Yes
X
|
NO
___
|
Indicate
by check mark whether AEP Generating Company, AEP Texas Central
Company,
AEP Texas North Company, Appalachian Power Company, Columbus Southern
Power Company, Indiana Michigan Power Company, Kentucky Power Company,
Ohio Power Company, Public Service Company of Oklahoma and Southwestern
Electric Power Company, are accelerated filers (as defined in Rule
12b-2
of the Exchange Act).
|
|
Yes
___
|
NO
X
|
Number
of Shares of Common Stock Outstanding at July 29,
2005
|
|||
American
Electric Power Company, Inc.
|
384,772,013
|
||
AEP
Generating Company
|
1,000
|
||
AEP
Texas Central Company
|
2,211,678
|
||
AEP
Texas North Company
|
5,488,560
|
||
Appalachian
Power Company
|
13,499,500
|
||
Columbus
Southern Power Company
|
16,410,426
|
||
Indiana
Michigan Power Company
|
1,400,000
|
||
Kentucky
Power Company
|
1,009,000
|
||
Ohio
Power Company
|
27,952,473
|
||
Public
Service Company of Oklahoma
|
9,013,000
|
||
Southwestern
Electric Power Company
|
7,536,640
|
||
|
||||
Glossary
of Terms
|
||||
Forward-Looking
Information
|
|
|||
Part
I. FINANCIAL INFORMATION
|
||||
Items
1, 2 and 3 - Financial Statements, Management’s Financial Discussion and
Analysis and Quantitative and
Qualitative Disclosures
About Risk Management Activities:
|
||||
American
Electric Power Company, Inc. and Subsidiary
Companies:
|
||||
Management’s
Financial Discussion and Analysis of Results of Operations
|
|
|||
Quantitative
and Qualitative Disclosures About Risk Management
Activities
|
|
|||
Condensed
Consolidated Financial Statements
|
|
|||
Condensed
Notes to Consolidated Financial Statements
|
|
|||
AEP
Generating Company:
|
||||
Management’s
Narrative Financial Discussion and Analysis
|
|
|||
Condensed
Financial Statements
|
|
|||
AEP
Texas Central Company and Subsidiary:
|
||||
Management’s
Financial Discussion and Analysis
|
|
|||
Quantitative
and Qualitative Disclosures About Risk Management
Activities
|
|
|||
Condensed
Consolidated Financial Statements
|
|
|||
AEP
Texas North Company:
|
||||
Management’s
Narrative Financial Discussion and Analysis
|
|
|||
Quantitative
and Qualitative Disclosures About Risk Management
Activities
|
|
|||
Condensed
Financial Statements
|
|
|||
Appalachian
Power Company and Subsidiaries:
|
||||
Management’s
Financial Discussion and Analysis
|
|
|||
Quantitative
and Qualitative Disclosures About Risk Management
Activities
|
|
|||
Condensed
Consolidated Financial Statements
|
|
|||
Columbus
Southern Power Company and Subsidiaries:
|
||||
Management’s
Narrative Financial Discussion and Analysis
|
|
|||
Quantitative
and Qualitative Disclosures About Risk Management
Activities
|
|
|||
Condensed
Consolidated Financial Statements
|
|
|||
Indiana
Michigan Power Company and Subsidiaries:
|
||||
Management’s
Financial Discussion and Analysis
|
|
|||
Quantitative
and Qualitative Disclosures About Risk Management
Activities
|
|
|||
Condensed
Consolidated Financial Statements
|
|
|||
Kentucky
Power Company:
|
||||
Management’s
Narrative Financial Discussion and Analysis
|
|
|||
Quantitative
and Qualitative Disclosures About Risk Management
Activities
|
|
|||
Condensed
Financial Statements
|
|
|||
Ohio
Power Company Consolidated:
|
||||
Management’s
Financial Discussion and Analysis
|
|
|||
Quantitative
and Qualitative Disclosures About Risk Management
Activities
|
|
|||
Condensed
Consolidated Financial Statements
|
|
|||
Public
Service Company of Oklahoma:
|
|||||||
Management’s
Narrative Financial Discussion and Analysis
|
|
||||||
Quantitative
and Qualitative Disclosures About Risk Management
Activities
|
|
||||||
Condensed
Financial Statements
|
|
||||||
Southwestern
Electric Power Company Consolidated:
|
|||||||
Management’s
Financial Discussion and Analysis
|
|
||||||
Quantitative
and Qualitative Disclosures About Risk Management
Activities
|
|
||||||
Condensed
Consolidated Financial Statements
|
|
||||||
Condensed
Notes to Financial Statements of Registrant Subsidiaries
|
|
||||||
Combined
Management’s Discussion and Analysis of Registrant
Subsidiaries
|
|
||||||
Item
4.
|
Controls
and Procedures
|
|
|||||
Part
II. OTHER INFORMATION
|
|||||||
Item
1.
|
Legal
Proceedings
|
|
|||||
Item
2.
|
Unregistered
Sales of Equity Securities and Use of Proceeds
|
|
|||||
Item
4.
|
Submission
of Matters to a Vote of Security Holders
|
|
|||||
Item
5.
|
Other
Information
|
|
|||||
Item
6.
|
Exhibits
|
|
|||||
Exhibits:
|
|||||||
Exhibit
10 (a)
|
|||||||
Exhibit
10 (b)
|
|||||||
Exhibit
12
|
|||||||
Exhibit
31(a)
|
|||||||
Exhibit
31(b)
|
|||||||
Exhibit
31(c)
|
|||||||
Exhibit
31(d)
|
|||||||
Exhibit
32(a)
|
|||||||
Exhibit
32(b)
|
|||||||
SIGNATURE
|
|
This
combined Form 10-Q is separately filed by American Electric Power
Company,
Inc., AEP Generating Company, AEP Texas Central Company, AEP Texas
North
Company, Appalachian Power Company, Columbus Southern Power Company,
Indiana Michigan Power Company, Kentucky Power Company, Ohio Power
Company, Public Service Company of Oklahoma and Southwestern Electric
Power Company. Information contained herein relating to any individual
registrant is filed by such registrant on its own behalf. Each
registrant
makes no representation as to information relating to the other
registrants.
|
Term
|
Meaning
|
AEGCo
|
AEP Generating Company, an electric utility subsidiary of
AEP.
|
|
AEP
or Parent
|
American
Electric Power Company, Inc.
|
|
AEP
Consolidated
|
AEP
and its majority owned consolidated subsidiaries and consolidated
affiliates.
|
|
AEP
Credit
|
AEP
Credit, Inc., a subsidiary of AEP which factors accounts receivable
and
accrued utility revenues for
affiliated domestic electric utility companies.
|
|
AEP
East companies
|
APCo,
CSPCo, I&M, KPCo and OPCo.
|
|
AEPES
|
AEP
Energy Services, Inc., a subsidiary of AEP Resources,
Inc.
|
|
AEP
System or the System
|
American
Electric Power System, an integrated electric utility system, owned
and
operated by AEP’s electric
utility subsidiaries.
|
|
AEP
System Power Pool or AEP
Power Pool
|
Members
are APCo, CSPCo, I&M, KPCo and OPCo. The Pool shares the generation,
cost of generation and resultant
wholesale off-system sales of the member companies.
|
|
AEPSC
|
American
Electric Power Service Corporation, a service subsidiary providing
management and professional
services to AEP and its subsidiaries.
|
|
AEP
West companies
|
PSO,
SWEPCo, TCC and TNC.
|
|
AFUDC
|
Allowance
for Funds Used During Construction.
|
|
ALJ
|
Administrative
Law Judge.
|
|
APCo
|
Appalachian
Power Company, an AEP electric utility subsidiary.
|
|
ARO
|
Asset
Retirement Obligations.
|
|
CAA
|
Clean
Air Act.
|
|
COLI
|
Corporate
owned, life insurance program.
|
|
Cook
Plant
|
The
Donald C. Cook Nuclear Plant, a two-unit, 2,110 MW nuclear plant
owned by
I&M.
|
|
CSPCo
|
Columbus
Southern Power Company, an AEP electric utility
subsidiary.
|
|
CSW
|
Central
and South West Corporation, a subsidiary of AEP (Effective January
21,
2003, the legal name of
Central and South West Corporation was changed to AEP Utilities,
Inc.).
|
|
DETM
|
Duke Energy Trading and Marketing L.L.C., a risk management
counterparty.
|
|
DOE
|
United States Department of Energy.
|
|
ECAR
|
East
Central Area Reliability Council.
|
|
EITF
|
Financial
Accounting Standards Board’s Emerging Issues Task
Force.
|
|
ERCOT
|
Electric
Reliability Council of Texas.
|
|
FASB
|
Financial
Accounting Standards Board.
|
|
Federal
EPA
|
United States Environmental Protection Agency.
|
|
FERC
|
Federal
Energy Regulatory Commission.
|
|
FIN
46
|
FASB
Interpretation No. 46, “Consolidation of Variable Interest
Entities.”
|
|
GAAP
|
Generally
Accepted Accounting Principles.
|
|
HPL
|
Houston
Pipeline Company.
|
|
I&M
|
Indiana
Michigan Power Company, an AEP electric utility
subsidiary.
|
|
IPP
|
Independent
Power Producers.
|
|
IURC
|
Indiana
Utility Regulatory Commission.
|
|
JMG
|
JMG
Funding LP.
|
|
KPCo
|
Kentucky
Power Company, an AEP electric utility subsidiary.
|
|
KPSC
|
Kentucky
Public Service Commission.
|
|
KWH
|
Kilowatthour.
|
|
LIG
|
Louisiana
Intrastate Gas, a former AEP subsidiary.
|
|
ME
SWEPCo
|
Mutual
Energy SWEPCo L.P., a Texas retail electric provider.
|
|
MLR
|
Member
load ratio, the method used to allocate AEP Power Pool transactions
to its
members.
|
|
MTM
|
Mark-to-Market.
|
|
MW
|
Megawatt.
|
|
MWH
|
Megawatthour.
|
|
NOx
|
Nitrogen
oxide.
|
|
Nonutility
Money Pool
|
AEP
System’s Nonutility Money Pool.
|
|
NYMEX
|
New
York Mercantile Exchange.
|
|
OATT
|
Open
Access Transmission Tariff.
|
|
OCC
|
Oklahoma
Corporation Commission.
|
|
OPCo
|
Ohio
Power Company, an AEP electric utility subsidiary.
|
|
OTC
|
Over
the counter.
|
|
PJM
|
Pennsylvania
- New Jersey - Maryland regional transmission
organization.
|
|
PSO
|
Public
Service Company of Oklahoma, an AEP electric utility
subsidiary.
|
|
PUCO
|
Public
Utilities Commission of Ohio
|
|
PUCT
|
The
Public Utility Commission of Texas.
|
|
PUHCA
|
Public
Utility Holding Company Act.
|
|
PURPA
|
Public
Utility Regulatory Policies Act of 1978.
|
|
Registrant
Subsidiaries
|
AEP
subsidiaries which are SEC registrants; AEGCo, APCo, CSPCo, I&M, KPCo,
OPCo, PSO, SWEPCo,
TCC and TNC.
|
|
REP
|
Texas Retail Electric Provider.
|
|
Risk
Management Contracts
|
Trading
and nontrading derivatives, including those derivatives designated
as cash
flow and fair value hedges.
|
|
Rockport
Plant
|
A
generating plant, consisting of two 1,300 MW coal-fired generating
units
near Rockport, Indiana owned by
AEGCo and I&M.
|
|
RTO
|
Regional
Transmission Organization.
|
|
S&P
|
Standard
and Poor’s.
|
|
SEC
|
United
States Securities and Exchange Commission.
|
|
SECA
|
Seams
Elimination Cost Allocation.
|
|
SFAS
|
Statement
of Financial Accounting Standards issued by the Financial Accounting
Standards Board.
|
|
SFAS
109
|
Statement
of Financial Accounting Standards No. 109, Accounting
for Income Taxes.
|
|
SFAS
133
|
Statement
of Financial Accounting Standards No. 133, Accounting
for Derivative Instruments and Hedging
Activities.
|
|
SNF
|
Spent
Nuclear Fuel.
|
|
SO2
|
Sulfur
Dioxide.
|
|
SPP
|
Southwest
Power Pool.
|
|
STP
|
South
Texas Project Nuclear Generating Plant.
|
|
SWEPCo
|
Southwestern
Electric Power Company, an AEP electric utility
subsidiary.
|
|
TCC
|
AEP
Texas Central Company, an AEP electric utility subsidiary.
|
|
Tenor
|
Maturity
of a contract.
|
|
TEM
|
SUEZ
Energy Marketing NA, Inc. (formerly known as Tractebel Energy Marketing,
Inc.)
|
|
Texas
Restructuring Legislation
|
Legislation
enacted in 1999 to restructure the electric utility industry in
Texas.
|
|
TNC
|
AEP
Texas North Company, an AEP electric utility subsidiary.
|
|
True-up
Proceeding
|
A
filing made under the Texas Restructuring Legislation to finalize
the
amount of stranded costs and other true-
up items and the recovery of such amounts.
|
|
TVA
|
Tennessee
Valley Authority.
|
|
Utility
Money Pool
|
AEP
System’s Utility Money Pool.
|
|
VaR
|
Value
at Risk, a method to quantify risk exposure.
|
|
Virginia
SCC
|
Virginia
State Corporation Commission.
|
|
WPCo
|
Wheeling
Power Company, an AEP electric distribution subsidiary.
|
|
Zimmer
Plant
|
William
H. Zimmer Generating Station, a 1,300 MW coal-fired unit owned
25.4% by
CSPCo.
|
·
|
Electric
load and customer growth.
|
·
|
Weather
conditions, including storms.
|
·
|
Available
sources and costs of, and transportation for, fuels and the
creditworthiness of fuel suppliers and transporters.
|
·
|
Availability
of generating capacity and the performance of our generating
plants.
|
·
|
The
ability to recover regulatory assets and stranded costs in connection
with
deregulation.
|
·
|
The
ability to recover increases in fuel and other energy costs through
regulated or competitive electric rates.
|
·
|
New
legislation, litigation and government regulation including requirements
for reduced emissions of sulfur, nitrogen, mercury, carbon and
other
substances.
|
·
|
Timing
and resolution of pending and future rate cases, negotiations and
other
regulatory decisions (including rate or other recovery for new
investments, transmission
service and environmental compliance).
|
·
|
Resolution
of litigation (including pending Clean Air Act enforcement actions
and
disputes arising from the bankruptcy of Enron Corp.).
|
·
|
Our
ability to constrain operation and maintenance costs.
|
·
|
Our
ability to sell assets at acceptable prices and other acceptable
terms,
including rights to share in earnings derived from the assets subsequent
to their sale.
|
·
|
The
economic climate and growth in our service territory and changes
in market
demand and demographic patterns.
|
·
|
Inflationary
trends.
|
·
|
Our
ability to develop and execute a strategy based on a view regarding
prices
of electricity, natural gas and other energy-related
commodities.
|
·
|
Changes
in the creditworthiness and number of participants in the energy
trading
market.
|
·
|
Changes
in the financial markets, particularly those affecting the availability
of
capital and our ability to refinance existing debt at attractive
rates.
|
·
|
Actions
of rating agencies, including changes in the ratings of
debt.
|
·
|
Volatility
and changes in markets for electricity, natural gas and other
energy-related commodities.
|
·
|
Changes
in utility regulation, including membership and integration into
regional
transmission structures.
|
·
|
Accounting
pronouncements periodically issued by accounting standard-setting
bodies.
|
·
|
The
performance of our pension and other postretirement benefit
plans.
|
·
|
Prices
for power that we generate and sell at wholesale.
|
·
|
Changes
in technology, particularly with respect to new, developing or
alternative
sources of generation.
|
·
|
Other
risks and unforeseen events, including wars, the effects of terrorism
(including increased security costs), embargoes and other catastrophic
events.
|
·
|
Sold
its ownership interest in the South Texas Project (STP) nuclear
plant for
approximately $314 million and the assumption of liabilities of
approximately $22 million;
|
·
|
Received
a good cause exception to the true-up rule to allow TCC to make
its
true-up filing prior to the closing of the sale of TCC’s ownership
interest in Oklaunion, which is still in litigation;
and
|
·
|
Submitted
its true-up filing to the PUCT for a final determination of stranded
costs
and other true-up amounts.
|
·
|
Utility
Operations:
|
|
·
|
Domestic
generation of electricity for sale to retail and wholesale
customers.
|
|
·
|
Domestic
electricity transmission and
distribution.
|
·
|
Investments-Gas
Operations:
|
|
·
|
Gas
pipeline and storage services.
|
|
·
|
Gas
marketing and risk management activities.
|
|
LIG Pipeline Company
and its
subsidiaries, including Jefferson Island Storage & Hub LLC, were
classified as discontinued operations during 2003
and were sold during 2004. We sold a 98% controlling interest in
HPL
during the first quarter of 2005.
|
·
|
Investments-UK
Operations:
|
|
·
|
Generation
of electricity in the U.K. for sale to wholesale
customers.
|
|
·
|
Coal
procurement and transportation to our plants.
|
|
UK Operations were classified as discontinued operations during 2003 and were sold during the third quarter of 2004. | ||
·
|
Investments-Other:
|
|
·
|
Bulk
commodity barging operations, wind farms, independent power producers
and
other energy
supply
related businesses.
|
|
|
||
Four independent power producers were sold during the third and fourth quarters of 2004. |
Three
Months Ended June 30,
|
Six
Months Ended June 30,
|
||||||||||||||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||||||||||||||
Earnings
|
EPS
|
Earnings
|
EPS
|
Earnings
|
EPS
|
Earnings
|
EPS
|
||||||||||||||||||
Utility
Operations
|
$
|
247
|
$
|
0.64
|
$
|
184
|
$
|
0.46
|
$
|
600
|
$
|
1.54
|
$
|
488
|
$
|
1.23
|
|||||||||
Investments
- Gas Operations
|
(2
|
)
|
(0.01
|
)
|
(4
|
)
|
(0.01
|
)
|
8
|
0.02
|
(14
|
)
|
(0.03
|
)
|
|||||||||||
Investments
- Other
|
(1
|
)
|
-
|
(4
|
)
|
(0.01
|
)
|
4
|
0.01
|
-
|
-
|
||||||||||||||
All
Other (a)
|
(26
|
)
|
(0.06
|
)
|
(25
|
)
|
(0.06
|
)
|
(40
|
)
|
(0.10
|
)
|
(34
|
)
|
(0.09
|
)
|
|||||||||
Income
Before Discontinued Operations
|
218
|
0.57
|
151
|
0.38
|
572
|
1.47
|
440
|
1.11
|
|||||||||||||||||
Investments
- Gas Operations
|
-
|
-
|
2
|
-
|
-
|
-
|
1
|
-
|
|||||||||||||||||
Investments
- UK Operations
|
-
|
-
|
(52
|
)
|
(0.13
|
)
|
(5
|
)
|
(0.01
|
)
|
(64
|
)
|
(0.16
|
)
|
|||||||||||
Investments
- Other
|
3
|
0.01
|
(1
|
)
|
-
|
9
|
0.02
|
5
|
0.01
|
||||||||||||||||
Discontinued
Operations, Net of Tax
|
3
|
0.01
|
(51
|
)
|
(0.13
|
)
|
4
|
0.01
|
(58
|
)
|
(0.15
|
)
|
|||||||||||||
Net
Income
|
$
|
221
|
$
|
0.58
|
$
|
100
|
$
|
0.25
|
$
|
576
|
$
|
1.48
|
$
|
382
|
$
|
0.96
|
|||||||||
Weighted
Average Shares Outstanding
|
384
|
396
|
389
|
396
|
Three
Months Ended June 30,
|
Six
Months Ended June
30,
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
(in
millions)
|
|||||||||||||
Revenues
|
$
|
2,668
|
$
|
2,545
|
$
|
5,282
|
$
|
5,147
|
|||||
Fuel
and Purchased Power
|
956
|
820
|
1,861
|
1,599
|
|||||||||
Gross
Margin
|
1,712
|
1,725
|
3,421
|
3,548
|
|||||||||
Depreciation
and Amortization
|
317
|
308
|
635
|
618
|
|||||||||
Other
Operating Expenses
|
943
|
994
|
1,814
|
1,882
|
|||||||||
Operating
Income
|
452
|
423
|
972
|
1,048
|
|||||||||
Other
Income (Expense), Net
|
56
|
16
|
204
|
26
|
|||||||||
Interest
Expense and Preferred Stock Dividend Requirements
|
156
|
161
|
300
|
327
|
|||||||||
Income
Taxes
|
105
|
94
|
276
|
259
|
|||||||||
Income
Before Discontinued Operations
|
$
|
247
|
$
|
184
|
$
|
600
|
$
|
488
|
Three
Months Ended
|
Six
Months Ended
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
Energy
Summary
|
(in
millions of KWH)
|
||||||||||||
Retail:
|
|||||||||||||
Residential
|
9,956
|
9,740
|
23,180
|
23,167
|
|||||||||
Commercial
|
9,573
|
9,390
|
18,305
|
18,169
|
|||||||||
Industrial
|
13,480
|
12,902
|
26,253
|
25,175
|
|||||||||
Miscellaneous
|
639
|
806
|
1,284
|
1,549
|
|||||||||
Total
Retail
|
33,648
|
32,838
|
69,022
|
68,060
|
|||||||||
Texas
Retail and Other
|
161
|
298
|
389
|
522
|
|||||||||
Total
|
33,809
|
33,136
|
69,411
|
68,582
|
|||||||||
Wholesale
|
12,138
|
13,644
|
24,773
|
27,495
|
|||||||||
Texas
Wires Delivery
|
6,736
|
6,250
|
12,254
|
11,740
|
Three
Months Ended
|
Six
Months Ended
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
Weather
Summary
|
(in
degree days)
|
||||||||||||
Eastern
Region
|
|||||||||||||
Actual
- Heating
|
165
|
168
|
1,939
|
2,032
|
|||||||||
Normal
- Heating (a)
|
176
|
180
|
1,988
|
1,986
|
|||||||||
Actual
- Cooling
|
287
|
313
|
287
|
316
|
|||||||||
Normal
- Cooling (a)
|
278
|
278
|
281
|
281
|
|||||||||
Western
Region
(b)
|
|||||||||||||
Actual
- Heating
|
26
|
30
|
795
|
913
|
|||||||||
Normal
- Heating (a)
|
33
|
33
|
1,006
|
1,012
|
|||||||||
Actual
- Cooling
|
681
|
659
|
701
|
689
|
|||||||||
Normal
- Cooling (a)
|
645
|
642
|
662
|
660
|
(a)
Normal Heating/Cooling represents the 30-year average of degree
days.
|
|
(b)
Western Region statistics represent PSO/SWEPCo customer base
only.
|
Second
Quarter of 2004
|
$
|
184
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins
|
5
|
||||||
Texas
Supply
|
(36
|
)
|
|||||
Transmission
Revenues
|
(21
|
)
|
|||||
Off-system
Sales
|
38
|
||||||
Other
Revenues
|
1
|
||||||
(13
|
)
|
||||||
Changes
in Operating Expenses And Other:
|
|||||||
Maintenance
and Other Operation
|
46
|
||||||
Depreciation
and Amortization
|
(9
|
)
|
|||||
Taxes
Other Than Income Taxes
|
5
|
||||||
Other
Income (Expense), Net
|
40
|
||||||
Interest
Expenses
|
5
|
||||||
87
|
|||||||
Income
Taxes
|
(11
|
)
|
|||||
Second
Quarter of 2005
|
$
|
247
|
·
|
Retail
margins in our utility business were $5 million higher than last
year. The
primary driver of this increase was a 3% increase in volume attributable
to load growth in residential and commercial classes as well as
favorable
weather in 2005. The margin increase related to load growth was
partially
offset by higher fuel costs of approximately $44 million, which
primarily
relates to our utilities in the East with inactive fuel clauses.
|
·
|
Our
Texas Supply business had a $36 million decrease in gross margin
as a
result of the sale of a majority of our Texas generation assets
in the
third quarter of 2004 and STP in May 2005.
|
·
|
Transmission
Revenues decreased $21 million primarily due to the loss of through
and
out rates as mandated by the FERC. Higher transmission revenues
in the
ECAR region because of the addition of SECA rates partially offset
the
change in FERC tariffs.
|
·
|
Margins
from Off-system Sales for 2005 were $38 million higher than 2004
primarily
due to higher volumes and favorable price
margins.
|
·
|
Maintenance
and Other Operation expenses decreased $46 million. Approximately
$11
million of the decrease is due to timing of maintenance projects
and
different spending patterns experienced in the second quarter of
2005 as
compared to the same period in 2004. Additionally, in 2004 we incurred
$20
million related to major storms. Also, an $18 million reduction
relates to
the sale of the Texas generation and STP assets and a $19 million
reduction relates to lower labor, incentives, fringes and outside
service
costs. These favorable variances were partially offset by a $22
million
severance accrual in 2005 as a result of our company-wide staffing
and
budget review, which will ultimately reduce our staffing levels
by 466
positions.
|
Six
Months Ended June 30, 2004
|
$
|
488
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins
|
(61
|
)
|
|||||
Texas
Supply
|
(56
|
)
|
|||||
Transmission
Revenues
|
(51
|
)
|
|||||
Off-system
Sales
|
34
|
||||||
Other
Revenues
|
7
|
||||||
(127
|
)
|
||||||
Changes
in Operating Expenses And Other:
|
|||||||
Maintenance
and Other Operation
|
67
|
||||||
Depreciation
and Amortization
|
(17
|
)
|
|||||
Taxes
Other Than Income Taxes
|
1
|
||||||
Other
Income (Expense), Net
|
178
|
||||||
Interest
Expenses
|
27
|
||||||
256
|
|||||||
Income
Taxes
|
(17
|
)
|
|||||
Six
Months Ended June 30, 2005
|
$
|
600
|
·
|
Overall
Retail Margins in our utility business were $61 million lower than
last
year. The primary driver of this decrease was higher delivered
fuel costs
of approximately $100 million, of which the majority relates to
our East
companies with inactive fuel clauses. The higher fuel costs were
partially
offset by continued customer growth and usage in our residential
and
commercial classes.
|
·
|
Our
Texas Supply business had a $56 million decrease in gross margin
due to
the sale of a majority of our Texas generation assets in the third
quarter
of 2004 and STP in May 2005.
|
·
|
Transmission
Revenues decreased $51 million primarily due to the loss of through
and
out rates as mandated by the FERC. Higher transmission revenues
in the
ECAR region because of the addition of SECA rates partially offset
the
change in FERC tariffs.
|
·
|
Margins
from Off-system Sales for 2005 were $34 million higher than 2004
primarily
due to a 3% growth in volume and favorable price margins partially
offset
by a $41 million decrease in optimization
activity.
|
·
|
Maintenance
and Other Operation expenses decreased $67 million. Approximately
$10
million of the decrease is due to timing of maintenance projects
and
different spending patterns experienced in the first six months
of 2005 as
compared to the same period in 2004. Expenses were lower by $60
million
primarily due to the cancellation of our COLI policies in 2005
and lower
labor, incentives and outside service costs in 2005. Also, a $19
million
reduction relates to the sale in 2004 of our Texas generation assets.
These favorable variances were partially offset by a $22 million
severance
accrual in 2005 as a result of our company-wide staffing and budget
review, which will ultimately reduce our staffing levels by 466
positions.
|
|
·
|
Other
Income (Expense), Net increased $178 million primarily due to the
following:
|
|
·
|
$112
million resulting from the receipt of revenues related to the earnings
sharing agreement with Centrica as stipulated in the purchase and
sale
agreement from the sale of our REPs in 2002. Agreement was reached
with
Centrica in March 2005 resolving disputes on how such amounts are
to be
calculated.
|
|
·
|
$37
million related to the recognition of carrying costs on environmental
and
RTO expenses by our Ohio companies related to the Rate Stabilization
Plans.
|
|
·
|
$15
million related to increased AFUDC due to extensive construction
activities occurring in 2005.
|
|
·
|
$15
million related to the recognition of carrying costs by TCC on
its net
stranded generation costs and its capacity auction true-up
asset.
|
|
·
|
Interest
Expenses decreased $27 million due to the refinancing of higher
coupon
debt and the retirement of debt in 2004 and in the first six months
of
2005.
|
·
|
A
$5 million decreased loss due to reductions in outstanding debt
at AEP
Communications that occurred in October 2004.
|
·
|
A
$3 million increased profit at MEMCO due to favorable operating
conditions
and strong freight rates in 2005.
|
·
|
A
$3 million increased loss at AEP Resources related to $1 million
of
increased losses from the Dow plant in 2005 and increased legal
and tax
expenses of $2 million in 2005.
|
·
|
The
remaining $2 million increased loss relates to several items at
various
subsidiaries, none of which is individually
significant.
|
·
|
A
$5 million increase at CSW Energy Services related to a current
year gain
due to a working capital true-up for our November 2004 Numanco
sale and a
release of product liability and litigation reserves related to
our Total
Electric Vehicle investment due to the resolution of all open litigation
as of March 31, 2005.
|
·
|
An
$8 million increase due to reductions in outstanding debt at AEP
Communications that occurred in October 2004.
|
·
|
A
$5 million increase at AEP Coal mostly related to Black Lung Trust
settlements.
|
·
|
A
$3 million increase at AEP Investments due to the investment write-down
of
PHPK Technologies, Inc. in 2004 of $1 million, favorable earnings
from Pac
Hydro of $1 million in 2005 and $1 million in reduced operations
and
maintenance at AEP EmTech.
|
·
|
A
$1 million increase at CSW International related to tax reserve
adjustments in June 2005.
|
·
|
A
$2 million increase related to several items at various subsidiaries,
none
of which is individually significant.
|
·
|
A
$17 million decrease at AEP Resources primarily related to a $2
million
favorable judgment on an Australian tax issue received in 2004,
a $4
million favorable entry in 2004 related to capitalized fuel during
construction of the Dow Plant, $5 million of increased losses related
to
the Dow plant in 2005 and an unfavorable tax adjustment of $4 million
booked in 2005.
|
·
|
A
$3 million decrease at our IPPs resulting from an unfavorable tax
adjustment in June 2005.
|
June
30, 2005
|
December
31, 2004
|
||||||||||||
Common
Shareholders’ Equity
|
$
|
8,382
|
41.1
|
%
|
$
|
8,515
|
40.6
|
%
|
|||||
Cumulative
Preferred Stock
|
61
|
0.3
|
61
|
0.3
|
|||||||||
Cumulative
Preferred Stock (Subject to Mandatory Redemption)
|
-
|
-
|
66
|
0.3
|
|||||||||
Long-term
Debt, including amounts due within one year
|
11,916
|
58.5
|
12,287
|
58.7
|
|||||||||
Short-term
Debt
|
14
|
0.1
|
23
|
0.1
|
|||||||||
Total
Capitalization
|
$
|
20,373
|
100.0
|
%
|
$
|
20,952
|
100.0
|
%
|
Amount
|
Maturity
|
||||||
(in
millions)
|
|||||||
Commercial
Paper Backup:
|
|||||||
Revolving Credit Facility |
$
|
1,000
|
May
2007
|
||||
Revolving Credit Facility |
1,500
|
March
2010
|
|||||
Letter
of Credit Facility
|
200
|
September
2006
|
|||||
Total
|
2,700
|
||||||
Cash
and Cash Equivalents
|
607
|
||||||
Total
Liquidity Sources
|
3,307
|
||||||
Less:
AEP Commercial Paper Outstanding
|
-
|
(a) | |||||
Letters of Credit Outstanding |
50
|
||||||
Net
Available Liquidity at June 30, 2005
|
$
|
3,257
|
(a)
|
Amount
does not include JMG commercial paper outstanding in the amount
of $14
million. This commercial paper is specifically associated with
the Gavin
scrubber and does not reduce AEP’s available liquidity. The JMG commercial
paper is supported by a separate letter of credit facility not
included
above.
|
Moody’s
|
S&P
|
Fitch
|
||||||||
Short-term
Debt
|
P-3
|
A-2
|
F-2
|
|||||||
Senior
Unsecured Debt
|
Baa3
|
BBB
|
BBB
|
Six
Months Ended June 30,
|
|||||||
2005
|
2004
|
||||||
(in
millions)
|
|||||||
Cash
and Cash Equivalents at Beginning of Period
|
$
|
320
|
$
|
778
|
|||
Cash
Flows From (Used For):
|
|||||||
Operating
Activities
|
894
|
1,275
|
|||||
Investing
Activities
|
484
|
(565
|
)
|
||||
Financing
Activities
|
(1,091
|
)
|
(825
|
)
|
|||
Net
Increase (Decrease) in Cash and Cash Equivalents
|
287
|
(115
|
)
|
||||
Cash
and Cash Equivalents at End of Period
|
$
|
607
|
$
|
663
|
|||
Other
Temporary Cash Investments
|
$
|
275
|
$
|
403
|
Six
Months Ended June 30,
|
|||||||
2005
|
2004
|
||||||
(in
millions)
|
|||||||
Net
Income
|
$
|
576
|
$
|
382
|
|||
Plus:
(Income) Loss From Discontinued Operations
|
(4
|
)
|
58
|
||||
Income
from Continuing Operations
|
572
|
440
|
|||||
Noncash
Items Included in Earnings
|
594
|
797
|
|||||
Changes
in Assets and Liabilities
|
(272
|
)
|
38
|
||||
Net
Cash Flows From Operating Activities
|
$
|
894
|
$
|
1,275
|
Six
Months Ended June 30,
|
|||||||
2005
|
2004
|
||||||
(in
millions)
|
|||||||
Construction
Expenditures
|
$
|
(1,018
|
)
|
$
|
(690
|
)
|
|
Change
in Other Temporary Cash Investments, Net
|
(103
|
)
|
(1
|
)
|
|||
Purchases
of Auction Rate Securities
|
(1,338
|
)
|
(201
|
)
|
|||
Proceeds
from the Sale of Auction Rate Securities
|
1,441
|
203
|
|||||
Proceeds
from Sale of Assets
|
1,500
|
131
|
|||||
Other
|
2
|
(7
|
)
|
||||
Net
Cash Flows From (Used For) Investing Activities
|
$
|
484
|
$
|
(565
|
)
|
Six
Months Ended June 30,
|
|||||||
2005
|
2004
|
||||||
(in
millions)
|
|||||||
Issuance
of Common Stock
|
$
|
28
|
$
|
11
|
|||
Repurchase
of Common Stock
|
(427
|
)
|
-
|
||||
Issuance/Retirement
of Debt, net
|
(353
|
)
|
(555
|
)
|
|||
Retirement
of Preferred Stock
|
(66
|
)
|
(4
|
)
|
|||
Dividends
Paid on Common Stock
|
(273
|
)
|
(277
|
)
|
|||
Net
Cash Flows Used For Financing Activities
|
$
|
(1,091
|
)
|
$
|
(825
|
)
|
·
|
Legislative
and regulatory proposals to adopt stringent controls on SO2,
NOx
and mercury emissions from coal-fired power plants,
|
·
|
Clean
Water Act rules to reduce the impacts of water intake structures
on
aquatic species at certain of our power plants, and
|
·
|
Possible
future requirements to reduce carbon dioxide emissions to address
concerns
about global climate change.
|
·
|
The
Federal EPA proposed a Clean Air Interstate Rule (CAIR) to reduce
SO2
and NOx
emissions across the Eastern United States (29 states and the District
of
Columbia) and make progress toward attainment of the new fine particulate
matter and ground-level ozone national ambient air quality standards.
These reductions could also satisfy these states’ obligations to make
reasonable progress towards the national visibility goal under
the
regional haze program.
|
·
|
The
Federal EPA proposed to regulate mercury emissions from coal-fired
electric generating units.
|
Utility
Operations
|
Investments-Gas
Operations
|
Investments-UK
Operations
|
Total
|
||||||||||
Total
MTM Risk Management Contract
Net Assets
(Liabilities) at December
31, 2004
|
$
|
277
|
$
|
-
|
$
|
(12
|
)
|
$
|
265
|
||||
(Gain)
Loss from Contracts Realized/Settled
During the Period (a)
|
(52
|
)
|
(4
|
)
|
12
|
(44
|
)
|
||||||
Fair
Value of New Contracts When Entered
During the Period (b)
|
2
|
-
|
-
|
2
|
|||||||||
Net
Option Premiums Paid/(Received) (c)
|
(1
|
)
|
-
|
-
|
(1
|
)
|
|||||||
Change
in Fair Value Due to Valuation Methodology
Changes
|
-
|
-
|
-
|
-
|
|||||||||
Changes
in Fair Value of Risk Management
Contracts (d)
|
30
|
(3
|
)
|
-
|
27
|
||||||||
Changes
in Fair Value of Risk Management
Contracts Allocated to
Regulated
Jurisdictions (e)
|
(13
|
)
|
-
|
-
|
(13
|
)
|
|||||||
Total
MTM Risk Management Contract Net
Assets
(Liabilities) at June
30, 2005
|
$
|
243
|
$
|
(7
|
)
|
$
|
-
|
236
|
|||||
Net
Cash Flow and Fair Value Hedge Contracts (f)
|
(37
|
)
|
|||||||||||
Ending
Net Risk Management Assets at June
30, 2005
|
$
|
199
|
(a)
|
“(Gain)
Loss from Contracts Realized/Settled During the Period” includes realized
gains from risk management contracts and related derivatives that
settled
during 2005 where we entered into the contract prior to
2005.
|
(b)
|
“Fair
Value of New Contracts When Entered During the Period” represents the fair
value at inception of long-term contracts entered into with customers
during 2005. Most of the fair value comes from longer term fixed
price
contracts with customers that seek to limit their risk against
fluctuating
energy prices. Inception value is only recorded if observable market
data
can be obtained for valuation inputs for the entire contract term.
The
contract prices are valued against market curves associated with
the
delivery location and delivery term.
|
(c)
|
“Net
Option Premiums Paid/(Received)” reflects the net option premiums
paid/(received) as they relate to unexercised and unexpired option
contracts entered in 2005.
|
(d)
|
“Changes
in Fair Value of Risk Management Contracts” represents the fair value
change in the risk management portfolio due to market fluctuations
during
the current period. Market fluctuations are attributable to various
factors such as supply/demand, weather, storage, etc.
|
(e)
|
“Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions” relates to the net gains (losses) of those contracts that
are not reflected in the Condensed Consolidated Statements of Income.
These net gains (losses) are recorded as regulatory assets/liabilities
for
those subsidiaries that operate in regulated
jurisdictions.
|
(f)
|
“Net
Cash Flow and Fair Value Hedge Contracts” (pretax) are discussed in detail
within the following pages.
|
Utility
Operations
|
Investments-Gas
Operations
|
Total
|
||||||||
Current
Assets
|
$
|
376
|
$
|
222
|
$
|
598
|
||||
Noncurrent
Assets
|
529
|
164
|
693
|
|||||||
Total
Assets
|
905
|
386
|
1,291
|
|||||||
Current
Liabilities
|
(325
|
)
|
(217
|
)
|
(542
|
)
|
||||
Noncurrent
Liabilities
|
(337
|
)
|
(176
|
)
|
(513
|
)
|
||||
Total
Liabilities
|
(662
|
)
|
(393
|
)
|
(1,055
|
)
|
||||
Total
Net Assets (Liabilities),
excluding
Hedges
|
$
|
243
|
$
|
(7
|
)
|
$
|
236
|
MTM
Risk Management Contracts (a)
|
PLUS:
Hedges
|
Total
(b)
|
||||||||
Current
Assets
|
$
|
598
|
$
|
1
|
$
|
599
|
||||
Noncurrent
Assets
|
693
|
1
|
694
|
|||||||
Total
MTM Derivative Contract Assets
|
1,291
|
2
|
1,293
|
|||||||
Current
Liabilities
|
(542
|
)
|
(36
|
)
|
(578
|
)
|
||||
Noncurrent
Liabilities
|
(513
|
)
|
(3
|
)
|
(516
|
)
|
||||
Total
MTM Derivative Contract Liabilities
|
(1,055
|
)
|
(39
|
)
|
(1,094
|
)
|
||||
Total
MTM Derivative Contract Net Assets
|
$
|
236
|
$
|
(37
|
)
|
$
|
199
|
(a)
|
Does
not include Cash Flow and Fair Value Hedges.
|
(b)
|
Represents
amount of total MTM derivative contracts recorded within Risk Management
Assets, Long-term Risk Management Assets, Risk Management Liabilities
and
Long-term Risk Management Liabilities on our Condensed Consolidated
Balance Sheets.
|
·
|
The
source of fair value used in determining the carrying amount of
our total
MTM asset or liability (external sources or modeled
internally).
|
·
|
The
maturity, by year, of our net assets/liabilities, giving an indication
of
when these MTM amounts will settle and generate
cash.
|
Remainder
2005
|
2006
|
2007
|
2008
|
2009
|
After
2009 (c)
|
Total
(d)
|
||||||||||||||||
Utility
Operations:
|
||||||||||||||||||||||
Prices
Actively Quoted - Exchange Traded
Contracts
|
$
|
(32
|
)
|
$
|
6
|
$
|
23
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
(3
|
)
|
||||||
Prices
Provided by Other External Sources
- OTC Broker Quotes (a)
|
99
|
107
|
52
|
39
|
-
|
-
|
297
|
|||||||||||||||
Prices
Based on Models and Other Valuation
Methods (b)
|
(40
|
)
|
(60
|
)
|
(18
|
)
|
7
|
33
|
27
|
(51
|
)
|
|||||||||||
Total
|
$
|
27
|
$
|
53
|
$
|
57
|
$
|
46
|
$
|
33
|
$
|
27
|
$
|
243
|
||||||||
Investments
- Gas Operations:
|
||||||||||||||||||||||
Prices
Actively Quoted - Exchange Traded
Contracts
|
$
|
(5
|
)
|
$
|
(7
|
)
|
$
|
5
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
(7
|
)
|
|||||
Prices
Provided by Other External Sources
- OTC Broker Quotes (a)
|
20
|
(3
|
)
|
(3
|
)
|
-
|
-
|
-
|
14
|
|||||||||||||
Prices
Based on Models and Other Valuation
Methods (b)
|
(3
|
)
|
(3
|
)
|
-
|
(2
|
)
|
(4
|
)
|
(2
|
)
|
(14
|
)
|
|||||||||
Total
|
$
|
12
|
$
|
(13
|
)
|
$
|
2
|
$
|
(2
|
)
|
$
|
(4
|
)
|
$
|
(2
|
)
|
$
|
(7
|
)
|
|||
Total:
|
||||||||||||||||||||||
Prices
Actively Quoted - Exchange Traded
Contracts
|
$
|
(37
|
)
|
$
|
(1
|
)
|
$
|
28
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
(10
|
)
|
|||||
Prices
Provided by Other External Sources
- OTC Broker Quotes (a)
|
119
|
104
|
49
|
39
|
-
|
-
|
311
|
|||||||||||||||
Prices
Based on Models and Other Valuation
Methods (b)
|
(43
|
)
|
(63
|
)
|
(18
|
)
|
5
|
29
|
25
|
(65
|
)
|
|||||||||||
Total
|
$
|
39
|
$
|
40
|
$
|
59
|
$
|
44
|
$
|
29
|
$
|
25
|
$
|
236
|
(a)
|
Prices
Provided by Other External Sources- OTC Broker Quotes reflects
information
obtained from over-the-counter brokers (OTC), industry services,
or
multiple-party on-line platforms.
|
(b)
|
Prices
Based on Models and Other Valuation Methods is in the absence of
pricing
information from external sources, modeled information is derived
using
valuation models developed by the reporting entity, reflecting
when
appropriate, option pricing theory, discounted cash flow concepts,
valuation adjustments, etc. and may require projection of prices
for
underlying commodities beyond the period that prices are available
from
third-party sources. In addition, where external pricing information
or
market liquidity is limited, such valuations are classified as
modeled.
|
(c)
|
There
is mark-to-market value in excess of 10 percent of our total
mark-to-market value in individual periods beyond 2009. $24 million
of
this mark-to-market value is in 2010.
|
(d)
|
Amounts
exclude Cash Flow and Fair Value
Hedges.
|
Commodity
|
Transaction
Class
|
Market/Region
|
Tenor
|
|||
(in
months)
|
||||||
Natural
Gas
|
Futures
|
NYMEX/Henry
Hub
|
60
|
|||
Physical
Forwards
|
Gulf
Coast, Texas
|
36
|
||||
Swaps
|
Gas
East - Northeast, Mid-continent,
|
|||||
Gulf
Coast, Texas
|
36
|
|||||
Swaps
|
Gas
West - Rocky Mountains, West Coast
|
42
|
||||
Exchange
Option Volatility
|
NYMEX/Henry
Hub
|
12
|
||||
Power
|
Futures
|
Power
East - PJM
|
36
|
|||
Physical
Forwards
|
Power
East - MISO Cin Hub
|
42
|
||||
Physical
Forwards
|
Power
East - PJM West
|
42
|
||||
Physical
Forwards
|
Power
East - AEP Dayton (PJM)
|
18
|
||||
Physical
Forwards
|
Power
East - NEPOOL
|
42
|
||||
Physical
Forwards
|
Power
East - NYPP
|
42
|
||||
Physical
Forwards
|
Power
East - ERCOT
|
42
|
||||
Physical
Forwards
|
Power
East - Com Ed
|
18
|
||||
Physical
Forwards
|
Power
East - Entergy
|
6
|
||||
Physical
Forwards
|
Power
West - Palo Verde, Mead
|
54
|
||||
Physical
Forwards
|
Power
West - North Path 15, South Path 15
|
54
|
||||
Physical
Forwards
|
Power
West - Mid Columbia
|
54
|
||||
Peak
Power Volatility (Options)
|
Cinergy,
PJM
|
12
|
||||
Crude
Oil
|
Swaps
|
West
Texas Intermediate
|
36
|
|||
Emissions
|
Credits
|
SO2, NOx
|
42
|
|||
Coal
|
Physical
Forwards
|
PRB,
NYMEX, CSX
|
30
|
Accumulated
Other Comprehensive Income
(Loss)
After Tax (a)
|
After
Tax
Portion
Expected to be Reclassified to Earnings During the Next 12 Months
(b)
|
||||||
Power
and Gas
|
$
|
(19
|
)
|
$
|
(18
|
)
|
|
Interest
Rate
|
(32
|
)
|
(5
|
)
|
|||
Total
|
$
|
(51
|
)
|
$
|
(23
|
)
|
Power
and Gas
|
Interest
Rate
|
Total
|
||||||||
Beginning
Balance, December 31, 2004
|
$
|
23
|
$
|
(23
|
)
|
$
|
-
|
|||
Changes
in Fair Value (c)
|
(15
|
)
|
(12
|
)
|
(27
|
)
|
||||
Reclassifications
from AOCI to Net Income (d)
|
(27
|
)
|
3
|
(24
|
)
|
|||||
Ending
Balance, June 30, 2005
|
$
|
(19
|
)
|
$
|
(32
|
)
|
$
|
(51
|
)
|
(a)
|
“Accumulated
Other Comprehensive Income (Loss) After Tax” - Gains/losses are net of
related income taxes that have not yet been included in the determination
of net income; reported as a separate component of shareholders’ equity on
the balance sheet.
|
(b)
|
“After
Tax Portion Expected to be Reclassified to Earnings During the
Next 12
Months” - Amount of gains or losses (realized or unrealized) from
derivatives used as hedging instruments that have been deferred
and are
expected to be reclassified into net income during the next 12
months at
the time the hedged transaction affects net income.
|
(c)
|
“Changes
in Fair Value” - Changes in the fair value of derivatives designated as
cash flow hedges during the reporting period that are not yet settled
at
June 30, 2005. Amounts are reported net of related income
taxes.
|
(d)
|
“Reclassifications
from AOCI to Net Income” - Gains or losses from derivatives used as
hedging instruments in cash flow hedges that were reclassified
into Net
Income during the reporting period. Amounts are reported net of
related
income taxes.
|
Counterparty
Credit Quality
|
Exposure
Before Credit Collateral
|
Credit
Collateral
|
Net
Exposure
|
Number
of Counterparties >10%
|
Net
Exposure of Counterparties >10%
|
|||||||||||
Investment
Grade
|
$
|
767
|
$
|
140
|
$
|
627
|
2
|
$
|
178
|
|||||||
Split
Rating
|
13
|
3
|
10
|
1
|
9
|
|||||||||||
Noninvestment
Grade
|
193
|
116
|
77
|
3
|
66
|
|||||||||||
No
External Ratings:
|
||||||||||||||||
Internal
Investment Grade
|
50
|
-
|
50
|
1
|
34
|
|||||||||||
Internal
Noninvestment Grade
|
25
|
6
|
19
|
2
|
17
|
|||||||||||
Total
|
$
|
1,048
|
$
|
265
|
$
|
783
|
9
|
$
|
304
|
Remainder
2005
|
2006
|
2007
|
||||||||
Estimated
Plant Output Hedged
|
91
|
%
|
85
|
%
|
85
|
%
|
Six
Months Ended
June
30, 2005
|
Twelve
Months Ended
December
31, 2004
|
||||||||||||||||
(in
millions)
|
(in
millions)
|
||||||||||||||||
End
|
High
|
Average
|
Low
|
End
|
High
|
Average
|
Low
|
||||||||||
$4
|
$5
|
$2
|
$1
|
$3
|
$19
|
$5
|
$1
|
June
30, 2005
|
Average
for
Year-to-Date
2005
|
High
for
Year-to-Date
2005
|
Low
for Year-to-Date 2005
|
||||||||||
95%
Confidence Level, Ten-Day Holding
Period
|
$
|
15
|
$
|
9
|
$
|
17
|
$
|
5
|
|||||
99%
Confidence Level, One-Day Holding
Period
|
$
|
6
|
$
|
4
|
$
|
7
|
$
|
2
|
Three
Months Ended
|
Six
Months Ended
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
REVENUES
|
|||||||||||||
Utility
Operations
|
$
|
2,649
|
$
|
2,508
|
$
|
5,186
|
$
|
5,089
|
|||||
Gas
Operations
|
19
|
779
|
376
|
1,431
|
|||||||||
Other
|
105
|
124
|
194
|
255
|
|||||||||
TOTAL
|
2,773
|
3,411
|
5,756
|
6,775
|
|||||||||
EXPENSES
|
|||||||||||||
Fuel
for Electric Generation
|
772
|
734
|
1,543
|
1,428
|
|||||||||
Purchased
Electricity for Resale
|
183
|
87
|
313
|
170
|
|||||||||
Purchased
Gas for Resale
|
1
|
701
|
250
|
1,286
|
|||||||||
Maintenance
and Other Operation
|
873
|
978
|
1,663
|
1,842
|
|||||||||
Depreciation
and Amortization
|
325
|
320
|
652
|
639
|
|||||||||
Taxes
Other Than Income Taxes
|
173
|
181
|
361
|
374
|
|||||||||
TOTAL
|
2,327
|
3,001
|
4,782
|
5,739
|
|||||||||
OPERATING
INCOME
|
446
|
410
|
974
|
1,036
|
|||||||||
Other
Income
|
106
|
59
|
345
|
121
|
|||||||||
Other
Expense
|
(40
|
)
|
(38
|
)
|
(106
|
)
|
(74
|
)
|
|||||
Investment
Value Losses
|
-
|
(2
|
)
|
-
|
(2
|
)
|
|||||||
INTEREST
AND OTHER CHARGES
|
|||||||||||||
Interest
Expense
|
188
|
199
|
361
|
398
|
|||||||||
Preferred
Stock Dividend Requirements of Subsidiaries
|
3
|
1
|
5
|
3
|
|||||||||
TOTAL
|
191
|
200
|
366
|
401
|
|||||||||
INCOME
BEFORE INCOME TAXES
|
321
|
229
|
847
|
680
|
|||||||||
Income
Taxes
|
103
|
78
|
275
|
240
|
|||||||||
INCOME
BEFORE DISCONTINUED OPERATIONS
|
218
|
151
|
572
|
440
|
|||||||||
DISCONTINUED
OPERATIONS, Net of Tax
|
3
|
(51
|
)
|
4
|
(58
|
)
|
|||||||
NET
INCOME
|
$
|
221
|
$
|
100
|
$
|
576
|
$
|
382
|
|||||
WEIGHTED
AVERAGE NUMBER OF SHARES OUTSTANDING
|
384
|
396
|
389
|
396
|
|||||||||
EARNINGS
PER SHARE
|
|||||||||||||
Income
Before Discontinued Operations
|
$
|
0.57
|
$
|
0.38
|
$
|
1.47
|
$
|
1.11
|
|||||
Discontinued
Operations
|
0.01
|
(0.13
|
)
|
0.01
|
(0.15
|
)
|
|||||||
TOTAL
EARNINGS PER SHARE (BASIC AND DILUTIVE)
|
$
|
0.58
|
$
|
0.25
|
$
|
1.48
|
$
|
0.96
|
|||||
CASH
DIVIDENDS PAID PER SHARE
|
$
|
0.35
|
$
|
0.35
|
$
|
0.70
|
$
|
0.70
|
2005
|
2004
|
||||||
CURRENT
ASSETS
|
|||||||
Cash
and Cash Equivalents
|
$
|
607
|
$
|
320
|
|||
Other
Temporary Cash Investments
|
275
|
275
|
|||||
Accounts
Receivable:
|
|||||||
Customers
|
717
|
930
|
|||||
Accrued
Unbilled Revenues
|
354
|
592
|
|||||
Miscellaneous
|
33
|
79
|
|||||
Allowance
for Uncollectible Accounts
|
(46
|
)
|
(77
|
)
|
|||
Total
Accounts Receivable
|
1,058
|
1,524
|
|||||
Fuel,
Materials and Supplies
|
729
|
852
|
|||||
Risk
Management Assets
|
599
|
737
|
|||||
Margin
Deposits
|
112
|
113
|
|||||
Other
|
150
|
200
|
|||||
TOTAL
|
3,530
|
4,021
|
|||||
PROPERTY,
PLANT AND EQUIPMENT
|
|||||||
Electric:
|
|||||||
Production
|
16,346
|
15,969
|
|||||
Transmission
|
6,369
|
6,293
|
|||||
Distribution
|
10,471
|
10,280
|
|||||
Other
(including gas, coal mining and nuclear fuel)
|
3,093
|
3,585
|
|||||
Construction
Work in Progress
|
1,296
|
1,159
|
|||||
Total
|
37,575
|
37,286
|
|||||
Accumulated
Depreciation and Amortization
|
14,682
|
14,485
|
|||||
TOTAL
- NET
|
22,893
|
22,801
|
|||||
OTHER
NONCURRENT ASSETS
|
|||||||
Regulatory
Assets
|
3,707
|
3,601
|
|||||
Securitized
Transition Assets
|
622
|
642
|
|||||
Spent
Nuclear Fuel and Decommissioning Trusts
|
1,095
|
1,053
|
|||||
Investments
in Power and Distribution Projects
|
138
|
154
|
|||||
Goodwill
|
76
|
76
|
|||||
Long-term
Risk Management Assets
|
694
|
470
|
|||||
Prepaid
Pension Obligations
|
384
|
386
|
|||||
Other
|
754
|
831
|
|||||
TOTAL
|
7,470
|
7,213
|
|||||
Assets
Held for Sale
|
46
|
628
|
|||||
TOTAL
ASSETS
|
$
|
33,939
|
$
|
34,663
|
2005
|
2004
|
||||||||||||
CURRENT
LIABILITIES
|
(in
millions)
|
||||||||||||
Accounts
Payable
|
$
|
925
|
$
|
1,051
|
|||||||||
Short-term
Debt
|
14
|
23
|
|||||||||||
Long-term
Debt Due Within One Year (a)
|
1,064
|
1,279
|
|||||||||||
Cumulative
Preferred Stocks of Subsidiaries Subject to Mandatory Redemption
|
-
|
66
|
|||||||||||
Risk
Management Liabilities
|
578
|
608
|
|||||||||||
Accrued
Taxes
|
788
|
611
|
|||||||||||
Accrued
Interest
|
180
|
180
|
|||||||||||
Customer
Deposits
|
380
|
414
|
|||||||||||
Other
|
602
|
775
|
|||||||||||
TOTAL
|
4,531
|
5,007
|
|||||||||||
NONCURRENT
LIABILITIES
|
|||||||||||||
Long-term
Debt (a)
|
10,852
|
11,008
|
|||||||||||
Long-term
Risk Management Liabilities
|
516
|
329
|
|||||||||||
Deferred
Income Taxes
|
4,663
|
4,819
|
|||||||||||
Regulatory
Liabilities and Deferred Investment Tax Credits
|
2,618
|
2,540
|
|||||||||||
Asset
Retirement Obligations
|
860
|
827
|
|||||||||||
Employee
Benefits and Pension Obligations
|
546
|
730
|
|||||||||||
Deferred
Gain on Sale and Leaseback - Rockport Plant Unit 2
|
162
|
166
|
|||||||||||
Deferred
Credits and Other
|
747
|
411
|
|||||||||||
TOTAL
|
20,964
|
20,830
|
|||||||||||
Liabilities
Held for Sale
|
1
|
250
|
|||||||||||
TOTAL
LIABILITIES
|
25,496
|
26,087
|
|||||||||||
Cumulative
Preferred Stock Not Subject to Mandatory
Redemption
|
61
|
61
|
|||||||||||
Commitments
and Contingencies (Note 5)
|
|||||||||||||
COMMON
SHAREHOLDERS’ EQUITY
|
|||||||||||||
Common
Stock Par Value $6.50:
|
|||||||||||||
2005
|
2004
|
||||||||||||
Shares
Authorized
|
600,000,000
|
600,000,000
|
|||||||||||
Shares
Issued
|
405,896,571
|
404,858,145
|
|||||||||||
(21,499,992
and 8,999,992 shares were held in treasury at June 30, 2005
and December 31, 2004, respectively)
|
2,638
|
2,632
|
|||||||||||
Paid-in
Capital
|
3,813
|
4,203
|
|||||||||||
Retained
Earnings
|
2,327
|
2,024
|
|||||||||||
Accumulated
Other Comprehensive Income (Loss)
|
(396
|
)
|
(344
|
)
|
|||||||||
TOTAL
|
8,382
|
8,515
|
|||||||||||
TOTAL
LIABILITIES AND SHAREHOLDERS’ EQUITY
|
$
|
33,939
|
$
|
34,663
|
2005
|
2004
|
|||||||||
OPERATING
ACTIVITIES
|
||||||||||
Net
Income
|
$
|
576
|
$
|
382
|
||||||
Plus:
(Income) Loss from Discontinued Operations
|
(4
|
)
|
58
|
|||||||
Income
from Continuing Operations
|
572
|
440
|
||||||||
Adjustments
for Noncash Items:
|
||||||||||
Depreciation
and Amortization
|
652
|
639
|
||||||||
Accretion
of Asset Retirement Obligations
|
35
|
31
|
||||||||
Deferred
Income Taxes
|
(75
|
)
|
92
|
|||||||
Deferred
Investment Tax Credits
|
(15
|
)
|
(13
|
)
|
||||||
Asset
Impairments, Investment Value Losses and Other Related
Charges
|
-
|
2
|
||||||||
Carrying
Costs
|
(56
|
)
|
-
|
|||||||
Amortization
of Deferred Property Taxes
|
10
|
(4
|
)
|
|||||||
Mark-to-Market
of Risk Management Contracts
|
43
|
50
|
||||||||
Pension
Contributions
|
(204
|
)
|
(8
|
)
|
||||||
Over/Under
Fuel Recovery
|
(45
|
)
|
70
|
|||||||
Gain
on Sales of Assets
|
(115
|
)
|
(3
|
)
|
||||||
Change
in Other Noncurrent Assets
|
(80
|
)
|
10
|
|||||||
Change
in Other Noncurrent Liabilities
|
(121
|
)
|
(34
|
)
|
||||||
Changes
in Certain Components of Working Capital:
|
||||||||||
Accounts
Receivable, Net
|
155
|
157
|
||||||||
Fuel,
Materials and Supplies
|
(29
|
)
|
(144
|
)
|
||||||
Accounts
Payable
|
84
|
(158
|
)
|
|||||||
Taxes
Accrued
|
172
|
140
|
||||||||
Customer
Deposits
|
(34
|
)
|
83
|
|||||||
Interest
Accrued
|
(5
|
)
|
(8
|
)
|
||||||
Other
Current Assets
|
63
|
7
|
||||||||
Other
Current Liabilities
|
(113
|
)
|
(74
|
)
|
||||||
Net
Cash Flows From Operating Activities
|
894
|
1,275
|
||||||||
INVESTING
ACTIVITIES
|
||||||||||
Construction
Expenditures
|
(1,018
|
)
|
(690
|
)
|
||||||
Change
in Other Temporary Cash Investments, Net
|
(103
|
)
|
(1
|
)
|
||||||
Purchases
of Auction Rate Securities
|
(1,338
|
)
|
(201
|
)
|
||||||
Proceeds
from the Sale of Auction Rate Securities
|
1,441
|
203
|
||||||||
Proceeds
from Sale of Assets
|
1,500
|
131
|
||||||||
Other
|
2
|
(7
|
)
|
|||||||
Net
Cash Flows From (Used For) Investing Activities
|
484
|
(565
|
)
|
|||||||
FINANCING
ACTIVITIES
|
||||||||||
Issuance
of Common Stock
|
28
|
11
|
||||||||
Repurchase
of Common Stock
|
(427
|
)
|
-
|
|||||||
Issuance
of Long-term Debt
|
1,660
|
243
|
||||||||
Change
in Short-term Debt, Net
|
27
|
188
|
||||||||
Retirement
of Long-term Debt
|
(2,040
|
)
|
(986
|
)
|
||||||
Retirement
of Preferred Stock
|
(66
|
)
|
(4
|
)
|
||||||
Dividends
Paid on Common Stock
|
(273
|
)
|
(277
|
)
|
||||||
Net
Cash Flows Used For Financing Activities
|
(1,091
|
)
|
(825
|
)
|
||||||
Net
Increase (Decrease) in Cash and Cash Equivalents
|
287
|
(115
|
)
|
|||||||
Cash
and Cash Equivalents at Beginning of Period
|
320
|
778
|
||||||||
Cash
and Cash Equivalents at End of Period
|
$
|
607
|
$
|
663
|
||||||
Net
Increase in Cash and Cash Equivalents from Discontinued
Operations
|
$
|
-
|
$
|
2
|
||||||
Cash
and Cash Equivalents from Discontinued Operations - Beginning of
Period
|
-
|
13
|
||||||||
Cash
and Cash Equivalents from Discontinued Operations - End of
Period
|
$
|
-
|
$
|
15
|
||||||
See
Condensed Notes to Consolidated Financial
Statements.
|
Common
Stock
|
Accumulated
Other Comprehensive Income (Loss)
|
|||||||||||||||||||
Shares
|
Amount
|
Paid-in
Capital
|
Retained
Earnings
|
Total
|
||||||||||||||||
DECEMBER
31, 2003
|
404
|
$
|
2,626
|
$
|
4,184
|
$
|
1,490
|
$
|
(426
|
)
|
$
|
7,874
|
||||||||
Issuance
of Common Stock
|
1
|
4
|
7
|
11
|
||||||||||||||||
Common
Stock Dividends
|
(277
|
)
|
(277
|
)
|
||||||||||||||||
Other
|
2
|
2
|
||||||||||||||||||
TOTAL
|
7,610
|
|||||||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||||||
Other
Comprehensive Income (Loss), Net of Tax:
|
||||||||||||||||||||
Foreign
Currency Translation Adjustments,
Net
of Tax of $0
|
(1
|
)
|
(1
|
)
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $41
|
75
|
75
|
||||||||||||||||||
Minimum
Pension Liability, Net of Tax of $10
|
17
|
17
|
||||||||||||||||||
NET
INCOME
|
382
|
382
|
||||||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
473
|
|||||||||||||||||||
JUNE
30, 2004
|
405
|
$
|
2,630
|
$
|
4,193
|
$
|
1,595
|
$
|
(335
|
)
|
$
|
8,083
|
||||||||
DECEMBER
31, 2004
|
405
|
$
|
2,632
|
$
|
4,203
|
$
|
2,024
|
$
|
(344
|
)
|
$
|
8,515
|
||||||||
Issuance
of Common Stock
|
1
|
6
|
22
|
28
|
||||||||||||||||
Common
Stock Dividends
|
(273
|
)
|
(273
|
)
|
||||||||||||||||
Repurchase
of Common Stock
|
(427
|
)
|
(427
|
)
|
||||||||||||||||
Other
|
15
|
15
|
||||||||||||||||||
TOTAL
|
7,858
|
|||||||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||||||
Other
Comprehensive Income (Loss), Net of Tax:
|
||||||||||||||||||||
Foreign
Currency Translation Adjustments,
Net
of Tax of
$0
|
(1
|
)
|
(1
|
)
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $28
|
(51
|
)
|
(51
|
)
|
||||||||||||||||
NET
INCOME
|
576
|
576
|
||||||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
524
|
|||||||||||||||||||
JUNE
30, 2005
|
406
|
$
|
2,638
|
$
|
3,813
|
$
|
2,327
|
$
|
(396
|
)
|
$
|
8,382
|
2005
|
2004
|
||||||
First
Mortgage Bonds
|
$
|
242
|
$
|
417
|
|||
Defeased
TCC First Mortgage Bonds (a)
|
84
|
84
|
|||||
Installment
Purchase Contracts
|
2,055
|
1,773
|
|||||
Notes
Payable
|
928
|
939
|
|||||
Senior
Unsecured Notes
|
7,292
|
7,717
|
|||||
Securitization
Bonds
|
669
|
698
|
|||||
Notes
Payable to Trust
|
113
|
113
|
|||||
Equity
Unit Senior Notes (b)
|
345
|
345
|
|||||
Long-term
DOE Obligation (c)
|
232
|
229
|
|||||
Other
Long-term Debt
|
3
|
14
|
|||||
Equity
Unit Contract Adjustment Payments
|
4
|
9
|
|||||
Unamortized
Discount, Net
|
(51
|
)
|
(51
|
)
|
|||
TOTAL
LONG-TERM DEBT OUTSTANDING
|
11,916
|
12,287
|
|||||
Less
Portion Due Within One Year
|
1,064
|
1,279
|
|||||
TOTAL
LONG-TERM PORTION
|
$
|
10,852
|
$
|
11,008
|
(a)
|
On
May 7, 2004, we deposited cash and treasury securities of $125
million
with a trustee to defease all of TCC’s outstanding First Mortgage Bonds.
Trust fund assets related to this obligation of $70 and $72 million
are
included in Other Temporary Cash Investments at June 30, 2005 and
December
31, 2004, respectively, and $22 million are included in Other Noncurrent
Assets in the Condensed Consolidated Balance Sheets at both June
30, 2005
and December 31, 2004. Trust fund assets are restricted for exclusive
use
in funding the interest and principal due on the First Mortgage
Bonds.
|
(b)
|
In
June 2005, we remarketed $345 million of 5.75% Equity Unit Senior
Notes
originally issued in June 2002 with new notes bearing a 4.709%
interest
rate. See “Remarketing of Senior Notes” section of Note
11.
|
(c)
|
Pursuant
to the Nuclear Waste Policy Act of 1982, I&M (a nuclear licensee) has
an obligation with the United States Department of Energy for spent
nuclear fuel disposal. The obligation includes a one-time fee for
nuclear
fuel consumed prior to April 7, 1983. I&M is the only AEP subsidiary
that generated electric power with nuclear fuel prior to that date.
Trust
fund assets of $264 million and $262 million related to this obligation
are included in Spent Nuclear Fuel and Decommissioning Trusts in
the
Condensed Consolidated Balance Sheets at June 30, 2005 and December
31,
2004, respectively.
|
1.
|
Significant
Accounting Matters
|
2.
|
New
Accounting Pronouncements
|
3.
|
Rate
Matters
|
4.
|
Customer
Choice and Industry Restructuring
|
5.
|
Commitments
and Contingencies
|
6.
|
Guarantees
|
7.
|
Acquisitions,
Dispositions, Discontinued Operations and Assets Held for Sale
|
8.
|
Benefit
Plans
|
9.
|
Business
Segments
|
10.
|
Income
Taxes
|
11.
|
Financing
Activities
|
12.
|
Company-wide
Staffing and Budget Review
|
Three
Months Ended June 30,
|
Six
Months Ended June 30,
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
(in
millions)
|
(in
millions)
|
||||||||||||
Other
Income:
|
|||||||||||||
Interest
and Dividend Income
|
$
|
14
|
$
|
5
|
$
|
25
|
$
|
11
|
|||||
Equity
Earnings
|
2
|
3
|
7
|
10
|
|||||||||
Nonutility
Revenue
|
29
|
29
|
92
|
58
|
|||||||||
Gain
on Sale of Texas REPs
|
-
|
-
|
112
|
-
|
|||||||||
Carrying
Charges
|
36
|
(1
|
)
|
56
|
1
|
||||||||
Other
|
25
|
23
|
53
|
41
|
|||||||||
Total
Other Income
|
$
|
106
|
$
|
59
|
$
|
345
|
$
|
121
|
|||||
Other
Expense:
|
|||||||||||||
Nonutility
Expense
|
$
|
21
|
$
|
23
|
$
|
78
|
$
|
51
|
|||||
Other
|
19
|
15
|
28
|
23
|
|||||||||
Total
Other Expense
|
$
|
40
|
$
|
38
|
$
|
106
|
$
|
74
|
June
30,
|
December
31,
|
||||||
2005
|
2004
|
||||||
Components
|
(in
millions)
|
||||||
Foreign
Currency Translation Adjustments, net of tax
|
$
|
5
|
$
|
6
|
|||
Securities
Available for Sale, net of tax
|
(1
|
)
|
(1
|
)
|
|||
Cash
Flow Hedges, net of tax
|
(51
|
)
|
-
|
||||
Minimum
Pension Liability, net of tax
|
(349
|
)
|
(349
|
)
|
|||
Total
|
$
|
(396
|
)
|
$
|
(344
|
)
|
Nuclear
Decommissioning
|
Ash
Ponds
|
Wind
Mills
and
Mining Operations
|
Total
|
||||||||||
(in
millions)
|
|||||||||||||
ARO
at January 1, 2005, Including STP
|
$
|
960
|
$
|
84
|
$
|
32
|
$
|
1,076
|
|||||
Accretion
Expense
|
31
|
3
|
1
|
35
|
|||||||||
Liabilities
Incurred
|
-
|
-
|
8
|
8
|
|||||||||
ARO
at June 30, 2005, Including STP
|
991
|
87
|
41
|
1,119
|
|||||||||
Less
ARO Liability for STP (a)
|
(256
|
)
|
-
|
-
|
(256
|
)
|
|||||||
ARO
at June 30, 2005
|
$
|
735
|
$
|
87
|
$
|
41
|
$
|
863
|
(b)
|
(a)
|
The
ARO for TCC’s share of STP was included in Liabilities Held for Sale at
December 31, 2004 and was subsequently transferred to the buyer
with the
sale in the second quarter of 2005 (see “Texas Plants-South Texas Project”
section of Note 7).
|
(b)
|
The
current portion of our ARO, totaling $3 million, is included in
Other in
the Current Liabilities section in our Condensed Consolidated Balance
Sheets.
|
Three
Months Ended
June
30,
|
Six
Months Ended
June
30,
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
Related
Party Transactions
|
(in
millions)
|
||||||||||||
AEP
Consolidated Purchased Power - Ohio Valley Electric
Corporation (44.2% owned by AEP System )
|
$
|
48
|
$
|
36
|
$
|
91
|
$
|
70
|
Six
Months Ended June 30,
|
|||||||
2005
|
2004
|
||||||
Cash
Flow Information
|
(in
millions)
|
||||||
Cash
was paid (received) for:
|
|||||||
Interest
(net of capitalized amounts)
|
$
|
322
|
$
|
378
|
|||
Income
Taxes
|
86
|
(43
|
)
|
||||
Change
in construction-related Accounts Payable included in Investing
Activities
- Construction Expenditures
|
9 | (22 | ) | ||||
Noncash
Investing and Financing Activities:
|
|||||||
Acquisitions
Under Capital Leases
|
22
|
27
|
|||||
(Disposition)
of Liabilities Related to Divestitures
|
(22
|
)
|
(11
|
)
|
TCC
|
|||||||
June
30, 2005
|
December
31, 2004
|
||||||
(in
millions)
|
|||||||
Stranded
Generation Plant Costs
|
$
|
887
|
$
|
897
|
|||
Net
Generation-related Regulatory Asset
|
249
|
249
|
|||||
Unrefunded
Excess Earnings
|
(3
|
)
|
(10
|
)
|
|||
Net
Stranded Generation Costs
|
1,133
|
1,136
|
|||||
Carrying
Costs on Stranded Generation Plant Costs
|
215
|
225
|
|||||
Net
Stranded Generation Costs Designated for
Securitization
|
1,348
|
1,361
|
|||||
Wholesale
Capacity Auction True-up
|
483
|
483
|
|||||
Carrying
Costs on Wholesale Capacity Auction True-up
|
102
|
77
|
|||||
Retail
Clawback
|
(61
|
)
|
(61
|
)
|
|||
Deferred
Over-recovered Fuel Balance
|
(209
|
)
|
(212
|
)
|
|||
Net
Other Recoverable True-up Amounts
|
315
|
287
|
|||||
Total
Recorded Net True-up Regulatory Asset
|
$
|
1,663
|
$
|
1,648
|
TNC
|
|||||||
June
30, 2005
|
December
31, 2004
|
||||||
(in
millions)
|
|||||||
Retail
Clawback
|
$
|
(14
|
)
|
$
|
(14
|
)
|
|
Deferred
Over-recovered Fuel Balance
|
(5
|
)
|
(4
|
)
|
|||
Total
Recorded Net True-up Regulatory Liability
|
$
|
(19
|
)
|
$
|
(18
|
)
|
SEEBOARD
(a)
|
U.K.
Operations (b)
|
Total
|
||||||||
(in
millions)
|
||||||||||
2005
Revenue
|
$
|
-
|
$
|
-
|
$
|
-
|
||||
2005
Pretax Income (Loss)
|
-
|
-
|
-
|
|||||||
2005
Income (Loss) After tax
|
3
|
-
|
3
|
Pushan
Power Plant
|
LIG
(c)
|
U.K.
Operations
|
Total
|
||||||||||
(in
millions)
|
|||||||||||||
2004
Revenue
|
$
|
-
|
$
|
4
|
$
|
34
|
$
|
38
|
|||||
2004
Pretax Income (Loss)
|
-
|
2
|
(80
|
)
|
(78
|
)
|
|||||||
2004
Income (Loss) After tax
|
(1
|
)
|
2
|
(52
|
)
|
(51
|
)
|
SEEBOARD
(a)
|
U.K.
Operations (b)
|
Total
|
||||||||
(in
millions)
|
||||||||||
2005
Revenue
|
$
|
-
|
$
|
-
|
$
|
-
|
||||
2005
Pretax Income (Loss)
|
-
|
(8
|
)
|
(8
|
)
|
|||||
2005
Income (Loss) After tax
|
9
|
(5
|
)
|
4
|
Pushan
Power Plant
|
LIG
(c)
|
U.K.
Operations
|
Total
|
||||||||||
(in
millions)
|
|||||||||||||
2004
Revenue
|
$
|
10
|
$
|
164
|
$
|
75
|
$
|
249
|
|||||
2004
Pretax Income (Loss)
|
9
|
1
|
(99
|
)
|
(89
|
)
|
|||||||
2004
Income (Loss) After tax
|
5
|
1
|
(64
|
)
|
(58
|
)
|
Texas
Plants
|
|||||||
June
30, 2005
|
December
31, 2004
|
||||||
Assets:
|
(in
millions)
|
||||||
Other
Current Assets
|
$
|
2
|
$
|
24
|
|||
Property,
Plant and Equipment, Net
|
44
|
413
|
|||||
Regulatory
Assets
|
-
|
48
|
|||||
Nuclear
Decommissioning Trust Fund
|
-
|
143
|
|||||
Total
Assets Held for Sale
|
$
|
46
|
$
|
628
|
|||
Liabilities:
|
|||||||
Regulatory
Liabilities
|
$
|
1
|
$
|
1
|
|||
Asset
Retirement Obligations
|
-
|
249
|
|||||
Total
Liabilities Held for Sale
|
$
|
1
|
$
|
250
|
Three
Months Ended June 30, 2005 and 2004:
|
Pension
Plans
|
Other
Postretirement Benefit Plans
|
|||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
(in
millions)
|
|||||||||||||
Service
Cost
|
$
|
23
|
$
|
21
|
$
|
10
|
$
|
10
|
|||||
Interest
Cost
|
56
|
56
|
26
|
29
|
|||||||||
Expected
(Return) on Plan Assets
|
(78
|
)
|
(72
|
)
|
(22
|
)
|
(20
|
)
|
|||||
Amortization
of Transition Obligation
|
-
|
1
|
7
|
7
|
|||||||||
Amortization
of Net Actuarial Loss
|
14
|
4
|
7
|
9
|
|||||||||
Net
Periodic Benefit Cost
|
$
|
15
|
$
|
10
|
$
|
28
|
$
|
35
|
Six
Months Ended June 30, 2005 and 2004:
|
Pension
Plans
|
Other
Postretirement Benefit Plans
|
|||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
(in
millions)
|
|||||||||||||
Service
Cost
|
$
|
46
|
$
|
43
|
$
|
21
|
$
|
20
|
|||||
Interest
Cost
|
112
|
112
|
53
|
58
|
|||||||||
Expected
(Return) on Plan Assets
|
(155
|
)
|
(144
|
)
|
(45
|
)
|
(40
|
)
|
|||||
Amortization
of Transition Obligation
|
-
|
1
|
14
|
14
|
|||||||||
Amortization
of Net Actuarial Loss
|
27
|
8
|
14
|
18
|
|||||||||
Net
Periodic Benefit Cost
|
$
|
30
|
$
|
20
|
$
|
57
|
$
|
70
|
·
|
Domestic
generation of electricity for sale to retail and wholesale
customers.
|
·
|
Domestic
electricity transmission and
distribution.
|
·
|
Gas
pipeline and storage services.
|
·
|
Gas
marketing and risk management activities.
|
Operations
of Louisiana Intrastate Gas, including Jefferson Island Storage,
were
classified as Discontinued Operations during 2003 and were sold
during
the third and fourth quarters of 2004, respectively. We sold our
98%
interest in HPL during the first quarter of
2005.
|
·
|
International
generation of electricity for sale to wholesale
customers.
|
·
|
Coal
procurement and transportation to our plants.
|
UK
Operations were classified as Discontinued Operations during 2003
and were
sold during the third quarter of
2004.
|
·
|
Bulk
commodity barging operations, wind farms, independent power producers
and
other energy supply related businesses.
|
Four
independent power producers were sold during the third and fourth
quarters
of 2004.
|
Investments
|
||||||||||||||||||||||
Three
Months Ended
|
Utility
Operations
|
Gas
Operations
|
UK
Operations
|
Other
|
All
Other (a)
|
Reconciling
Adjustments (b)
|
Consolidated
|
|||||||||||||||
June
30, 2005
|
(in
millions)
|
|||||||||||||||||||||
Revenues
from:
|
||||||||||||||||||||||
External
Customers
|
$
|
2,649
|
$
|
19
|
$
|
-
|
$
|
105
|
$
|
-
|
$
|
-
|
$
|
2,773
|
||||||||
Other
Operating Segments
|
19
|
(17
|
)
|
-
|
3
|
-
|
(5
|
)
|
-
|
|||||||||||||
Total
Revenues
|
$
|
2,668
|
$
|
2
|
$
|
-
|
$
|
108
|
$
|
-
|
$
|
(5
|
)
|
$
|
2,773
|
|||||||
Income
(Loss) Before Discontinued Operations
|
$
|
247
|
$
|
(2
|
)
|
$
|
-
|
$
|
(1
|
)
|
$
|
(26
|
)
|
$
|
-
|
$
|
218
|
|||||
Discontinued
Operations, Net of Tax
|
-
|
-
|
-
|
3
|
-
|
-
|
3
|
|||||||||||||||
Net
Income (Loss)
|
$
|
247
|
$
|
(2
|
)
|
$
|
-
|
$
|
2
|
$
|
(26
|
)
|
$
|
-
|
$
|
221
|
||||||
As
of June 30, 2005
|
||||||||||||||||||||||
Total
Property, Plant and Equipment
|
$
|
36,736
|
$
|
2
|
$
|
-
|
$
|
834
|
$
|
3
|
$
|
-
|
$
|
37,575
|
||||||||
Accumulated
Depreciation and Amortization
|
14,580
|
1
|
-
|
100
|
1
|
-
|
14,682
|
|||||||||||||||
Total
Property, Plant and Equipment - Net
|
$
|
22,156
|
$
|
1
|
$
|
-
|
$
|
734
|
$
|
2
|
$
|
-
|
$
|
22,893
|
||||||||
Total
Assets
|
$
|
31,965
|
$
|
1,028
|
$
|
574
|
(c) |
$
|
421
|
$
|
9,269
|
$
|
(9,318
|
)
|
$
|
33,939
|
||||||
Assets
Held for Sale
|
46
|
-
|
-
|
-
|
-
|
-
|
46
|
(a)
|
All
Other includes interest, litigation and other miscellaneous parent
company
expenses.
|
(b)
|
Reconciling
Adjustments for Total Assets primarily include the elimination
of
intercompany advances to affiliates and intercompany accounts receivable
along with the elimination of AEP’s investments in subsidiary
companies.
|
(c)
|
Total
Assets of $574 million for the Investments-UK Operations segment
include
$553 million in affiliated accounts receivable related to federal
income
taxes that are eliminated in consolidation. The majority of the
remaining
$21 million in assets represents cash equivalents along with value-added
tax receivables.
|
Investments
|
||||||||||||||||||||||
Three
Months Ended
|
Utility
Operations
|
Gas
Operations
|
UK
Operations
|
Other
|
All
Other (a)
|
Reconciling
Adjustments (b)
|
Consolidated
|
|||||||||||||||
June
30, 2004
|
(in
millions)
|
|||||||||||||||||||||
Revenues
from:
|
||||||||||||||||||||||
External
Customers
|
$
|
2,508
|
$
|
779
|
$
|
-
|
$
|
124
|
$
|
-
|
$
|
-
|
$
|
3,411
|
||||||||
Other
Operating Segments
|
37
|
15
|
-
|
7
|
(2
|
)
|
(57
|
)
|
-
|
|||||||||||||
Total
Revenues
|
$
|
2,545
|
$
|
794
|
$
|
-
|
$
|
131
|
$
|
(2
|
)
|
$
|
(57
|
)
|
$
|
3,411
|
||||||
Income
(Loss) Before Discontinued
Operations
|
$
|
184
|
$
|
(4
|
)
|
$
|
-
|
$
|
(4
|
)
|
$
|
(25
|
)
|
$
|
-
|
$
|
151
|
|||||
Discontinued
Operations, Net of Tax
|
-
|
2
|
(52
|
)
|
(1
|
)
|
-
|
-
|
(51
|
)
|
||||||||||||
Net
Income (Loss)
|
$
|
184
|
$
|
(2
|
)
|
$
|
(52
|
)
|
$
|
(5
|
)
|
$
|
(25
|
)
|
$
|
-
|
$
|
100
|
||||
As
of December 31, 2004
|
||||||||||||||||||||||
Total
Property, Plant and Equipment
|
$
|
36,006
|
$
|
445
|
$
|
-
|
$
|
832
|
$
|
3
|
$
|
-
|
$
|
37,286
|
||||||||
Accumulated
Depreciation and Amortization
|
14,355
|
43
|
-
|
86
|
1
|
-
|
14,485
|
|||||||||||||||
Total
Property, Plant and Equipment - Net
|
$
|
21,651
|
$
|
402
|
$
|
-
|
$
|
746
|
$
|
2
|
$
|
-
|
$
|
22,801
|
||||||||
Total
Assets
|
$
|
32,175
|
$
|
1,789
|
$
|
221
|
(c) |
$
|
2,071
|
$
|
8,093
|
$
|
(9,686
|
)
|
$
|
34,663
|
||||||
Assets
Held for Sale
|
628
|
-
|
-
|
-
|
-
|
-
|
628
|
(a)
|
All
Other includes interest, litigation and other miscellaneous parent
company
expenses.
|
(b)
|
Reconciling
Adjustments for Total Assets primarily include the elimination
of
intercompany advances to affiliates and intercompany accounts receivable
along with the elimination of AEP’s investments in subsidiary
companies.
|
(c)
|
Total
Assets of $221 million for the Investments-UK Operations segment
include
$124 million in affiliated accounts receivable that are eliminated
in
consolidation. The majority of the remaining $97 million in assets
represents cash equivalents and third party
receivables.
|
Investments
|
||||||||||||||||||||||
Six
Months Ended
|
Utility
Operations
|
Gas
Operations
|
UK
Operations
|
Other
|
All
Other (a)
|
Reconciling
Adjustments (b)
|
Consolidated
|
|||||||||||||||
June
30, 2005
|
(in
millions)
|
|||||||||||||||||||||
Revenues
from:
|
||||||||||||||||||||||
External
Customers
|
$
|
5,186
|
$
|
376
|
$
|
-
|
$
|
194
|
$
|
-
|
$
|
-
|
$
|
5,756
|
||||||||
Other
Operating Segments
|
96
|
(90
|
)
|
-
|
6
|
1
|
(13
|
)
|
-
|
|||||||||||||
Total
Revenues
|
$
|
5,282
|
$
|
286
|
$
|
-
|
$
|
200
|
$
|
1
|
$
|
(13
|
)
|
$
|
5,756
|
|||||||
Income
(Loss) Before Discontinued Operations
|
$
|
600
|
$
|
8
|
$
|
-
|
$
|
4
|
$
|
(40
|
)
|
$
|
-
|
$
|
572
|
|||||||
Discontinued
Operations, Net of Tax
|
-
|
-
|
(5
|
)
|
9
|
-
|
-
|
4
|
||||||||||||||
Net
Income (Loss)
|
$
|
600
|
$
|
8
|
$
|
(5
|
)
|
$
|
13
|
$
|
(40
|
)
|
$
|
-
|
$
|
576
|
||||||
As
of June 30, 2005
|
||||||||||||||||||||||
Total
Property, Plant and Equipment
|
$
|
36,736
|
$
|
2
|
$
|
-
|
$
|
834
|
$
|
3
|
$
|
-
|
$
|
37,575
|
||||||||
Accumulated
Depreciation and Amortization
|
14,580
|
1
|
-
|
100
|
1
|
-
|
14,682
|
|||||||||||||||
Total
Property, Plant and Equipment - Net
|
$
|
22,156
|
$
|
1
|
$
|
-
|
$
|
734
|
$
|
2
|
$
|
-
|
$
|
22,893
|
||||||||
Total
Assets
|
$
|
31,965
|
$
|
1,028
|
$
|
574
|
(c) |
$
|
421
|
$
|
9,269
|
$
|
(9,318
|
)
|
$
|
33,939
|
||||||
Assets
Held for Sale
|
46
|
-
|
-
|
-
|
-
|
-
|
46
|
(a)
|
All
Other includes interest, litigation and other miscellaneous parent
company
expenses.
|
(b)
|
Reconciling
Adjustments for Total Assets primarily include the elimination
of
intercompany advances to affiliates and intercompany accounts receivable
along with the elimination of AEP’s investments in subsidiary
companies.
|
(c)
|
Total
Assets of $574 million for the Investments-UK Operations segment
include
$553 million in affiliated accounts receivable related to federal
income
taxes that are eliminated in consolidation. The majority of the
remaining
$21 million in assets represents cash equivalents and third party
receivables.
|
Investments
|
||||||||||||||||||||||
Six
Months Ended
|
Utility
Operations
|
Gas
Operations
|
UK
Operations
|
Other
|
All
Other (a)
|
Reconciling
Adjustments (b)
|
Consolidated
|
|||||||||||||||
June
30, 2004
|
(in
millions)
|
|||||||||||||||||||||
Revenues
from:
|
||||||||||||||||||||||
External
Customers
|
$
|
5,089
|
$
|
1,431
|
$
|
-
|
$
|
255
|
$
|
-
|
$
|
-
|
$
|
6,775
|
||||||||
Other
Operating Segments
|
58
|
39
|
-
|
27
|
4
|
(128
|
)
|
-
|
||||||||||||||
Total
Revenues
|
$
|
5,147
|
$
|
1,470
|
$
|
-
|
$
|
282
|
$
|
4
|
$
|
(128
|
)
|
$
|
6,775
|
|||||||
Income
(Loss) Before Discontinued Operations
|
$
|
488
|
$
|
(14
|
)
|
$
|
-
|
$
|
-
|
$
|
(34
|
)
|
$
|
-
|
$
|
440
|
||||||
Discontinued
Operations, Net of Tax
|
-
|
1
|
(64
|
)
|
5
|
-
|
-
|
(58
|
)
|
|||||||||||||
Net
Income (Loss)
|
$
|
488
|
$
|
(13
|
)
|
$
|
(64
|
)
|
$
|
5
|
$
|
(34
|
)
|
$
|
-
|
$
|
382
|
|||||
As
of December 31, 2004
|
||||||||||||||||||||||
Total
Property, Plant and Equipment
|
$
|
36,006
|
$
|
445
|
$
|
-
|
$
|
832
|
$
|
3
|
$
|
-
|
$
|
37,286
|
||||||||
Accumulated
Depreciation and Amortization
|
14,355
|
43
|
-
|
86
|
1
|
-
|
14,485
|
|||||||||||||||
Total
Property, Plant and Equipment - Net
|
$
|
21,651
|
$
|
402
|
$
|
-
|
$
|
746
|
$
|
2
|
$
|
-
|
$
|
22,801
|
||||||||
Total
Assets
|
$
|
32,175
|
$
|
1,789
|
$
|
221
|
(c) |
$
|
2,071
|
$
|
8,093
|
$
|
(9,686
|
)
|
$
|
34,663
|
||||||
Assets
Held for Sale
|
628
|
-
|
-
|
-
|
-
|
-
|
628
|
(a)
|
All
Other includes interest, litigation and other miscellaneous parent
company
expenses.
|
(b)
|
Reconciling
Adjustments for Total Assets primarily include the elimination
of
intercompany advances to affiliates and intercompany accounts receivable
along with the elimination of AEP’s investments in subsidiary
companies.
|
(c)
|
Total
Assets of $221 million for the Investments-UK Operations segment
include
$124 million in affiliated accounts receivable that are eliminated
in
consolidation. The majority of the remaining $97 million in assets
represents cash equivalents and third party
receivables.
|
Company
|
Type
of Debt
|
Principal
Amount
|
Interest
Rate
|
Due
Date
|
||||||
(in
millions)
|
||||||||||
Issuances:
|
||||||||||
AEP
|
Senior
Unsecured Notes
|
$
|
345
|
4.709%
|
2007
|
|||||
APCo
|
Senior
Unsecured Notes
|
200
|
4.95%
|
2015
|
||||||
APCo
|
Senior
Unsecured Notes
|
150
|
4.40%
|
2010
|
||||||
APCo
|
Senior
Unsecured Notes
|
250
|
5.00%
|
2017
|
||||||
OPCo
|
Installment
Purchase Contracts
|
54
|
Variable
|
2029
|
||||||
OPCo
|
Installment
Purchase Contracts
|
164
|
Variable
|
2028
|
||||||
PSO
|
Senior
Unsecured Notes
|
75
|
4.70%
|
2011
|
||||||
SWEPCo
|
Senior
Unsecured Notes
|
150
|
4.90%
|
2015
|
||||||
TCC
|
Installment
Purchase Contracts
|
162
|
Variable
|
2030
|
||||||
TCC
|
Installment
Purchase Contracts
|
120
|
Variable
|
2028
|
||||||
Non-Registrant:
|
||||||||||
AEP
Subsidiary
|
Notes
Payable
|
6
|
Variable
|
2009
|
||||||
Total
Issuances
|
$
|
1,676
|
(a)
|
(a)
|
Amount
indicated on statement of cash flows of $1,660 million is net of
issuance
costs and unamortized premium or
discount.
|
Company
|
Type
of Debt
|
Principal
Amount
|
Interest
Rate
|
Due
Date
|
||||||
(in
millions)
|
||||||||||
Retirements
and Principal Payments:
|
||||||||||
AEP
|
Senior
Unsecured Notes
|
$
|
550
|
6.125%
|
2006
|
|||||
AEP
|
Senior
Unsecured Notes
|
345
|
5.75%
|
2007
|
||||||
AEP
|
Other
Debt
|
6
|
Variable
|
2007
|
||||||
AEP
and Subsidiaries
|
Other
|
12
|
(b)
|
Variable
|
Various
|
|||||
APCo
|
First
Mortgage Bonds
|
50
|
8.00%
|
2005
|
||||||
APCo
|
First
Mortgage Bonds
|
30
|
6.89%
|
2005
|
||||||
APCo
|
First
Mortgage Bonds
|
45
|
8.00%
|
2025
|
||||||
APCo
|
Senior
Unsecured Notes
|
450
|
4.80%
|
2005
|
||||||
OPCo
|
Installment
Purchase Contracts
|
102
|
6.375%
|
2029
|
||||||
OPCo
|
Installment
Purchase Contracts
|
80
|
Variable
|
2028
|
||||||
OPCo
|
Installment
Purchase Contracts
|
36
|
Variable
|
2029
|
||||||
OPCo
|
Notes
Payable
|
3
|
6.81%
|
2008
|
||||||
OPCo
|
Notes
Payable
|
3
|
6.27%
|
2009
|
||||||
PSO
|
First
Mortgage Bonds
|
50
|
6.50%
|
2005
|
||||||
SWEPCo
|
Notes
Payable
|
3
|
4.47%
|
2011
|
||||||
SWEPCo
|
Notes
Payable
|
2
|
Variable
|
2008
|
||||||
TCC
|
Senior
Unsecured Notes
|
150
|
3.00%
|
2005
|
||||||
TCC
|
Senior
Unsecured Notes
|
100
|
Variable
|
2005
|
||||||
TCC
|
Securitization
Bonds
|
29
|
3.54%
|
2005
|
||||||
Non-Registrant:
|
||||||||||
AEP
Subsidiaries
|
Notes
Payable
|
6
|
Variable
|
Various
|
||||||
Total
Retirements
|
$
|
2,052
|
(c)
|
(b)
|
Amount
reflects mark-to-market of risk management contracts related to
long-term
debt.
|
(c)
|
The
cash used for retirement of long-term debt indicated on statement
of cash
flows of $2,040 million does not include $12 million related to
the
mark-to-market of risk management
contracts.
|
Company
|
Series
|
Number
of Shares Redeemed
|
Amount
|
|||||
(in
millions)
|
||||||||
I&M
|
5.900%
|
132,000
|
$
|
13
|
||||
I&M
|
6.250%
|
192,500
|
19
|
|||||
I&M
|
6.875%
|
157,500
|
16
|
|||||
I&M
|
6.300%
|
132,450
|
13
|
|||||
OPCo
|
5.900%
|
50,000
|
5
|
|||||
$
|
66
|
Amount
(in
millions)
|
||||
Total
Expense
|
$
|
24
|
||
Less:
Total Payments
|
3
|
|||
Remaining
Accrual at June 30, 2005
|
$
|
21
|
Second
Quarter of 2004 Net Income
|
$
|
1.5
|
|||||
Change
in Gross Margin:
|
|||||||
Wholesale
Sales
|
0.5
|
||||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
0.1
|
||||||
Depreciation
and Amortization
|
(0.2
|
)
|
|||||
Interest
Charges
|
0.2
|
||||||
Total
Change in Operating Expenses and Other
|
0.1
|
||||||
Income
Tax Expense
|
-
|
||||||
Second
Quarter of 2005 Net Income
|
$
|
2.1
|
Six
Months Ended June 30, 2004 Net Income
|
$
|
3.3
|
|||||
Change
in Gross Margin:
|
|||||||
Wholesale
Sales
|
(1.9
|
)
|
|||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
3.9
|
||||||
Depreciation
and Amortization
|
(0.4
|
)
|
|||||
Taxes
Other Than Income Taxes
|
(0.2
|
)
|
|||||
Nonoperating
Income and Expenses, Net
|
0.1
|
||||||
Total
Change in Operating Expenses and Other
|
3.4
|
||||||
Income
Tax Expense
|
(0.2
|
)
|
|||||
Six
Months Ended June 30, 2005 Net Income
|
$
|
4.6
|
Three
Months Ended
|
Six
Months Ended
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
OPERATING
REVENUES
|
$
|
65,082
|
$
|
56,348
|
$
|
131,628
|
$
|
111,630
|
|||||
OPERATING
EXPENSES
|
|||||||||||||
Fuel
for Electric Generation
|
33,233
|
25,036
|
68,368
|
46,434
|
|||||||||
Rent
- Rockport Plant Unit 2
|
17,071
|
17,071
|
34,142
|
34,142
|
|||||||||
Other
Operation
|
3,075
|
2,665
|
5,460
|
5,155
|
|||||||||
Maintenance
|
2,272
|
2,790
|
3,990
|
8,190
|
|||||||||
Depreciation
and Amortization
|
5,989
|
5,772
|
11,945
|
11,506
|
|||||||||
Taxes
Other Than Income Taxes
|
1,051
|
942
|
2,075
|
1,886
|
|||||||||
Income
Taxes
|
666
|
699
|
1,602
|
1,397
|
|||||||||
TOTAL
|
63,357
|
54,975
|
127,582
|
108,710
|
|||||||||
OPERATING
INCOME
|
1,725
|
1,373
|
4,046
|
2,920
|
|||||||||
Nonoperating
Income
|
84
|
5
|
84
|
29
|
|||||||||
Nonoperating
Expenses
|
49
|
80
|
113
|
149
|
|||||||||
Nonoperating
Income Tax Credit
|
877
|
947
|
1,768
|
1,804
|
|||||||||
Interest
Charges
|
564
|
739
|
1,196
|
1,271
|
|||||||||
NET
INCOME
|
$
|
2,073
|
$
|
1,506
|
$
|
4,589
|
$
|
3,333
|
|||||
Three
Months Ended
|
Six
Months Ended
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
BALANCE
AT BEGINNING OF PERIOD
|
$
|
25,813
|
$
|
22,006
|
$
|
24,237
|
$
|
21,441
|
|||||
Net
Income
|
2,073
|
1,506
|
4,589
|
3,333
|
|||||||||
Cash
Dividends Declared
|
939
|
1,261
|
1,879
|
2,523
|
|||||||||
BALANCE
AT END OF PERIOD
|
$
|
26,947
|
$
|
22,251
|
$
|
26,947
|
$
|
22,251
|
2005
|
2004
|
||||||
ELECTRIC
UTILITY PLANT
|
|||||||
Production
|
$
|
681,917
|
$
|
681,254
|
|||
General
|
3,937
|
3,739
|
|||||
Construction
Work in Progress
|
6,760
|
7,729
|
|||||
Total
|
692,614
|
692,722
|
|||||
Accumulated
Depreciation and Amortization
|
376,111
|
368,484
|
|||||
TOTAL
- NET
|
316,503
|
324,238
|
|||||
OTHER
PROPERTY AND INVESTMENTS
|
|||||||
Nonutility
Property, Net
|
119
|
119
|
|||||
CURRENT
ASSETS
|
|||||||
Accounts
Receivable - Affiliated Companies
|
24,159
|
23,078
|
|||||
Fuel
|
11,426
|
16,404
|
|||||
Materials
and Supplies
|
6,675
|
5,962
|
|||||
Prepayments
|
26
|
-
|
|||||
TOTAL
|
42,286
|
45,444
|
|||||
DEFERRED
DEBITS AND OTHER ASSETS
|
|||||||
Regulatory
Assets:
|
|||||||
Unamortized
Loss on Reacquired Debt
|
4,377
|
4,496
|
|||||
Asset
Retirement Obligations
|
1,214
|
1,117
|
|||||
Deferred
Property Taxes
|
2,507
|
557
|
|||||
Other
Deferred Charges
|
412
|
422
|
|||||
TOTAL
|
8,510
|
6,592
|
|||||
TOTAL
ASSETS
|
$
|
367,418
|
$
|
376,393
|
2005
|
2004
|
||||||
CAPITALIZATION
|
(in
thousands)
|
||||||
Common
Shareholder’s Equity:
|
|||||||
Common
Stock - $1,000 par value per share:
|
|||||||
Authorized
and Outstanding - 1,000 shares
|
$
|
1,000
|
$
|
1,000
|
|||
Paid-in
Capital
|
23,434
|
23,434
|
|||||
Retained
Earnings
|
26,947
|
24,237
|
|||||
Total
Common Shareholder’s Equity
|
51,381
|
48,671
|
|||||
Long-term
Debt
|
44,824
|
44,820
|
|||||
TOTAL
|
96,205
|
93,491
|
|||||
CURRENT
LIABILITIES
|
|||||||
Advances
from Affiliates
|
24,621
|
26,915
|
|||||
Accounts
Payable:
|
|||||||
General
|
708
|
443
|
|||||
Affiliated
Companies
|
15,235
|
17,905
|
|||||
Taxes
Accrued
|
6,764
|
8,806
|
|||||
Interest
Accrued
|
911
|
911
|
|||||
Obligations
Under Capital Leases
|
289
|
210
|
|||||
Rent
Accrued - Rockport Plant Unit 2
|
4,963
|
4,963
|
|||||
Other
|
348
|
73
|
|||||
TOTAL
|
53,839
|
60,226
|
|||||
DEFERRED
CREDITS AND OTHER LIABILITIES
|
|||||||
Deferred
Income Taxes
|
22,990
|
24,762
|
|||||
Regulatory
Liabilities:
|
|||||||
Asset
Removal Costs
|
27,104
|
25,428
|
|||||
Deferred
Investment Tax Credits
|
44,582
|
46,250
|
|||||
SFAS
109 Regulatory Liability, Net
|
12,245
|
12,852
|
|||||
Deferred
Gain on Sale and Leaseback - Rockport Plant Unit 2
|
97,119
|
99,904
|
|||||
Obligations
Under Capital Leases
|
12,070
|
12,264
|
|||||
Asset
Retirement Obligations
|
1,264
|
1,216
|
|||||
TOTAL
|
217,374
|
222,676
|
|||||
Commitments
and Contingencies (Note 5)
|
|||||||
TOTAL
CAPITALIZATION AND LIABILITIES
|
$
|
367,418
|
$
|
376,393
|
2005
|
2004
|
||||||
OPERATING
ACTIVITIES
|
|||||||
Net
Income
|
$
|
4,589
|
$
|
3,333
|
|||
Adjustments
to Reconcile Net Income to Net Cash Flows From Operating
Activities:
|
|||||||
Depreciation
and Amortization
|
11,945
|
11,506
|
|||||
Deferred
Income Taxes
|
(2,379
|
)
|
(1,319
|
)
|
|||
Deferred
Investment Tax Credits
|
(1,668
|
)
|
(1,668
|
)
|
|||
Deferred
Property Taxes
|
(1,950
|
)
|
(1,632
|
)
|
|||
Amortization
of Deferred Gain on Sale and Leaseback - Rockport Plant
Unit
2
|
(2,785
|
)
|
(2,785
|
)
|
|||
Change
in Other Noncurrent Assets
|
(1,296
|
)
|
(67
|
)
|
|||
Change
in Other Noncurrent Liabilities
|
1,534
|
73
|
|||||
Changes
in Components of Working Capital:
|
|||||||
Accounts
Receivable
|
(1,081
|
)
|
752
|
||||
Fuel,
Materials and Supplies
|
4,265
|
(4,011
|
)
|
||||
Accounts
Payable
|
(2,405
|
)
|
(2,226
|
)
|
|||
Taxes
Accrued
|
(2,042
|
)
|
4,457
|
||||
Other
Current Assets
|
(26
|
)
|
(21
|
)
|
|||
Other
Current Liabilities
|
354
|
80
|
|||||
Net
Cash Flows From Operating Activities
|
7,055
|
6,472
|
|||||
INVESTING
ACTIVITIES
|
|||||||
Construction
Expenditures
|
(2,882
|
)
|
(9,815
|
)
|
|||
Net
Cash Flows Used For Investing Activities
|
(2,882
|
)
|
(9,815
|
)
|
|||
FINANCING
ACTIVITIES
|
|||||||
Changes
in Advances from Affiliates, Net
|
(2,294
|
)
|
5,866
|
||||
Dividends
Paid
|
(1,879
|
)
|
(2,523
|
)
|
|||
Net
Cash Flows From (Used For) Financing Activities
|
(4,173
|
)
|
3,343
|
||||
Net
Increase in Cash and Cash Equivalents
|
-
|
-
|
|||||
Cash
and Cash Equivalents at Beginning of Period
|
-
|
-
|
|||||
Cash
and Cash Equivalents at End of Period
|
$
|
-
|
$
|
-
|
SUPPLEMENTAL
DISCLOSURE:
|
|||
Cash
paid for interest net of capitalized amounts was $1,063,000 and
$1,138,000
and for income taxes was $8,080,000 and $570,000 in 2005 and 2004,
respectively. Noncash acquisitions under capital leases were $26,000
and
$14,000 in 2005 and 2004,
respectively.
|
Footnote
Reference
|
|
Significant
Accounting Matters
|
Note
1
|
New
Accounting Pronouncements
|
Note
2
|
Commitments
and Contingencies
|
Note
5
|
Guarantees
|
Note
6
|
Business
Segments
|
Note
9
|
Financing
Activities
|
Note
11
|
Company-wide
Staffing and Budget Review
|
Note
12
|
Second
Quarter of 2004 Net Income
|
$
|
-
|
|||||
Changes
in Gross Margin:
|
|||||||
Texas
Supply
|
2
|
||||||
Texas
Wires
|
8
|
||||||
Off-system
Sales
|
(4
|
)
|
|||||
Transmission
Revenues
|
(1
|
)
|
|||||
Total
Change in Gross Margin
|
5
|
||||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
22
|
||||||
Depreciation
and Amortization
|
(7
|
)
|
|||||
Taxes
Other Than Income Taxes
|
2
|
||||||
Carrying
Costs on Stranded Cost Recovery
|
20
|
||||||
Total
Change in Operating Expenses and Other
|
37
|
||||||
Income
Tax Expense
|
(14
|
)
|
|||||
Second
Quarter of 2005 Net Income
|
$
|
28
|
·
|
Texas
Supply margins were $2 million higher primarily due to a provision
for
refund decrease in 2004 of $52 million as a result of the 2004
final fuel
reconciliation true-up, lower fuel expense of $77 million, and
an increase
in realized dedicated gas revenue of $6 million. The increase in
Texas
Supply margins was offset by the loss of revenue from Centrica,
our
largest REP customer, of $96 million, loss of ERCOT Reliability
Must Run
(RMR) margins of $9 million and decreased ERCOT Energy sales of
$11
million. Also contributing to the offset of higher Texas Supply
margins
were the loss of capacity sales of $9 million due to the sale of
certain
generation plants and a decrease of $6 million of affiliated REP
sales due
to loss of customers for AEP Texas C&I.
|
·
|
Wires
revenues increased $8 million primarily due to an increase in sales
volumes of 7% resulting partly from a 12% increase in cooling degree
days.
|
·
|
Margins
from Off-system Sales decreased $4 million primarily due to lower
optimization activity.
|
·
|
Other
Operation and Maintenance expenses decreased $22 million primarily
due to
a $9 million decrease in power plant operations and an $11 million
decrease in power plant maintenance both due to the sale of certain
generation plants along with a $2 million decrease in employee-related
expenses.
|
·
|
Depreciation
and Amortization expense increased $7 million primarily due to
the
recovery and amortization of securitized assets.
|
·
|
Taxes
Other Than Income Taxes decreased $2 million primarily due to lower
property-related taxes as a result of the sale of certain generation
plants.
|
·
|
Carrying
Costs on Stranded Cost Recovery of $20 million were recorded in
the second
quarter of 2005.
|
Six
Months Ended June 30, 2004 Net Income
|
$
|
29
|
|||||
Changes
in Gross Margin:
|
|||||||
Texas
Supply
|
(33
|
)
|
|||||
Texas
Wires
|
9
|
||||||
Off-system
Sales
|
(5
|
)
|
|||||
Other
Revenues
|
(9
|
)
|
|||||
Total
Change in Gross Margin
|
(38
|
)
|
|||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
30
|
||||||
Depreciation
and Amortization
|
(7
|
)
|
|||||
Taxes
Other Than Income Taxes
|
2
|
||||||
Carrying
Costs on Stranded Cost Recovery
|
15
|
||||||
Nonoperating
Income and Expense, Net
|
(6
|
)
|
|||||
Interest
Charges
|
6
|
||||||
Total
Change in Operating Expenses and Other
|
40
|
||||||
Income
Tax Expense
|
(1
|
)
|
|||||
Six
Months ended June 30, 2005 Net Income
|
$
|
30
|
·
|
Texas
Supply margins were $33 million lower primarily due to the loss
of revenue
from Centrica, our largest REP customer, of $172 million, loss
of ERCOT
RMR margins of $16 million and decreased ERCOT Energy sales of
$14
million. Also contributing to the lower Texas Supply margins were
the loss
of capacity sales of $17 million due to the sale of certain generation
plants and a decrease of $7 million of affiliated REP sales due
to loss of
customers for AEP Texas C&I. These decreases were partially offset by
a decrease in 2004 for provision for refund of $62 million due
to the 2004
final fuel reconciliation true-up and lower fuel expense of $134
million.
|
·
|
Texas
Wires revenue increased $9 million primarily due to an increase
in sales
volumes of 4% due in large part to increased degree days.
|
·
|
Margins
from Off-system Sales decreased $5 million primarily due to lower
optimization activity.
|
·
|
Other
Revenues for 2005 decreased $9 million primarily due to a prior
year
adjustment in 2004 for affiliated OATT and ancillary services resulting
from revised ERCOT data received for the years 2001 through
2003.
|
·
|
Other
Operation and Maintenance expenses decreased $30 million primarily
due to
a $14 million decrease in power plant operations and a $10 million
decrease in power plant maintenance both due to the sale of certain
generation plants, and a $9 million decrease in administrative,
general
and employee- related expenses offset in part by slightly higher
transmission and distribution-related expenses.
|
·
|
Depreciation
and Amortization expense increased $7 million primarily related
to the
recovery and amortization of securitized assets.
|
·
|
Taxes
Other Than Income Taxes decreased $2 million primarily due to lower
property-related taxes as a result of the sale of certain generation
plants.
|
·
|
Carrying
Costs on Stranded Cost Recovery increased $15 million. Carrying
Costs on
Stranded Cost Recovery of $42 million were recorded in the first
six
months of 2005 offset by an adjustment of $27 million for prior
years. The
adjustment related to a nonaffiliated utility’s securitization proceeding
in which the PUCT issued an order in March 2005 that resulted in
a
reduction in the nonaffiliated utility’s carrying costs based on a
methodology detailed in the order for calculating a cost-of-money
benefit
related to accumulated deferred federal income taxes on net stranded
cost
and other true-up items retroactively applied to January 1, 2004.
|
·
|
Nonoperating
Income and Expense, Net decreased $6 million primarily due to $14
million
of income in 2004 relating to risk management contracts which expired
in
December 2004 offset by higher net revenue from third party nonutility
construction projects and a decrease in donation
expense.
|
·
|
Interest
Charges decreased $6 million primarily due to the defeasance of
First
Mortgage Bonds in 2004 and the resultant deferral of the interest
cost as
a regulatory asset related to the cost of the sale of generation
assets,
the redemption of the 8% Notes Payable to Trust, long-term debt
maturities
and other financing activities.
|
Moody’s
|
S&P
|
Fitch
|
|||
First
Mortgage Bonds
|
Baa1
|
BBB
|
A
|
||
Senior
Unsecured Debt
|
Baa2
|
BBB
|
A-
|
2005
|
2004
|
||||||
(in
thousands)
|
|||||||
Cash
and Cash Equivalents at Beginning of Period
|
$
|
-
|
$
|
760
|
|||
Cash
Flows From (Used For):
|
|||||||
Operating
Activities
|
(109,779
|
)
|
118,275
|
||||
Investing
Activities
|
144,833
|
(163,139
|
)
|
||||
Financing
Activities
|
(32,960
|
)
|
49,914
|
||||
Net
Increase in Cash and Cash Equivalents
|
2,094
|
5,050
|
|||||
Cash
and Cash Equivalents at End of Period
|
$
|
2,094
|
$
|
5,810
|
Principal
|
Interest
|
Due
|
||||||||
Type
of Debt
|
Amount
|
Rate
|
Date
|
|||||||
(in
thousands)
|
(%)
|
|||||||||
Installment
Purchase Contract
|
$
|
111,700
|
Variable
|
2030
|
||||||
Installment
Purchase Contract
|
50,000
|
Variable
|
2030
|
|||||||
Installment
Purchase Contract
|
60,000
|
(a) |
Variable
|
2028
|
||||||
Installment
Purchase Contract
|
60,265
|
(a) |
Variable
|
2028
|
||||||
(a) -
represents issuance in advance of retirement $120 million, 6.0%
Installment Purchase Contracts
on July 1, 2005.
|
Principal
|
Interest
|
Due
|
||||||||
Type
of Debt
|
Amount
|
Rate
|
Date
|
|||||||
(in
thousands)
|
(%)
|
|||||||||
Senior
Unsecured Notes Payable
|
$
|
150,000
|
3.00
|
2005
|
||||||
Senior
Unsecured Notes Payable
|
100,000
|
Variable
|
2005
|
|||||||
Securitization
Bonds
|
29,386
|
3.54
|
2005
|
Total
MTM Risk Management Contract Net Assets at December 31,
2004
|
$
|
9,701
|
||
(Gain)
Loss from Contracts Realized/Settled During the Period (a)
|
(3,721
|
)
|
||
Fair
Value of New Contracts When Entered During the Period (b)
|
74
|
|||
Net
Option Premiums Paid/(Received) (c)
|
(11
|
)
|
||
Change
in Fair Value Due to Valuation Methodology Changes
|
-
|
|||
Changes
in Fair Value of Risk Management Contracts (d)
|
(3,427
|
)
|
||
Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions (e)
|
-
|
|||
Total
MTM Risk Management Contract Net Assets
|
2,616
|
|||
Net
Cash Flow Hedge Contracts (f)
|
(558
|
)
|
||
Total
MTM Risk Management Contract Net Assets at June 30,
2005
|
$
|
2,058
|
(a)
|
“(Gain)
Loss from Contracts Realized/Settled During the Period” includes realized
risk management contracts and related derivatives that settled
during 2005
where we entered into the contract prior to 2005.
|
(b)
|
“Fair
Value of New Contracts When Entered During the Period” represents the fair
value at inception of long-term contracts entered into with customers
during 2005. Most of the fair value comes from longer term fixed
price
contracts with customers that seek to limit their risk against
fluctuating
energy prices. Inception value is only recorded if observable market
data
can be obtained for valuation inputs for the entire contract term.
The
contract prices are valued against market curves associated with
the
delivery location and delivery term.
|
(c)
|
“Net
Option Premiums Paid/(Received)” reflects the net option premiums
paid/(received) as they relate to unexercised and unexpired option
contracts that were entered in 2005.
|
(d)
|
“Changes
in Fair Value of Risk Management Contracts” represents the fair value
change in the risk management portfolio due to market fluctuations
during
the current period. Market fluctuations are attributable to various
factors such as supply/demand, weather, etc.
|
(e)
|
“Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions” relates to the net gains (losses) of those contracts that
are not reflected in the Condensed Consolidated Statements of Operations.
These net gains (losses) are recorded as regulatory assets/liabilities
for
those subsidiaries that operate in regulated
jurisdictions.
|
(f)
|
“Net
Cash Flow Hedge Contracts” (pretax) are discussed below in Accumulated
Other Comprehensive Income (Loss).
|
MTM
Risk Management Contracts (a)
|
Cash
Flow Hedges
|
Total
(b)
|
||||||||
Current
Assets
|
$
|
3,995
|
$
|
22
|
$
|
4,017
|
||||
Noncurrent
Assets
|
4,977
|
6
|
4,983
|
|||||||
Total
MTM Derivative Contract Assets
|
8,972
|
28
|
9,000
|
|||||||
Current
Liabilities
|
(3,737
|
)
|
(535
|
)
|
(4,272
|
)
|
||||
Noncurrent
Liabilities
|
(2,619
|
)
|
(51
|
)
|
(2,670
|
)
|
||||
Total
MTM Derivative Contract Liabilities
|
(6,356
|
)
|
(586
|
)
|
(6,942
|
)
|
||||
Total
MTM Derivative Contract Net Assets (Liabilities)
|
$
|
2,616
|
$
|
(558
|
)
|
$
|
2,058
|
(a)
|
Does
not include Cash Flow Hedges.
|
(b)
|
Represents
amount of total MTM derivative contracts recorded within Risk Management
Assets, Long-term Risk Management Assets, Risk Management Liabilities
and
Long-term Risk Management Liabilities on our Condensed Consolidated
Balance Sheets.
|
·
|
The
source of fair value used in determining the carrying amount of
our total
MTM asset or liability (external sources or modeled
internally).
|
·
|
The
maturity, by year, of our net assets/liabilities, giving an indication
of
when these MTM amounts will settle and generate
cash.
|
Remainder
of 2005
|
2006
|
2007
|
2008
|
2009
|
After
2009
(c)
|
Total
(d)
|
||||||||||||||||
Prices
Actively Quoted - Exchange Traded
Contracts
|
$
|
(667
|
)
|
$
|
(5
|
)
|
$
|
529
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
(143
|
)
|
|||||
Prices
Provided by Other External Sources
- OTC Broker Quotes (a)
|
1,427
|
1,809
|
598
|
648
|
-
|
-
|
4,482
|
|||||||||||||||
Prices
Based on Models and Other Valuation
Methods (b)
|
(728
|
)
|
(1,291
|
)
|
(537
|
)
|
(57
|
)
|
407
|
483
|
(1,723
|
)
|
||||||||||
Total
|
$
|
32
|
$
|
513
|
$
|
590
|
$
|
591
|
$
|
407
|
$
|
483
|
$
|
2,616
|
(a)
|
“Prices
Provided by Other External Sources - OTC Broker Quotes” reflects
information obtained from over-the-counter brokers, industry services,
or
multiple-party on-line platforms.
|
(b)
|
“Prices
Based on Models and Other Valuation Methods” is in absence of pricing
information from external sources. Modeled information is derived
using
valuation models developed by the reporting entity, reflecting
when
appropriate, option pricing theory, discounted cash flow concepts,
valuation adjustments, etc. and may require projection of prices
for
underlying commodities beyond the period that prices are available
from
third-party sources. In addition, where external pricing information
or
market liquidity are limited, such valuations are classified as
modeled.
The determination of the point at which a market is no longer liquid
for
placing it in the modeled category varies by market.
|
(c)
|
There
is a mark-to-market value in excess of 10 percent of our total
mark-to-market value in individual periods beyond 2009. $290 thousand
of
this mark-to-market value is in 2010.
|
(d)
|
Amounts
exclude Cash Flow Hedges.
|
Power
|
||||
Beginning
Balance December 31, 2004
|
$
|
657
|
||
Changes
in Fair Value (a)
|
(737
|
)
|
||
Reclassifications
from AOCI to Net Income (b)
|
(277
|
)
|
||
Ending
Balance June 30, 2005
|
$
|
(357
|
)
|
(a)
|
“Changes
in Fair Value” shows changes in the fair value of derivatives designated
as cash flow hedges during the reporting period that are not yet
settled
at June 30, 2005. Amounts are reported net of related income
taxes.
|
(b)
|
“Reclassifications
from AOCI to Net Income” represents gains or losses from derivatives used
as hedging instruments in cash flow hedges that were reclassified
into net
income during the reporting period. Amounts are reported net of
related
income taxes.
|
Six
Months Ended
|
Twelve
Months Ended
|
|||||||||||||||
June
30, 2005
|
December
31, 2004
|
|||||||||||||||
(in
thousands)
|
(in
thousands)
|
|||||||||||||||
End
|
High
|
Average
|
Low
|
End
|
High
|
Average
|
Low
|
|||||||||
$74
|
$88
|
$43
|
$25
|
$157
|
$511
|
$220
|
$75
|
Three
Months Ended
|
Six
Months Ended
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
OPERATING
REVENUES
|
|||||||||||||
Electric
Generation, Transmission and Distribution
|
$
|
184,793
|
$
|
257,053
|
$
|
366,987
|
$
|
525,911
|
|||||
Sales
to AEP Affiliates
|
5,302
|
12,896
|
10,266
|
31,026
|
|||||||||
TOTAL
|
190,095
|
269,949
|
377,253
|
556,937
|
|||||||||
OPERATING
EXPENSES
|
|||||||||||||
Fuel
for Electric Generation
|
4,012
|
20,806
|
10,087
|
43,912
|
|||||||||
Fuel
from Affiliates for Electric Generation
|
21
|
59,977
|
44
|
100,176
|
|||||||||
Purchased
Electricity for Resale
|
9,996
|
16,468
|
25,366
|
26,554
|
|||||||||
Purchased
Electricity from AEP Affiliates
|
-
|
1,938
|
-
|
6,011
|
|||||||||
Other
Operation
|
67,549
|
78,066
|
133,209
|
153,507
|
|||||||||
Maintenance
|
12,433
|
23,709
|
29,472
|
39,113
|
|||||||||
Depreciation
and Amortization
|
35,434
|
28,879
|
64,720
|
57,976
|
|||||||||
Taxes
Other Than Income Taxes
|
20,923
|
23,157
|
43,454
|
45,214
|
|||||||||
Income
Taxes (Credits)
|
(1,312
|
)
|
(6,388
|
)
|
149
|
5,618
|
|||||||
TOTAL
|
149,056
|
246,612
|
306,501
|
478,081
|
|||||||||
OPERATING
INCOME
|
41,039
|
23,337
|
70,752
|
78,856
|
|||||||||
Carrying
Costs on Stranded Cost Recovery
|
19,938
|
-
|
14,797
|
-
|
|||||||||
Nonoperating
Income
|
18,260
|
12,061
|
34,556
|
24,163
|
|||||||||
Nonoperating
Expenses
|
8,987
|
2,648
|
24,124
|
7,756
|
|||||||||
Nonoperating
Income Tax Expense
|
9,240
|
880
|
6,755
|
860
|
|||||||||
Interest
Charges
|
32,642
|
32,211
|
59,721
|
65,340
|
|||||||||
NET
INCOME (LOSS)
|
28,368
|
(341
|
)
|
29,505
|
29,063
|
||||||||
Preferred
Stock Dividend Requirements
|
61
|
61
|
121
|
121
|
|||||||||
EARNINGS
(LOSS) APPLICABLE TO COMMON STOCK
|
$
|
28,307
|
$
|
(402
|
)
|
$
|
29,384
|
$
|
28,942
|
Common
Stock
|
Paid-in
Capital
|
Retained
Earnings
|
Accumulated
Other Comprehensive Income (Loss)
|
Total
|
||||||||||||
DECEMBER
31, 2003
|
$
|
55,292
|
$
|
132,606
|
$
|
1,083,023
|
$
|
(61,872
|
)
|
$
|
1,209,049
|
|||||
Common
Stock Dividends
|
(48,000
|
)
|
(48,000
|
)
|
||||||||||||
Preferred
Stock Dividends
|
(121
|
)
|
(121
|
)
|
||||||||||||
TOTAL
|
1,160,928
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net
of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $5,069
|
(9,414
|
)
|
(9,414
|
)
|
||||||||||||
Minimum
Pension Liability, Net of Tax of $0
|
(2,466
|
)
|
(2,466
|
)
|
||||||||||||
NET
INCOME
|
29,063
|
29,063
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
17,183
|
|||||||||||||||
JUNE
30, 2004
|
$
|
55,292
|
$
|
132,606
|
$
|
1,063,965
|
$
|
(73,752
|
)
|
$
|
1,178,111
|
|||||
DECEMBER
31, 2004
|
$
|
55,292
|
$
|
132,606
|
$
|
1,084,904
|
$
|
(4,159
|
)
|
$
|
1,268,643
|
|||||
Common
Stock Dividends
|
(150,000
|
)
|
(150,000
|
)
|
||||||||||||
Preferred
Stock Dividends
|
(121
|
)
|
(121
|
)
|
||||||||||||
TOTAL
|
1,118,522
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net
of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $546
|
(1,014
|
)
|
(1,014
|
)
|
||||||||||||
NET
INCOME
|
29,505
|
29,505
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
28,491
|
|||||||||||||||
JUNE
30, 2005
|
$
|
55,292
|
$
|
132,606
|
$
|
964,288
|
$
|
(5,173
|
)
|
$
|
1,147,013
|
2005
|
2004
|
||||||
ELECTRIC
UTILITY PLANT
|
|||||||
Transmission
|
$
|
809,467
|
$
|
788,371
|
|||
Distribution
|
1,452,625
|
1,433,380
|
|||||
General
|
230,953
|
220,435
|
|||||
Construction
Work in Progress
|
55,690
|
50,612
|
|||||
Total
|
2,548,735
|
2,492,798
|
|||||
Accumulated
Depreciation and Amortization
|
744,189
|
725,225
|
|||||
TOTAL
- NET
|
1,804,546
|
1,767,573
|
|||||
OTHER
PROPERTY AND INVESTMENTS
|
|||||||
Nonutility
Property, Net
|
2,273
|
1,577
|
|||||
Bond
Defeasance Funds
|
21,811
|
22,110
|
|||||
TOTAL
|
24,084
|
23,687
|
|||||
CURRENT
ASSETS
|
|||||||
Cash
and Cash Equivalents
|
2,094
|
-
|
|||||
Other
Cash Deposits
|
242,600
|
135,132
|
|||||
Accounts
Receivable:
|
|||||||
Customers
|
153,737
|
157,431
|
|||||
Affiliated
Companies
|
21,356
|
67,860
|
|||||
Accrued
Unbilled Revenues
|
26,979
|
21,589
|
|||||
Allowance
for Uncollectible Accounts
|
(994
|
)
|
(3,493
|
)
|
|||
Materials
and Supplies
|
12,861
|
12,288
|
|||||
Risk
Management Assets
|
4,017
|
14,048
|
|||||
Margin
Deposits
|
2,609
|
1,891
|
|||||
Prepayments
and Other Current Assets
|
16,042
|
9,151
|
|||||
TOTAL
|
481,301
|
415,897
|
|||||
DEFERRED
DEBITS AND OTHER ASSETS
|
|||||||
Regulatory
Assets:
|
|||||||
SFAS
109 Regulatory Asset, Net
|
18,936
|
15,236
|
|||||
Wholesale
Capacity Auction True-Up
|
585,336
|
559,973
|
|||||
Unamortized
Loss on Reacquired Debt
|
11,311
|
11,842
|
|||||
Designated
for Securitization
|
1,347,502
|
1,361,299
|
|||||
Deferred
Debt - Restructuring
|
11,139
|
11,596
|
|||||
Other
|
90,302
|
102,032
|
|||||
Securitized
Transition Assets
|
622,137
|
642,384
|
|||||
Long-term
Risk Management Assets
|
4,983
|
9,508
|
|||||
Prepaid
Pension Obligations
|
110,210
|
109,628
|
|||||
Deferred
Property Taxes
|
15,450
|
-
|
|||||
Deferred
Charges
|
34,660
|
36,986
|
|||||
TOTAL
|
2,851,966
|
2,860,484
|
|||||
Assets
Held for Sale - Texas Generation Plants
|
45,611
|
628,149
|
|||||
TOTAL
ASSETS
|
$
|
5,207,508
|
$
|
5,695,790
|
2005
|
2004
|
||||||
CAPITALIZATION
|
(in
thousands)
|
||||||
Common
Shareholder’s Equity:
|
|||||||
Common
Stock - $25 par value per share:
|
|||||||
Authorized
- 12,000,000 shares
|
|||||||
Outstanding
- 2,211,678 shares
|
$
|
55,292
|
$
|
55,292
|
|||
Paid-in
Capital
|
132,606
|
132,606
|
|||||
Retained
Earnings
|
964,288
|
1,084,904
|
|||||
Accumulated
Other Comprehensive Income (Loss)
|
(5,173
|
)
|
(4,159
|
)
|
|||
Total
Common Shareholder’s Equity
|
1,147,013
|
1,268,643
|
|||||
Cumulative
Preferred Stock Not Subject to Mandatory Redemption
|
5,940
|
5,940
|
|||||
Total
Shareholders’ Equity
|
1,152,953
|
1,274,583
|
|||||
Long-term
Debt - Nonaffiliated
|
1,672,748
|
1,541,552
|
|||||
TOTAL
|
2,825,701
|
2,816,135
|
|||||
CURRENT
LIABILITIES
|
|||||||
Long-term
Debt Due Within One Year - Nonaffiliated
|
237,262
|
365,742
|
|||||
Advances
from Affiliates
|
120,064
|
207
|
|||||
Accounts
Payable:
|
|||||||
General
|
51,779
|
109,688
|
|||||
Affiliated
Companies
|
37,004
|
64,045
|
|||||
Customer
Deposits
|
5,414
|
6,147
|
|||||
Taxes
Accrued
|
113,542
|
184,014
|
|||||
Interest
Accrued
|
38,672
|
41,227
|
|||||
Risk
Management Liabilities
|
4,272
|
8,394
|
|||||
Obligations
Under Capital Leases
|
423
|
412
|
|||||
Other
|
22,514
|
20,115
|
|||||
TOTAL
|
630,946
|
799,991
|
|||||
DEFERRED
CREDITS AND OTHER LIABILITIES
|
|||||||
Deferred
Income Taxes
|
1,177,334
|
1,247,111
|
|||||
Long-term
Risk Management Liabilities
|
2,670
|
4,896
|
|||||
Regulatory
Liabilities:
|
|||||||
Asset
Removal Costs
|
104,214
|
102,624
|
|||||
Deferred
Investment Tax Credits
|
105,871
|
107,743
|
|||||
Over-recovery
of Fuel Costs
|
209,126
|
211,526
|
|||||
Retail
Clawback
|
61,384
|
61,384
|
|||||
Other
|
77,166
|
76,653
|
|||||
Obligations
Under Capital Leases
|
496
|
468
|
|||||
Deferred
Credits and Other
|
11,651
|
17,276
|
|||||
TOTAL
|
1,749,912
|
1,829,681
|
|||||
Liabilities
Held for Sale - Texas Generation Plants
|
949
|
249,983
|
|||||
Commitments
and Contingencies (Note 5)
|
|||||||
TOTAL
CAPITALIZATION AND LIABILITIES
|
$
|
5,207,508
|
$
|
5,695,790
|
2005
|
2004
|
||||||
OPERATING
ACTIVITIES
|
|||||||
Net
Income
|
$
|
29,505
|
$
|
29,063
|
|||
Adjustments
to Reconcile Net Income to Net Cash Flows From
Operating Activities:
|
|||||||
Depreciation
and Amortization
|
64,720
|
57,976
|
|||||
Accretion
Expense
|
7,549
|
8,209
|
|||||
Deferred
Income Taxes
|
(83,369
|
)
|
(11,682
|
)
|
|||
Deferred
Investment Tax Credits
|
(1,872
|
)
|
(2,603
|
)
|
|||
Deferred
Property Taxes
|
(15,450
|
)
|
(22,440
|
)
|
|||
Pension
and Postemployment Benefit Reserves
|
(1,516
|
)
|
481
|
||||
Mark-to-Market
of Risk Management Contracts
|
7,085
|
4,593
|
|||||
Pension
Contributions
|
(113
|
)
|
(675
|
)
|
|||
Carrying
Costs
|
(14,797
|
)
|
-
|
||||
Wholesale
Capacity Auction True-up
|
769
|
-
|
|||||
Over/Under
Fuel Recovery
|
(2,400
|
)
|
60,000
|
||||
(Gain)/Loss
on Sale of Assets
|
16
|
(312
|
)
|
||||
Change
in Other Noncurrent Assets
|
(6,169
|
)
|
2,905
|
||||
Change
in Other Noncurrent Liabilities
|
3,176
|
(27,166
|
)
|
||||
Changes
in Components of Working Capital:
|
|||||||
Accounts
Receivable, Net
|
46,481
|
(26,582
|
)
|
||||
Fuel,
Materials and Supplies
|
(969
|
)
|
(3,735
|
)
|
|||
Accounts
Payable
|
(62,628
|
)
|
18,804
|
||||
Taxes
Accrued
|
(69,046
|
)
|
31,378
|
||||
Customer
Deposits
|
(733
|
)
|
4,361
|
||||
Interest
Accrued
|
(2,555
|
)
|
(756
|
)
|
|||
Other
Current Assets
|
(9,285
|
)
|
(371
|
)
|
|||
Other
Current Liabilities
|
1,822
|
(3,173
|
)
|
||||
Net
Cash Flows From (Used For) Operating Activities
|
(109,779
|
)
|
118,275
|
||||
INVESTING
ACTIVITIES
|
|||||||
Construction
Expenditures
|
(61,408
|
)
|
(49,339
|
)
|
|||
Proceeds
From Sale of Assets
|
313,709
|
1,477
|
|||||
Change
in Other Cash Deposits, Net
|
(107,468
|
)
|
(93,607
|
)
|
|||
Change
in Bond Defeasance Funds and Other
|
-
|
(21,670
|
)
|
||||
Net
Cash Flows From (Used For) Investing Activities
|
144,833
|
(163,139
|
)
|
||||
FINANCING
ACTIVITIES
|
|||||||
Issuance
of Long-term Debt
|
276,690
|
-
|
|||||
Retirement
of Long-term Debt
|
(279,386
|
)
|
(35,004
|
)
|
|||
Changes
in Advances to/from Affiliates, Net
|
119,857
|
133,039
|
|||||
Dividends
Paid on Common Stock
|
(150,000
|
)
|
(48,000
|
)
|
|||
Dividends
Paid on Cumulative Preferred Stock
|
(121
|
)
|
(121
|
)
|
|||
Net
Cash Flows From (Used For) Financing Activities
|
(32,960
|
)
|
49,914
|
||||
Net
Increase in Cash and Cash Equivalents
|
2,094
|
5,050
|
|||||
Cash
and Cash Equivalents at Beginning of Period
|
-
|
760
|
|||||
Cash
and Cash Equivalents at End of Period
|
$
|
2,094
|
$
|
5,810
|
SUPPLEMENTAL
DISCLOSURE:
|
Cash
paid (received) for interest net of capitalized amounts was $52,441,000
and $61,529,000 and for income taxes was $161,372,000 and $(7,067,000)
in
2005 and 2004, respectively. Noncash capital lease acquisitions
were
$261,000 and $218,000 in 2005 and 2004, respectively. Construction
Expenditures include the change in construction-related Accounts
Payable
of $1,697,000 and $(423,000) in 2005 and 2004,
respectively.
|
Footnote
Reference
|
|
Significant
Accounting Matters
|
Note
1
|
New
Accounting Pronouncements
|
Note
2
|
Rate
Matters
|
Note
3
|
Customer
Choice and Industry Restructuring
|
Note
4
|
Commitments
and Contingencies
|
Note
5
|
Guarantees
|
Note
6
|
Acquisitions,
Dispositions and Assets Held for Sale
|
Note
7
|
Benefit
Plans
|
Note
8
|
Business
Segments
|
Note
9
|
Income
Taxes
|
Note
10
|
Financing
Activities
|
Note
11
|
Company-wide
Staffing and Budget Review
|
Note
12
|
Second
Quarter of 2004 Net Income
|
$
|
8
|
|||||
Changes
in Gross Margin:
|
|||||||
Texas
Supply
|
4
|
||||||
Wires
Revenue
|
3
|
||||||
Off-system
Sales
|
(2
|
)
|
|||||
Transmission
Revenue
|
1
|
||||||
Total
Change in Gross Margin
|
6
|
||||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
(1
|
)
|
|||||
Total
Change in Operating Expenses and Other:
|
(1
|
)
|
|||||
Income
Tax Expense
|
(1
|
)
|
|||||
Second
Quarter of 2005 Net Income
|
$
|
12
|
·
|
Texas
Supply margins increased by $4 million primarily
due to a $3 million increase in capacity sales, offset by lower
sales
volumes of 18% due to the loss of Centrica, our largest REP customer.
Also, provision for rate refunds decreased $13 million due to
the 2004
final fuel reconciliation true-up, offset by a decrease of $13
million in
the net fuel revenue/fuel expense.
|
·
|
Wires
Revenue increased by $3 million primarily due to an increase
in delivery
volumes of 10%.
|
·
|
Margins
from Off-system Sales decreased by $2 million primarily due to
lower
optimization activity.
|
·
|
Transmission
Revenue increased $1 million primarily due to Texas transmission
rate
increases.
|
·
|
Other
Operation and Maintenance expenses increased $1 million primarily
related
to field data collection for tracking system upgrades, 2005 staffing
and
budget review severance and disposal of fuel oil inventory, reduced
in
part by lower power plant maintenance on Reliability Must Run
(RMR) plants
no longer in service.
|
Six
Months Ended June 30, 2004 Net Income
|
$
|
21
|
|||||
Changes
in Gross Margin:
|
|||||||
Wires
Revenue
|
2
|
||||||
Off-system
Sales
|
(3
|
)
|
|||||
Transmission
Revenue
|
2
|
||||||
Other
Revenue
|
(4
|
)
|
|||||
Total
Change in Gross Margin
|
(3
|
)
|
|||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
1
|
||||||
Depreciation
and Amortization
|
(1
|
)
|
|||||
Taxes
Other Than Income Taxes
|
(1
|
)
|
|||||
Nonoperating
Income and Expenses, Net
|
(3
|
)
|
|||||
Interest
Charges
|
2
|
||||||
Total
Change in Operating Expenses and Other:
|
(2
|
)
|
|||||
Income
Tax Expense
|
3
|
||||||
Six
Months ended June 30, 2005 Net Income
|
$
|
19
|
·
|
Wires
Revenue increased by $2 million primarily
due to higher delivery volumes of 5%.
|
·
|
Margins
from Off-system Sales for 2005 decreased by $3 million primarily
due to
lower optimization activity.
|
·
|
Transmission
Revenue increased $2 million due primarily to Texas transmission
rate
increases.
|
·
|
Other
Revenue decreased $4 million primarily due to a prior year favorable
adjustment for affiliated OATT and ancillary services resulting
from
revised ERCOT data received for the years 2001 through
2003.
|
·
|
Other
Operation and Maintenance expenses decreased $1 million primarily
due to
decreased maintenance for RMR plants no longer in
service.
|
·
|
Nonoperating
Income and Expenses, Net increased $3 million primarily due to
$5 million
of income in 2004 relating to risk management contracts which
expired in
December 2004 offset by increased net revenue of $2 million from
third
party nonutility construction projects.
|
·
|
Interest
Charges decreased $2 million primarily due to long-term debt
maturities in
2004 and interest in 2004 related to the FERC settlement with
wholesale
customers.
|
Moody’s
|
S&P
|
Fitch
|
|||
First
Mortgage Bonds
|
A3
|
BBB
|
A
|
||
Senior
Unsecured Debt
|
Baa1
|
BBB
|
A-
|
Total
MTM Risk Management Contract Net Assets at December 31,
2004
|
$
|
4,192
|
||
(Gain)
Loss from Contracts Realized/Settled During the Period (a)
|
(1,608
|
)
|
||
Fair
Value of New Contracts When Entered During the Period (b)
|
32
|
|||
Net
Option Premiums Paid/(Received) (c)
|
(5
|
)
|
||
Change
in Fair Value Due to Valuation Methodology Changes
|
-
|
|||
Changes
in Fair Value of Risk Management Contracts (d)
|
(1,481
|
)
|
||
Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions (e)
|
-
|
|||
Total
MTM Risk Management Contract Net Assets
|
1,130
|
|||
Net
Cash Flow Hedge Contracts (f)
|
(241
|
)
|
||
Total
MTM Risk Management Contract Net Assets at June 30, 2005
|
$
|
889
|
(a)
|
“(Gain)
Loss from Contracts Realized/Settled During the Period” includes realized
risk management contracts and related derivatives that settled
during 2005
where we entered into the contract prior to 2005.
|
(b)
|
“Fair
Value of New Contracts When Entered During the Period” represents the fair
value at inception of long-term contracts entered into with customers
during 2005. Most of the fair value comes from longer term fixed
price
contracts with customers that seek to limit their risk against
fluctuating
energy prices. Inception value is only recorded if observable
market data
can be obtained for valuation inputs for the entire contract
term. The
contract prices are valued against market curves associated with
the
delivery location and delivery term.
|
(c)
|
“Net
Option Premiums Paid/(Received)” reflects the net option premiums
paid/(received) as they relate to unexercised and unexpired option
contracts that were entered in 2005.
|
(d)
|
“Changes
in Fair Value of Risk Management Contracts” represents the fair value
change in the risk management portfolio due to market fluctuations
during
the current period. Market fluctuations are attributable to various
factors such as supply/demand, weather, etc.
|
(e)
|
“Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions” relates to the net gains (losses) of those contracts that
are not reflected in the Condensed Statements of Income. These
net gains
(losses) are recorded as regulatory assets/liabilities for those
subsidiaries that operate in regulated jurisdictions.
|
(f)
|
“Net
Cash Flow Hedge Contracts” (pretax) are discussed below in Accumulated
Other Comprehensive Income (Loss).
|
MTM
Risk Management Contracts (a)
|
Cash
Flow Hedges
|
Total
(b)
|
||||||||
Current
Assets
|
$
|
1,727
|
$
|
9
|
$
|
1,736
|
||||
Noncurrent
Assets
|
2,151
|
3
|
2,154
|
|||||||
Total
MTM Derivative Contract Assets
|
3,878
|
12
|
3,890
|
|||||||
Current
Liabilities
|
(1,616
|
)
|
(231
|
)
|
(1,847
|
)
|
||||
Noncurrent
Liabilities
|
(1,132
|
)
|
(22
|
)
|
(1,154
|
)
|
||||
Total
MTM Derivative Contract Liabilities
|
(2,748
|
)
|
(253
|
)
|
(3,001
|
)
|
||||
Total
MTM Derivative Contract Net Assets (Liabilities)
|
$
|
1,130
|
$
|
(241
|
)
|
$
|
889
|
(a)
|
Does
not include Cash Flow Hedges.
|
(b)
|
Represents
amount of total MTM derivative contracts recorded within Risk
Management
Assets, Long-term Risk Management Assets, Risk Management Liabilities
and
Long-term Risk Management Liabilities on our Condensed Balance
Sheets.
|
·
|
The
source of fair value used in determining the carrying amount
of our total
MTM asset or liability (external sources or modeled
internally).
|
·
|
The
maturity, by year, of our net assets/liabilities, giving an indication
of
when these MTM amounts will settle and generate
cash.
|
Remainder
of 2005
|
2006
|
2007
|
2008
|
2009
|
After
2009
(c)
|
Total
(d)
|
||||||||||||||||
Prices
Actively Quoted - Exchange Traded
Contracts
|
$
|
(288
|
)
|
$
|
(2
|
)
|
$
|
229
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
(61
|
)
|
|||||
Prices
Provided by Other External Sources
- OTC Broker Quotes (a)
|
617
|
782
|
258
|
280
|
-
|
-
|
1,937
|
|||||||||||||||
Prices
Based on Models and Other Valuation
Methods (b)
|
(316
|
)
|
(558
|
)
|
(232
|
)
|
(25
|
)
|
176
|
209
|
(746
|
)
|
||||||||||
Total
|
$
|
13
|
$
|
222
|
$
|
255
|
$
|
255
|
$
|
176
|
$
|
209
|
$
|
1,130
|
(a)
|
“Prices
Provided by Other External Sources - OTC Broker Quotes” reflects
information obtained from over-the-counter brokers, industry
services, or
multiple-party on-line platforms.
|
(b)
|
“Prices
Based on Models and Other Valuation Methods” is in absence of pricing
information from external sources. Modeled information is derived
using
valuation models developed by the reporting entity, reflecting
when
appropriate, option pricing theory, discounted cash flow concepts,
valuation adjustments, etc. and may require projection of prices
for
underlying commodities beyond the period that prices are available
from
third-party sources. In addition, where external pricing information
or
market liquidity are limited, such valuations are classified
as modeled.
The determination of the point at which a market is no longer
liquid for
placing it in the modeled category varies by market.
|
(c)
|
There
is mark-to-market value in excess of 10 percent of our total
mark-to-market value in individual periods beyond 2009. $125
thousand of
this mark-to-market value is in 2010.
|
(d)
|
Amounts
exclude Cash Flow Hedges.
|
Power
|
||||
Beginning
Balance December 31, 2004
|
$
|
285
|
||
Changes
in Fair Value (a)
|
(319
|
)
|
||
Reclassifications
from AOCI to Net Income (b)
|
(120
|
)
|
||
Ending
Balance June 30, 2005
|
$
|
(154
|
)
|
(a)
|
“Changes
in Fair Value” shows changes in the fair value of derivatives designated
as cash flow hedges during the reporting period that are not
yet settled
at June 30, 2005. Amounts are reported net of related income
taxes.
|
(b)
|
“Reclassifications
from AOCI to Net Income” represents gains or losses from derivatives used
as hedging instruments in cash flow hedges that were reclassified
into net
income during the reporting period. Amounts are reported net
of related
income taxes.
|
Six
Months Ended
|
Twelve
Months Ended
|
|||||||||||||||
June
30, 2005
|
December
31, 2004
|
|||||||||||||||
(in
thousands)
|
(in
thousands)
|
|||||||||||||||
End
|
High
|
Average
|
Low
|
End
|
High
|
Average
|
Low
|
|||||||||
$32
|
$38
|
$19
|
$11
|
$68
|
$221
|
$95
|
$33
|
Three
Months Ended
|
Six
Months Ended
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
OPERATING
REVENUES
|
|||||||||||||
Electric
Generation, Transmission and Distribution
|
$
|
97,330
|
$
|
90,330
|
$
|
169,273
|
$
|
179,042
|
|||||
Sales
to AEP Affiliates
|
12,880
|
12,027
|
24,170
|
26,745
|
|||||||||
TOTAL
|
110,210
|
102,357
|
193,443
|
205,787
|
|||||||||
OPERATING
EXPENSES
|
|||||||||||||
Fuel
for Electric Generation
|
11,355
|
10,661
|
23,966
|
18,161
|
|||||||||
Fuel
from Affiliates for Electric Generation
|
-
|
12,542
|
372
|
23,766
|
|||||||||
Purchased
Electricity for Resale
|
37,604
|
23,282
|
53,942
|
41,305
|
|||||||||
Purchased
Electricity from AEP Affiliates
|
-
|
544
|
22
|
4,076
|
|||||||||
Other
Operation
|
22,404
|
20,918
|
40,965
|
41,299
|
|||||||||
Maintenance
|
4,920
|
5,950
|
9,139
|
10,633
|
|||||||||
Depreciation
and Amortization
|
10,362
|
9,854
|
20,517
|
19,546
|
|||||||||
Taxes
Other Than Income Taxes
|
5,713
|
5,293
|
11,418
|
10,397
|
|||||||||
Income
Taxes
|
3,093
|
2,541
|
6,679
|
8,482
|
|||||||||
TOTAL
|
95,451
|
91,585
|
167,020
|
177,665
|
|||||||||
OPERATING
INCOME
|
14,759
|
10,772
|
26,423
|
28,122
|
|||||||||
Nonoperating
Income
|
5,213
|
15,632
|
41,215
|
29,388
|
|||||||||
Nonoperating
Expenses
|
2,205
|
11,962
|
37,313
|
22,898
|
|||||||||
Nonoperating
Income Tax Expense
|
894
|
1,209
|
1,074
|
2,103
|
|||||||||
Interest
Charges
|
4,869
|
5,482
|
9,853
|
11,662
|
|||||||||
NET
INCOME
|
12,004
|
7,751
|
19,398
|
20,847
|
|||||||||
Preferred
Stock Dividend Requirements
|
26
|
26
|
52
|
52
|
|||||||||
EARNINGS
APPLICABLE TO COMMON STOCK
|
$
|
11,978
|
$
|
7,725
|
$
|
19,346
|
$
|
20,795
|
Common
Stock
|
Paid-in
Capital
|
Retained
Earnings
|
Accumulated
Other Comprehensive Income (Loss)
|
Total
|
||||||||||||
DECEMBER
31, 2003
|
$
|
137,214
|
$
|
2,351
|
$
|
125,428
|
$
|
(26,718
|
)
|
$
|
238,275
|
|||||
Common
Stock Dividends
|
(2,000
|
)
|
(2,000
|
)
|
||||||||||||
Preferred
Stock Dividends
|
(52
|
)
|
(52
|
)
|
||||||||||||
TOTAL
|
236,223
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $1,704
|
(3,164
|
)
|
(3,164
|
)
|
||||||||||||
NET
INCOME
|
20,847
|
20,847
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
17,683
|
|||||||||||||||
JUNE
30, 2004
|
$
|
137,214
|
$
|
2,351
|
$
|
144,223
|
$
|
(29,882
|
)
|
$
|
253,906
|
|||||
DECEMBER
31, 2004
|
$
|
137,214
|
$
|
2,351
|
$
|
170,984
|
$
|
(128
|
)
|
$
|
310,421
|
|||||
Common
Stock Dividends
|
(12,626
|
)
|
(12,626
|
)
|
||||||||||||
Preferred
Stock Dividends
|
(52
|
)
|
(52
|
)
|
||||||||||||
TOTAL
|
297,743
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $236
|
(439
|
)
|
(439
|
)
|
||||||||||||
NET
INCOME
|
19,398
|
19,398
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
18,959
|
|||||||||||||||
JUNE
30, 2005
|
$
|
137,214
|
$
|
2,351
|
$
|
177,704
|
$
|
(567
|
)
|
$
|
316,702
|
2005
|
2004
|
||||||
ELECTRIC
UTILITY PLANT
|
|||||||
Production
|
$
|
288,325
|
$
|
287,212
|
|||
Transmission
|
283,435
|
281,359
|
|||||
Distribution
|
483,763
|
474,961
|
|||||
General
|
115,911
|
115,174
|
|||||
Construction
Work in Progress
|
26,581
|
23,621
|
|||||
Total
|
1,198,015
|
1,182,327
|
|||||
Accumulated
Depreciation and Amortization
|
414,781
|
405,933
|
|||||
TOTAL
- NET
|
783,234
|
776,394
|
|||||
OTHER
PROPERTY AND INVESTMENTS
|
|||||||
Nonutility
Property, Net
|
1,181
|
1,407
|
|||||
CURRENT
ASSETS
|
|||||||
Cash
and Cash Equivalents
|
938
|
-
|
|||||
Other
Cash Deposits
|
2,308
|
2,308
|
|||||
Advances
to Affiliates
|
63,665
|
51,504
|
|||||
Accounts
Receivable:
|
|||||||
Customers
|
82,753
|
90,109
|
|||||
Affiliated
Companies
|
14,591
|
21,474
|
|||||
Accrued
Unbilled Revenues
|
4,816
|
3,789
|
|||||
Allowance
for Uncollectible Accounts
|
(609
|
)
|
(787
|
)
|
|||
Unbilled
Construction Costs
|
6,320
|
22,065
|
|||||
Fuel
Inventory
|
5,572
|
3,148
|
|||||
Materials
and Supplies
|
8,344
|
8,273
|
|||||
Risk
Management Assets
|
1,736
|
6,071
|
|||||
Margin
Deposits
|
2,603
|
818
|
|||||
Prepayments
and Other
|
917
|
1,053
|
|||||
TOTAL
|
193,954
|
209,825
|
|||||
DEFERRED
DEBITS AND OTHER ASSETS
|
|||||||
Regulatory
Assets:
|
|||||||
Deferred
Debt - Restructuring
|
5,849
|
6,093
|
|||||
Unamortized
Loss on Reacquired Debt
|
1,464
|
2,147
|
|||||
Other
|
3,484
|
3,783
|
|||||
Long-term
Risk Management Assets
|
2,154
|
4,110
|
|||||
Prepaid
Pension Obligations
|
44,909
|
44,911
|
|||||
Deferred
Property Taxes
|
8,145
|
-
|
|||||
Other
Deferred Charges
|
2,411
|
2,859
|
|||||
TOTAL
|
68,416
|
63,903
|
|||||
TOTAL
ASSETS
|
$
|
1,046,785
|
$
|
1,051,529
|
2005
|
2004
|
||||||
CAPITALIZATION
|
(in
thousands)
|
||||||
Common
Shareholder’s Equity:
|
|||||||
Common
Stock - $25 par value per share:
|
|||||||
Authorized
- 7,800,000 shares
|
|||||||
Outstanding
- 5,488,560 shares
|
$
|
137,214
|
$
|
137,214
|
|||
Paid-in
Capital
|
2,351
|
2,351
|
|||||
Retained
Earnings
|
177,704
|
170,984
|
|||||
Accumulated
Other Comprehensive Income (Loss)
|
(567
|
)
|
(128
|
)
|
|||
Total
Common Shareholder’s Equity
|
316,702
|
310,421
|
|||||
Cumulative
Preferred Stock Not Subject to Mandatory Redemption
|
2,357
|
2,357
|
|||||
Total
Shareholders’ Equity
|
319,059
|
312,778
|
|||||
Long-term
Debt - Nonaffiliated
|
276,797
|
276,748
|
|||||
TOTAL
|
595,856
|
589,526
|
|||||
CURRENT
LIABILITIES
|
|||||||
Long-term
Debt Due Within One Year - Nonaffiliated
|
37,609
|
37,609
|
|||||
Accounts
Payable:
|
|||||||
General
|
42,876
|
22,444
|
|||||
Affiliated
Companies
|
36,587
|
52,801
|
|||||
Customer
Deposits
|
632
|
1,020
|
|||||
Taxes
Accrued
|
25,422
|
37,269
|
|||||
Interest
Accrued
|
5,045
|
5,044
|
|||||
Risk
Management Liabilities
|
1,847
|
3,628
|
|||||
Obligations
Under Capital Leases
|
212
|
220
|
|||||
Other
|
8,925
|
9,628
|
|||||
TOTAL
|
159,155
|
169,663
|
|||||
DEFERRED
CREDITS AND OTHER LIABILITIES
|
|||||||
Deferred
Income Taxes
|
140,138
|
138,465
|
|||||
Long-term
Risk Management Liabilities
|
1,154
|
2,116
|
|||||
Regulatory
Liabilities:
|
|||||||
Asset
Removal Costs
|
82,838
|
81,143
|
|||||
Deferred
Investment Tax Credits
|
18,062
|
18,698
|
|||||
Over-recovery
of Fuel Costs
|
4,716
|
3,920
|
|||||
Retail
Clawback
|
13,924
|
13,924
|
|||||
Excess
Earnings
|
13,022
|
13,270
|
|||||
SFAS
109 Regulatory Liability, Net
|
7,243
|
8,500
|
|||||
Other
|
1,059
|
1,319
|
|||||
Obligations
Under Capital Leases
|
372
|
314
|
|||||
Deferred
Credits and Other
|
9,246
|
10,671
|
|||||
TOTAL
|
291,774
|
292,340
|
|||||
Commitments
and Contingencies (Note 5)
|
|||||||
TOTAL
CAPITALIZATION AND LIABILITIES
|
$
|
1,046,785
|
$
|
1,051,529
|
2005
|
2004
|
||||||
OPERATING
ACTIVITIES
|
|||||||
Net
Income
|
$
|
19,398
|
$
|
20,847
|
|||
Adjustments
to Reconcile Net Income to Net Cash Flows From
Operating Activities:
|
|||||||
Depreciation
and Amortization
|
20,517
|
19,546
|
|||||
Deferred
Income Taxes
|
(1,742
|
)
|
(2,767
|
)
|
|||
Deferred
Investment Tax Credits
|
(636
|
)
|
(656
|
)
|
|||
Deferred
Property Taxes
|
(8,145
|
)
|
(7,400
|
)
|
|||
Mark-to-Market
of Risk Management Contracts
|
3,062
|
1,955
|
|||||
Over/Under
Fuel Recovery
|
796
|
13,500
|
|||||
Change
in Other Noncurrent Assets
|
(2,432
|
)
|
(6,449
|
)
|
|||
Change
in Other Noncurrent Liabilities
|
1,924
|
3,289
|
|||||
Changes
in Components of Working Capital:
|
|||||||
Accounts
Receivable, Net
|
13,034
|
281
|
|||||
Fuel,
Materials and Supplies
|
(2,495
|
)
|
2,326
|
||||
Accounts
Payable
|
3,672
|
(2,590
|
)
|
||||
Taxes
Accrued
|
(11,847
|
)
|
14,527
|
||||
Customer
Deposits
|
(388
|
)
|
837
|
||||
Other
Current Assets
|
15,059
|
(3,047
|
)
|
||||
Other
Current Liabilities
|
(710
|
)
|
(2,783
|
)
|
|||
Net
Cash Flows From Operating Activities
|
49,067
|
51,416
|
|||||
INVESTING
ACTIVITIES
|
|||||||
Construction
Expenditures
|
(24,323
|
)
|
(18,117
|
)
|
|||
Change
in Other Cash Deposits, Net
|
-
|
564
|
|||||
Proceeds
from Sale of Assets
|
1,033
|
-
|
|||||
Net
Cash Flows Used For Investing Activities
|
(23,290
|
)
|
(17,553
|
)
|
|||
FINANCING
ACTIVITIES
|
|||||||
Retirement
of Long-term Debt
|
-
|
(24,036
|
)
|
||||
Changes
in Advances to/from Affiliates, Net
|
(12,161
|
)
|
(6,391
|
)
|
|||
Dividends
Paid on Common Stock
|
(12,626
|
)
|
(2,000
|
)
|
|||
Dividends
Paid on Cumulative Preferred Stock
|
(52
|
)
|
(52
|
)
|
|||
Net
Cash Flows Used For Financing Activities
|
(24,839
|
)
|
(32,479
|
)
|
|||
Net
Increase in Cash and Cash Equivalents
|
938
|
1,384
|
|||||
Cash
and Cash Equivalents at Beginning of Period
|
-
|
2
|
|||||
Cash
and Cash Equivalents at End of Period
|
$
|
938
|
$
|
1,386
|
SUPPLEMENTAL
DISCLOSURE:
|
|||
Cash
paid (received) for interest net of capitalized amounts was $9,014,000
and
$11,139,000 and for income taxes was $21,865,000 and $(412,000)
in 2005
and 2004, respectively. Noncash capital lease acquisitions in
2005 and
2004 were $171,000 and $122,000, respectively. Construction Expenditures
include the change in construction-related Accounts Payable of
$546,000
and $(285,000) in 2005 and 2004,
respectively.
|
Footnote
Reference
|
|
Significant
Accounting Matters
|
Note
1
|
New
Accounting Pronouncements
|
Note
2
|
Rate
Matters
|
Note
3
|
Customer
Choice and Industry Restructuring
|
Note
4
|
Commitments
and Contingencies
|
Note
5
|
Guarantees
|
Note
6
|
Benefit
Plans
|
Note
8
|
Business
Segments
|
Note
9
|
Financing
Activities
|
Note
11
|
Company-wide
Staffing and Budget Review
|
Note
12
|
Second
Quarter of 2004 Net Income
|
$
|
22
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins
|
(32
|
)
|
|||||
Off-system
Sales
|
12
|
||||||
Transmission
Revenues
|
(5
|
)
|
|||||
Other
Revenues
|
2
|
||||||
Total
Change in Gross Margin
|
(23
|
)
|
|||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
10
|
||||||
Depreciation
and Amortization
|
1
|
||||||
Nonoperating
Income and Expenses, Net
|
6
|
||||||
Interest
Charges
|
(1
|
)
|
|||||
Total
Change in Operating Expenses and Other
|
16
|
||||||
Income
Tax Expense
|
9
|
||||||
Second
Quarter of 2005 Net Income
|
$
|
24
|
·
|
Retail
Margins decreased by $32 million in comparison to 2004 primarily
due to our higher MLR share caused by the increase in our peak
demand that
was established in December 2004 resulting in a $19 million increase
in
capacity settlement payments under the Interconnection Agreement.
In
addition, there was a $9 million decrease in fuel margins resulting
from
higher fuel costs.
|
·
|
Margins
from Off-system Sales for 2005 increased by $12 million in comparison
to
2004 primarily due to higher physical sales caused by our new
peak demand
as well as higher optimization activity.
|
·
|
Transmission
Revenues decreased $5 million primarily due to the elimination
of $11
million of revenues related to through and out rates partially
offset by
an increase of $6 million in revenues due to replacement SECA
rates. See
“FERC Order on Regional Through and Out Rates” for additional discussion
of these FERC rate changes.
|
·
|
Other
Operation and Maintenance expenses decreased $10 million primarily
due to
a decrease in storm restoration and a reduction in planned maintenance
in
comparison to 2004 at Amos, Clinch River and Glen Lyn plants
partially
offset by an increase in PJM scheduling fees and an increase
in
transmission expenses related to the AEP Transmission Equalization
Agreement.
|
·
|
Nonoperating
Income and Expenses, Net increased $6 million primarily due to
the accrual
of carrying costs on deferred Virginia environmental and reliability
charges.
|
Six
Months Ended June 30, 2004 Net Income
|
$
|
87
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins
|
(65
|
)
|
|||||
Off-system
Sales
|
31
|
||||||
Transmission
Revenues
|
(13
|
)
|
|||||
Other
Revenues
|
3
|
||||||
Total
Change in Gross Margin
|
(44
|
)
|
|||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
2
|
||||||
Depreciation
and Amortization
|
(1
|
)
|
|||||
Nonoperating
Income and Expenses, Net
|
2
|
||||||
Total
Change in Operating Expenses and Other
|
3
|
||||||
Income
Tax Expense
|
25
|
||||||
Six
Months Ended June 30, 2005 Net Income
|
$
|
71
|
·
|
Retail
Margins decreased by $65 million in comparison to 2004 primarily
due to our higher MLR share caused by the increase in our peak
demand that
was established in December 2004 resulting in a $34 million increase
in
capacity settlement payments under the Interconnection Agreement.
In
addition, there was a $26 million decrease in fuel margins resulting
from
higher fuel costs.
|
·
|
Margins
from Off-system Sales for 2005 increased by $31 million in comparison
to
2004 primarily due to higher physical sales caused by our new
peak demand
as well as higher optimization activity.
|
·
|
Transmission
Revenues decreased $13 million primarily due to the elimination
of $23
million of revenues related to through and out rates partially
offset by
an increase of $10 million due to replacement SECA rates.
|
Moody’s
|
S&P
|
Fitch
|
|||
First
Mortgage Bonds
|
Baa1
|
BBB
|
A-
|
||
Senior
Unsecured Debt
|
Baa2
|
BBB
|
BBB+
|
2005
|
2004
|
||||||
(in
thousands)
|
|||||||
Cash
and Cash Equivalents at Beginning of Period
|
$
|
536
|
$
|
4,561
|
|||
Cash
Flows From (Used For):
|
|||||||
Operating
Activities
|
75,113
|
229,420
|
|||||
Investing
Activities
|
(259,312
|
)
|
(163,509
|
)
|
|||
Financing
Activities
|
184,944
|
(66,841
|
)
|
||||
Net
Increase (Decrease) in Cash and Cash Equivalents
|
745
|
(930
|
)
|
||||
Cash
and Cash Equivalents at End of Period
|
$
|
1,281
|
$
|
3,631
|
Principal
|
Interest
|
Due
|
||||||||
Type
of Debt
|
Amount
|
Rate
|
Date
|
|||||||
(in
thousands)
|
(%)
|
|||||||||
Senior
Unsecured Notes
|
$
|
250,000
|
5.00
|
2017
|
||||||
Senior
Unsecured Notes
|
200,000
|
4.95
|
2015
|
|||||||
Senior
Unsecured Notes
|
150,000
|
4.40
|
2010
|
|||||||
Notes
Payable - Affiliated
|
100,000
|
4.708
|
2010
|
Principal
|
Interest
|
Due
|
||||||||
Type
of Debt
|
Amount
|
Rate
|
Date
|
|||||||
(in
thousands)
|
(%)
|
|||||||||
Senior
Unsecured Notes
|
$
|
450,000
|
4.80
|
2005
|
||||||
First
Mortgage Bonds
|
50,000
|
8.00
|
2005
|
|||||||
First
Mortgage Bonds
|
45,000
|
8.00
|
2025
|
|||||||
First
Mortgage Bonds
|
30,000
|
6.89
|
2005
|
Total
MTM Risk Management Contract Net Assets at December 31,
2004
|
$
|
54,124
|
||
(Gain)
Loss from Contracts Realized/Settled During the Period (a)
|
(10,478
|
)
|
||
Fair
Value of New Contracts When Entered During the Period (b)
|
682
|
|||
Net
Option Premiums Paid/(Received) (c)
|
(294
|
)
|
||
Change
in Fair Value Due to Valuation Methodology Changes
|
-
|
|||
Changes
in Fair Value of Risk Management Contracts (d)
|
15,177
|
|||
Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions (e)
|
3,593
|
|||
Total
MTM Risk Management Contract Net Assets
|
62,804
|
|||
Net
Cash Flow and
Fair Value Hedge
Contracts (f)
|
(9,301
|
)
|
||
DETM
Assignment (g)
|
(18,943
|
)
|
||
Total
MTM Risk Management Contract Net Assets at June 30, 2005
|
$
|
34,560
|
(a)
|
“(Gain)
Loss from Contracts Realized/Settled During the Period” includes realized
risk management contracts and related derivatives that settled
during 2005
where we entered into the contract prior to 2005.
|
(b)
|
“Fair
Value of New Contracts When Entered During the Period” represents the fair
value at inception of long-term contracts entered into with customers
during 2005. Most of the fair value comes from longer term fixed
price
contracts with customers that seek to limit their risk against
fluctuating
energy prices. Inception value is only recorded if observable
market data
can be obtained for valuation inputs for the entire contract
term. The
contract prices are valued against market curves associated with
the
delivery location and delivery term.
|
(c)
|
“Net
Option Premiums Paid/(Received)” reflects the net option premiums
paid/(received) as they relate to unexercised and unexpired option
contracts that were entered in 2005.
|
(d)
|
“Changes
in Fair Value of Risk Management Contracts” represents the fair value
change in the risk management portfolio due to market fluctuations
during
the current period. Market fluctuations are attributable to various
factors such as supply/demand, weather, etc.
|
(e)
|
“Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions” relates to the net gains (losses) of those contracts that
are not reflected in the Condensed Consolidated Statements of
Income.
These net gains (losses) are recorded as regulatory assets/liabilities
for
those subsidiaries that operate in regulated
jurisdictions.
|
(f)
|
“Net
Cash Flow and Fair Value Hedge Contracts” (pretax) are discussed below in
Accumulated Other Comprehensive Income (Loss).
|
(g)
|
See
“Natural Gas Contracts with DETM” section in Note 17 of the 2004 Annual
Report.
|
MTM
Risk Management Contracts (a)
|
Hedges
|
DETM
Assignment (b)
|
Total
(c)
|
||||||||||
Current
Assets
|
$
|
91,499
|
$
|
486
|
$
|
-
|
$
|
91,985
|
|||||
Noncurrent
Assets
|
164,321
|
100
|
-
|
164,421
|
|||||||||
Total
MTM Derivative Contract Assets
|
255,820
|
586
|
-
|
256,406
|
|||||||||
Current
Liabilities
|
(84,208
|
)
|
(8,578
|
)
|
(6,373
|
)
|
(99,159
|
)
|
|||||
Noncurrent
Liabilities
|
(108,808
|
)
|
(1,309
|
)
|
(12,570
|
)
|
(122,687
|
)
|
|||||
Total
MTM Derivative Contract Liabilities
|
(193,016
|
)
|
(9,887
|
)
|
(18,943
|
)
|
(221,846
|
)
|
|||||
Total
MTM Derivative Contract Net Assets (Liabilities)
|
$
|
62,804
|
$
|
(9,301
|
)
|
$
|
(18,943
|
)
|
$
|
34,560
|
(a)
|
Does
not include Cash Flow and
Fair Value Hedges.
|
(b)
|
See
“Natural Gas Contracts with DETM” section in Note 17 of the 2004 Annual
Report.
|
(c)
|
Represents
amount of total MTM derivative contracts recorded within Risk
Management
Assets, Long-term Risk Management Assets, Risk Management Liabilities
and
Long-term Risk Management Liabilities on our Condensed Consolidated
Balance Sheets.
|
·
|
The
source of fair value used in determining the carrying amount
of our total
MTM asset or liability (external sources or modeled
internally).
|
·
|
The
maturity, by year, of our net assets/liabilities, giving an indication
of
when these MTM amounts will settle and generate
cash.
|
Remainder
of 2005
|
2006
|
2007
|
2008
|
2009
|
After
2009
(c)
|
Total
(d)
|
||||||||||||||||
Prices
Actively Quoted - Exchange Traded
Contracts
|
$
|
(10,546
|
)
|
$
|
(85
|
)
|
$
|
8,362
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
(2,269
|
)
|
|||||
Prices
Provided by Other External Sources
- OTC Broker Quotes (a)
|
22,863
|
32,936
|
11,448
|
11,743
|
-
|
-
|
78,990
|
|||||||||||||||
Prices
Based on Models and Other Valuation
Methods (b)
|
(11,715
|
)
|
(17,016
|
)
|
(4,753
|
)
|
1,575
|
9,970
|
8,022
|
(13,917
|
)
|
|||||||||||
Total
|
$
|
602
|
$
|
15,835
|
$
|
15,057
|
$
|
13,318
|
$
|
9,970
|
$
|
8,022
|
$
|
62,804
|
(a)
|
“Prices
Provided by Other External Sources - OTC Broker Quotes” reflects
information obtained from over-the-counter brokers, industry
services, or
multiple-party on-line platforms.
|
(b)
|
“Prices
Based on Models and Other Valuation Methods” is in absence of pricing
information from external sources. Modeled information is derived
using
valuation models developed by the reporting entity, reflecting
when
appropriate, option pricing theory, discounted cash flow concepts,
valuation adjustments, etc. and may require projection of prices
for
underlying commodities beyond the period that prices are available
from
third-party sources. In addition, where external pricing information
or
market liquidity are limited, such valuations are classified
as modeled.
The determination of the point at which a market is no longer
liquid for
placing it in the modeled category varies by market.
|
(c)
|
There
is mark-to-market value in excess of 10 percent of our total
mark-to-market value in individual periods beyond 2009. $8.5
million of
this mark-to-market value is in 2010.
|
(d)
|
Amounts
exclude Cash Flow and Fair Value
Hedges.
|
Power
|
Foreign
Currency
|
Interest
Rate
|
Total
|
||||||||||
Beginning
Balance December 31, 2004
|
$
|
2,422
|
$
|
(176
|
)
|
$
|
(11,570
|
)
|
$
|
(9,324
|
)
|
||
Changes
in Fair Value (a)
|
(3,692
|
)
|
-
|
(6,327
|
)
|
(10,019
|
)
|
||||||
Reclassifications
from AOCI to Net Income
(b)
|
(4,380
|
)
|
2
|
515
|
(3,863
|
)
|
|||||||
Ending
Balance June 30, 2005
|
$
|
(5,650
|
)
|
$
|
(174
|
)
|
$
|
(17,382
|
)
|
$
|
(23,206
|
)
|
(a)
|
“Changes
in Fair Value” shows changes in the fair value of derivatives designated
as cash flow hedges during the reporting period that are not
yet settled
at June 30, 2005. Amounts are reported net of related income
taxes.
|
(b)
|
“Reclassifications
from AOCI to Net Income” represents gains or losses from derivatives used
as hedging instruments in cash flow hedges that were reclassified
into net
income during the reporting period. Amounts are reported net
of related
income taxes above.
|
Six
Months Ended
|
Twelve
Months Ended
|
|||||||||||||||
June
30, 2005
|
December
31, 2004
|
|||||||||||||||
(in
thousands)
|
(in
thousands)
|
|||||||||||||||
End
|
High
|
Average
|
Low
|
End
|
High
|
Average
|
Low
|
|||||||||
$1,162
|
$1,391
|
$679
|
$399
|
$577
|
$1,883
|
$812
|
$277
|
Three
Months Ended
|
Six
Months Ended
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
OPERATING
REVENUES
|
|||||||||||||
Electric
Generation, Transmission and Distribution
|
$
|
439,548
|
$
|
414,865
|
$
|
943,689
|
$
|
888,090
|
|||||
Sales
to AEP Affiliates
|
55,979
|
51,047
|
108,917
|
104,929
|
|||||||||
TOTAL
|
495,527
|
465,912
|
1,052,606
|
993,019
|
|||||||||
OPERATING
EXPENSES
|
|||||||||||||
Fuel
for Electric Generation
|
123,017
|
98,694
|
236,398
|
209,405
|
|||||||||
Purchased
Electricity for Resale
|
26,732
|
17,786
|
54,965
|
34,430
|
|||||||||
Purchased
Electricity from AEP Affiliates
|
107,023
|
87,793
|
233,986
|
178,280
|
|||||||||
Other
Operation
|
77,284
|
72,058
|
148,292
|
140,800
|
|||||||||
Maintenance
|
37,266
|
52,933
|
84,456
|
94,253
|
|||||||||
Depreciation
and Amortization
|
46,491
|
47,231
|
96,450
|
95,144
|
|||||||||
Taxes
Other Than Income Taxes
|
23,322
|
23,499
|
47,361
|
46,952
|
|||||||||
Income
Taxes
|
8,756
|
19,836
|
34,998
|
60,276
|
|||||||||
TOTAL
|
449,891
|
419,830
|
936,906
|
859,540
|
|||||||||
OPERATING
INCOME
|
45,636
|
46,082
|
115,700
|
133,479
|
|||||||||
Nonoperating
Income
|
8,768
|
3,152
|
12,255
|
8,699
|
|||||||||
Nonoperating
Expenses
|
2,441
|
3,208
|
7,004
|
5,741
|
|||||||||
Nonoperating
Income Tax Expense (Credit)
|
605
|
(1,263
|
)
|
(1,278
|
)
|
(1,625
|
)
|
||||||
Interest
Charges
|
27,145
|
25,463
|
51,344
|
50,900
|
|||||||||
NET
INCOME
|
24,213
|
21,826
|
70,885
|
87,162
|
|||||||||
Preferred
Stock Dividend Requirements, Including Capital Stock
Expense and Other Expense
|
905
|
798
|
1,702
|
1,621
|
|||||||||
EARNINGS
APPLICABLE TO COMMON STOCK
|
$
|
23,308
|
$
|
21,028
|
$
|
69,183
|
$
|
85,541
|
Common
Stock
|
Paid-in
Capital
|
Retained
Earnings
|
Accumulated
Other Comprehensive Income (Loss)
|
Total
|
||||||||||||
DECEMBER
31, 2003
|
$
|
260,458
|
$
|
719,899
|
$
|
408,718
|
$
|
(52,088
|
)
|
$
|
1,336,987
|
|||||
Common
Stock Dividends
|
(50,000
|
)
|
(50,000
|
)
|
||||||||||||
Preferred
Stock Dividends
|
(400
|
)
|
(400
|
)
|
||||||||||||
Capital
Stock Expense
|
1,221
|
(1,221
|
)
|
-
|
||||||||||||
TOTAL
|
1,286,587
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $2,402
|
(4,462
|
)
|
(4,462
|
)
|
||||||||||||
NET
INCOME
|
87,162
|
87,162
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
82,700
|
|||||||||||||||
JUNE
30, 2004
|
$
|
260,458
|
$
|
721,120
|
$
|
444,259
|
$
|
(56,550
|
)
|
$
|
1,369,287
|
|||||
DECEMBER
31, 2004
|
$
|
260,458
|
$
|
722,314
|
$
|
508,618
|
$
|
(81,672
|
)
|
$
|
1,409,718
|
|||||
Capital
Contribution from Parent
|
100,000
|
100,000
|
||||||||||||||
Preferred
Stock Dividends
|
(400
|
)
|
(400
|
)
|
||||||||||||
Capital
Stock Expense and Other
|
2,447
|
(1,302
|
)
|
1,145
|
||||||||||||
TOTAL
|
1,510,463
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $7,474
|
(13,882
|
)
|
(13,882
|
)
|
||||||||||||
NET
INCOME
|
70,885
|
70,885
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
57,003
|
|||||||||||||||
JUNE
30, 2005
|
$
|
260,458
|
$
|
824,761
|
$
|
577,801
|
$
|
(95,554
|
)
|
$
|
1,567,466
|
2005
|
2004
|
||||||
ELECTRIC
UTILITY PLANT
|
|||||||
Production
|
$
|
2,689,055
|
$
|
2,502,273
|
|||
Transmission
|
1,262,915
|
1,255,390
|
|||||
Distribution
|
2,104,939
|
2,070,377
|
|||||
General
|
294,275
|
302,474
|
|||||
Construction
Work in Progress
|
390,272
|
399,116
|
|||||
Total
|
6,741,456
|
6,529,630
|
|||||
Accumulated
Depreciation and Amortization
|
2,475,900
|
2,443,218
|
|||||
TOTAL
- NET
|
4,265,556
|
4,086,412
|
|||||
OTHER
PROPERTY AND INVESTMENTS
|
|||||||
Nonutility
Property, Net
|
20,743
|
20,378
|
|||||
Other
Investments
|
12,951
|
18,775
|
|||||
TOTAL
|
33,694
|
39,153
|
|||||
CURRENT
ASSETS
|
|||||||
Cash
and Cash Equivalents
|
1,281
|
536
|
|||||
Other
Cash Deposits
|
167
|
1,133
|
|||||
Accounts
Receivable:
|
|||||||
Customers
|
149,541
|
126,422
|
|||||
Affiliated
Companies
|
114,762
|
140,950
|
|||||
Accrued
Unbilled Revenues
|
34,017
|
51,427
|
|||||
Miscellaneous
|
1,653
|
1,264
|
|||||
Allowance
for Uncollectible Accounts
|
(2,181
|
)
|
(5,561
|
)
|
|||
Risk
Management Assets
|
91,985
|
81,811
|
|||||
Fuel
|
73,426
|
45,756
|
|||||
Materials
and Supplies
|
43,849
|
45,644
|
|||||
Margin
Deposits
|
13,227
|
8,329
|
|||||
Prepayments
and Other
|
21,228
|
12,192
|
|||||
TOTAL
|
542,955
|
509,903
|
|||||
DEFERRED
DEBITS AND OTHER ASSETS
|
|||||||
Regulatory
Assets:
|
|||||||
SFAS
109 Regulatory Asset, Net
|
342,714
|
343,415
|
|||||
Transition
Regulatory Assets
|
23,345
|
25,467
|
|||||
Unamortized
Loss on Reacquired Debt
|
18,697
|
18,157
|
|||||
Other
|
62,316
|
36,368
|
|||||
Long-term
Risk Management Assets
|
164,421
|
81,245
|
|||||
Emission
Allowances
|
49,257
|
38,931
|
|||||
Deferred
Property Taxes
|
31,746
|
37,071
|
|||||
Deferred
Charges and Other
|
9,480
|
23,796
|
|||||
TOTAL
|
701,976
|
604,450
|
|||||
TOTAL
ASSETS
|
$
|
5,544,181
|
$
|
5,239,918
|
2005
|
2004
|
||||||
CAPITALIZATION
|
(in
thousands)
|
||||||
Common
Shareholder’s Equity
|
|||||||
Common
Stock - No par value:
|
|||||||
Authorized
- 30,000,000 shares
|
|||||||
Outstanding
- 13,499,500 shares
|
$
|
260,458
|
$
|
260,458
|
|||
Paid-in
Capital
|
824,761
|
722,314
|
|||||
Retained
Earnings
|
577,801
|
508,618
|
|||||
Accumulated
Other Comprehensive Income (Loss)
|
(95,554
|
)
|
(81,672
|
)
|
|||
Total
Common Shareholder’s Equity
|
1,567,466
|
1,409,718
|
|||||
Cumulative
Preferred Stock Not Subject to Mandatory Redemption
|
17,784
|
17,784
|
|||||
Total
Shareholders’ Equity
|
1,585,250
|
1,427,502
|
|||||
Long-term
Debt:
|
|||||||
Nonaffiliated
|
1,705,480
|
1,254,588
|
|||||
Affiliated
|
100,000
|
-
|
|||||
Total
Long-term Debt
|
1,805,480
|
1,254,588
|
|||||
TOTAL
|
3,390,730
|
2,682,090
|
|||||
CURRENT
LIABILITIES
|
|||||||
Long-term
Debt Due Within One Year - Nonaffiliated
|
100,010
|
530,010
|
|||||
Advances
from Affiliates
|
176,692
|
211,060
|
|||||
Accounts
Payable:
|
|||||||
General
|
167,684
|
130,710
|
|||||
Affiliated
Companies
|
74,517
|
76,314
|
|||||
Risk
Management Liabilities
|
99,159
|
89,136
|
|||||
Taxes
Accrued
|
60,557
|
90,404
|
|||||
Interest
Accrued
|
23,817
|
21,076
|
|||||
Customer
Deposits
|
58,269
|
42,822
|
|||||
Obligations
Under Capital Leases
|
6,016
|
6,742
|
|||||
Other
|
51,015
|
56,645
|
|||||
TOTAL
|
817,736
|
1,254,919
|
|||||
DEFERRED
CREDITS AND OTHER LIABILITIES
|
|||||||
Deferred
Income Taxes
|
862,567
|
852,536
|
|||||
Regulatory
Liabilities:
|
|||||||
Asset
Removal Costs
|
88,912
|
95,763
|
|||||
Over-recovery
of Fuel Cost
|
52,041
|
57,843
|
|||||
Deferred
Investment Tax Credits
|
28,114
|
30,382
|
|||||
Unrealized
Gain on Forward Commitments
|
33,236
|
23,270
|
|||||
Employee
Benefits and Pension Obligations
|
92,406
|
130,530
|
|||||
Long-term
Risk Management Liabilities
|
122,687
|
57,349
|
|||||
Asset
Retirement Obligations
|
25,576
|
24,626
|
|||||
Obligations
Under Capital Leases
|
11,101
|
13,136
|
|||||
Deferred
Credits
|
19,075
|
17,474
|
|||||
TOTAL
|
1,335,715
|
1,302,909
|
|||||
Commitments
and Contingencies (Note 5)
|
|||||||
TOTAL
CAPITALIZATION
AND LIABILITIES
|
$
|
5,544,181
|
$
|
5,239,918
|
2005
|
2004
|
||||||
OPERATING
ACTIVITIES
|
|||||||
Net
Income
|
$
|
70,885
|
$
|
87,162
|
|||
Adjustments
to Reconcile Net Income to Net Cash Flows From
Operating Activities:
|
|||||||
Depreciation
and Amortization
|
96,450
|
95,144
|
|||||
Accretion
Expense
|
950
|
859
|
|||||
Deferred
Income Taxes
|
18,206
|
24,377
|
|||||
Deferred
Investment Tax Credits
|
(2,268
|
)
|
2,090
|
||||
Deferred
Property Taxes
|
5,325
|
5,703
|
|||||
Pension
Contributions
|
(39,875
|
)
|
(348
|
)
|
|||
Pension
and Postemployment Benefit Reserves
|
1,714
|
(3,041
|
)
|
||||
Mark-to-Market
of Risk Management Contracts
|
(13,473
|
)
|
5,615
|
||||
Over/Under
Fuel Recovery
|
(8,759
|
)
|
607
|
||||
Carrying
Costs on Stranded Net Assets
|
(4,065
|
)
|
-
|
||||
Change
in Other Noncurrent Assets
|
(11,945
|
)
|
(11,419
|
)
|
|||
Change
in Other Noncurrent Liabilities
|
(23,979
|
)
|
9,559
|
||||
Changes
in Components of Working Capital:
|
|||||||
Accounts
Receivable, Net
|
16,710
|
29,423
|
|||||
Fuel,
Materials and Supplies
|
(25,875
|
)
|
(21,872
|
)
|
|||
Accounts
Payable
|
27,026
|
(32,223
|
)
|
||||
Taxes
Accrued
|
(29,847
|
)
|
27,674
|
||||
Customer
Deposits
|
15,447
|
11,623
|
|||||
Interest
Accrued
|
2,741
|
36
|
|||||
Other
Current Assets
|
(13,897
|
)
|
6,425
|
||||
Other
Current Liabilities
|
(6,358
|
)
|
(7,974
|
)
|
|||
Net
Cash Flows From Operating Activities
|
75,113
|
229,420
|
|||||
INVESTING
ACTIVITIES
|
|||||||
Construction
Expenditures
|
(268,009
|
)
|
(204,648
|
)
|
|||
Change
in Other Cash Deposits, Net
|
966
|
40,615
|
|||||
Proceeds
from Sale of Assets
|
7,731
|
524
|
|||||
Net
Cash Flows Used For Investing Activities
|
(259,312
|
)
|
(163,509
|
)
|
|||
FINANCING
ACTIVITIES
|
|||||||
Issuance
of Long-term Debt - Nonaffiliated
|
594,717
|
-
|
|||||
Issuance
of Long-term Debt - Affiliated
|
100,000
|
-
|
|||||
Retirement
of Long-term Debt
|
(575,005
|
)
|
(85,005
|
)
|
|||
Capital
Contribution from Parent
|
100,000
|
-
|
|||||
Changes
in Advances to/from Affiliates, Net
|
(34,368
|
)
|
68,564
|
||||
Dividends
Paid on Cumulative Preferred Stock
|
(400
|
)
|
(400
|
)
|
|||
Dividends
Paid on Common Stock
|
-
|
(50,000
|
)
|
||||
Net
Cash Flows From (Used For) Financing Activities
|
184,944
|
(66,841
|
)
|
||||
Net
Increase (Decrease) in Cash and Cash Equivalents
|
745
|
(930
|
)
|
||||
Cash
and Cash Equivalents at Beginning of Period
|
536
|
4,561
|
|||||
Cash
and Cash Equivalents at End of Period
|
$
|
1,281
|
$
|
3,631
|
SUPPLEMENTAL
DISCLOSURE:
|
Cash
paid for interest net of capitalized amounts was $45,064,000
and
$46,739,000 and for income taxes was $47,461,000 and $3,946,000
in 2005
and 2004, respectively. Noncash capital lease acquisitions in
2005 and
2004 were $748,000 and $910,000, respectively. Construction Expenditures
include the change in construction-related Accounts Payable of
$8,151,000
and $(3,646,000) in 2005 and 2004,
respectively.
|
Footnote
Reference
|
|
Significant
Accounting Matters
|
Note
1
|
New
Accounting Pronouncements
|
Note
2
|
Rate
Matters
|
Note
3
|
Commitments
and Contingencies
|
Note
5
|
Guarantees
|
Note
6
|
Benefit
Plans
|
Note
8
|
Business
Segments
|
Note
9
|
Income
Taxes
|
Note
10
|
Financing
Activities
|
Note
11
|
Company-wide
Staffing and Budget Review
|
Note
12
|
Second
Quarter of 2004 Net Income
|
$
|
31
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins
|
(5
|
)
|
|||||
Transmission
Revenues
|
(5
|
)
|
|||||
Off-system
Sales
|
4
|
||||||
Other
Revenues
|
1
|
||||||
Total
Change in Gross Margin
|
(5
|
)
|
|||||
Changes
in Operating Expenses and Other:
|
|||||||
Depreciation
and Amortization
|
9
|
||||||
Nonoperating
Income and Expenses, Net
|
4
|
||||||
Interest
Charges
|
(1
|
)
|
|||||
Total
Change in Operating Expenses and Other
|
12
|
||||||
Income
Tax Expense
|
(3
|
)
|
|||||
Second
Quarter of 2005 Net Income
|
$
|
35
|
·
|
Retail
Margins were $5 million less than the prior period primarily
due to lower
fuel margins partially offset by lower capacity settlement
costs.
|
·
|
Transmission
Revenues decreased $5 million primarily due to the loss of
through and out
rates, net of replacement SECA rates. See “FERC Order on Regional Through
and Out Rates” for additional discussion of these FERC rate
changes.
|
·
|
Off-system
Sales margins increased $4 million primarily due to favorable
price
margins.
|
·
|
Depreciation
and Amortization expense decreased $9 million primarily due
to the order
in the rate stabilization plan which resulted in a reversal
of unused
shopping credits of $18 million partially offset by the establishment
of a
$7 million regulatory liability to benefit low income customers
and for
economic development.
|
·
|
Nonoperating
Income and Expenses, Net increased $4 million primarily due
to the
establishment of a regulatory asset for carrying costs on environmental
capital expenditures.
|
Six
Months Ended June 30, 2004 Net Income
|
$
|
76
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins
|
(11
|
)
|
|||||
Transmission
Revenues
|
(11
|
)
|
|||||
Off-system
Sales
|
6
|
||||||
Other
Revenues
|
(1
|
)
|
|||||
Total
Change in Gross Margin
|
(17
|
)
|
|||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
11
|
||||||
Depreciation
and Amortization
|
8
|
||||||
Taxes
Other Than Income Taxes
|
(1
|
)
|
|||||
Nonoperating
Income and Expenses, Net
|
6
|
||||||
Interest
Charges
|
(1
|
)
|
|||||
Total
Change in Operating Expenses and Other
|
23
|
||||||
Income
Tax Expense
|
-
|
||||||
Six
Months Ended June 30, 2005 Net Income
|
$
|
82
|
·
|
Retail
Margins were $11 million less than the prior period primarily
due to lower
fuel margins partially offset by lower capacity settlement
costs.
|
·
|
Transmission
Revenues decreased $11 million primarily due to the loss of
through and
out rates, net of replacement SECA rates.
|
·
|
Off-system
Sales margins increased $6 million primarily due to favorable
price
margins.
|
·
|
Other
Operation and Maintenance expenses decreased $11 million primarily
due to
lower expenditures than estimated for storm expenses from the
major ice
storm in December 2004, a decrease in transmission expenses
related to the
AEP Transmission Equalization Agreement, and the settlement
and
cancellation of the corporate owned life insurance policy in
February
2005.
|
·
|
Depreciation
and Amortization expense decreased $8 million primarily due
to the order
in the rate stabilization plan which resulted in a reversal
of unused
shopping credits of $18 million partially offset by the establishment
of a
$7 million regulatory liability to benefit low income customers
and for
economic development.
|
·
|
Nonoperating
Income and Expenses, Net increased $6 million primarily due
to the
establishment of a regulatory asset for carrying costs on environmental
capital expenditures offset by lower margins on risk management
activities.
|
Moody’s
|
S&P
|
Fitch
|
|||
Senior
Unsecured Debt
|
A3
|
BBB
|
A-
|
Total
MTM Risk Management Contract Net Assets at December 31,
2004
|
$
|
30,919
|
||
(Gain)
Loss from Contracts Realized/Settled During the Period (a)
|
(7,395
|
)
|
||
Fair
Value of New Contracts When Entered During the Period (b)
|
599
|
|||
Net
Option Premiums Paid/(Received) (c)
|
(153
|
)
|
||
Change
in Fair Value Due to Valuation Methodology Changes
|
-
|
|||
Changes
in Fair Value of Risk Management Contracts (d)
|
8,160
|
|||
Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions (e)
|
-
|
|||
Total
MTM Risk Management Contract Net Assets
|
32,130
|
|||
Net
Cash Flow Hedge Contracts (f)
|
(4,502
|
)
|
||
DETM
Assignment (g)
|
(9,694
|
)
|
||
Total
MTM Risk Management Contract Net Assets at June 30, 2005
|
$
|
17,934
|
(a)
|
“(Gain)
Loss from Contracts Realized/Settled During the Period” includes realized
risk management contracts and related derivatives that settled
during 2005
where we entered into the contract prior to 2005.
|
(b)
|
“Fair
Value of New Contracts When Entered During the Period” represents the fair
value at inception of long-term contracts entered into with
customers
during 2005. Most of the fair value comes from longer term
fixed price
contracts with customers that seek to limit their risk against
fluctuating
energy prices. Inception value is only recorded if observable
market data
can be obtained for valuation inputs for the entire contract
term. The
contract prices are valued against market curves associated
with the
delivery location and delivery term.
|
(c)
|
“Net
Option Premiums Paid/(Received)” reflects the net option premiums
paid/(received) as they relate to unexercised and unexpired
option
contracts that were entered in 2005.
|
(d)
|
“Changes
in Fair Value of Risk Management Contracts” represents the fair value
change in the risk management portfolio due to market fluctuations
during
the current period. Market fluctuations are attributable to
various
factors such as supply/demand, weather, etc.
|
(e)
|
“Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions” relates to the net gains (losses) of those contracts that
are not reflected in the Condensed Consolidated Statements
of Income.
These net gains (losses) are recorded as regulatory assets/liabilities
for
those subsidiaries that operate in regulated
jurisdictions.
|
(f)
|
“Net
Cash Flow Hedge Contracts” (pretax) are discussed below in Accumulated
Other Comprehensive Income (Loss).
|
(g)
|
See
“Natural Gas Contracts with DETM” section in Note 17 of the 2004 Annual
Report.
|
MTM
Risk Management Contracts (a)
|
Cash
Flow Hedges
|
DETM
Assignment (b)
|
Total
(c)
|
||||||||||
Current
Assets
|
$
|
46,828
|
$
|
177
|
$
|
-
|
$
|
47,005
|
|||||
Noncurrent
Assets
|
84,091
|
51
|
-
|
84,142
|
|||||||||
Total
MTM Derivative Contract Assets
|
130,919
|
228
|
-
|
131,147
|
|||||||||
Current
Liabilities
|
(43,099
|
)
|
(4,322
|
)
|
(3,261
|
)
|
(50,682
|
)
|
|||||
Noncurrent
Liabilities
|
(55,690
|
)
|
(408
|
)
|
(6,433
|
)
|
(62,531
|
)
|
|||||
Total
MTM Derivative Contract Liabilities
|
(98,789
|
)
|
(4,730
|
)
|
(9,694
|
)
|
(113,213
|
)
|
|||||
Total
MTM Derivative Contract Net Assets
(Liabilities)
|
$
|
32,130
|
$
|
(4,502
|
)
|
$
|
(9,694
|
)
|
$
|
17,934
|
(a)
|
Does
not include Cash Flow Hedges.
|
(b)
|
See
“Natural Gas Contracts with DETM” section in Note 17 of the 2004 Annual
Report.
|
(c)
|
Represents
amount of total MTM derivative contracts recorded within Risk
Management
Assets, Long-term Risk Management Assets, Risk Management Liabilities
and
Long-term Risk Management Liabilities on our Condensed Consolidated
Balance Sheets.
|
·
|
The
source of fair value used in determining the carrying amount
of our total
MTM asset or liability (external sources or modeled
internally).
|
·
|
The
maturity, by year, of our net assets/liabilities, giving an
indication of
when these MTM amounts will settle and generate
cash.
|
Remainder
of 2005
|
2006
|
2007
|
2008
|
2009
|
After
2009
(c)
|
Total
(d)
|
||||||||||||||||
Prices
Actively Quoted - Exchange Traded
Contracts
|
$
|
(5,397
|
)
|
$
|
(44
|
)
|
$
|
4,279
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
(1,162
|
)
|
|||||
Prices
Provided by Other External Sources
- OTC
Broker Quotes (a)
|
11,698
|
16,857
|
5,854
|
6,009
|
-
|
-
|
40,418
|
|||||||||||||||
Prices
Based on Models and Other Valuation
Methods (b)
|
(5,991
|
)
|
(8,712
|
)
|
(2,436
|
)
|
806
|
5,102
|
4,105
|
(7,126
|
)
|
|||||||||||
Total
|
$
|
310
|
$
|
8,101
|
$
|
7,697
|
$
|
6,815
|
$
|
5,102
|
$
|
4,105
|
$
|
32,130
|
(a)
|
“Prices
Provided by Other External Sources - OTC Broker Quotes” reflects
information obtained from over-the-counter brokers, industry
services, or
multiple-party on-line platforms.
|
(b)
|
“Prices
Based on Models and Other Valuation Methods” is in absence of pricing
information from external sources. Modeled information is derived
using
valuation models developed by the reporting entity, reflecting
when
appropriate, option pricing theory, discounted cash flow concepts,
valuation adjustments, etc. and may require projection of prices
for
underlying commodities beyond the period that prices are available
from
third-party sources. In addition, where external pricing information
or
market liquidity are limited, such valuations are classified
as modeled.
The determination of the point at which a market is no longer
liquid for
placing it in the modeled category varies by market.
|
(c)
|
There
is mark-to-market value in excess of 10 percent of our total
mark-to-market value in individual periods beyond 2009. $4.4
million of
this mark-to-market value is in 2010.
|
(d)
|
Amounts
exclude Cash Flow Hedges.
|
Power
|
||||
Beginning
Balance December 31, 2004
|
$
|
1,393
|
||
Changes
in Fair Value (a)
|
(2,044
|
)
|
||
Reclassifications
from AOCI to Net Income (b)
|
(2,241
|
)
|
||
Ending
Balance June 30, 2005
|
$
|
(2,892
|
)
|
(a)
|
“Changes
in Fair Value” shows changes in the fair value of derivatives designated
as cash flow hedges during the reporting period that are not
yet settled
at June 30, 2005. Amounts are reported net of related income
taxes.
|
(b)
|
“Reclassifications
from AOCI to Net Income” represents gains or losses from derivatives used
as hedging instruments in cash flow hedges that were reclassified
into net
income during the reporting period. Amounts are reported net
of related
income taxes.
|
Six
Months Ended
|
Twelve
Months Ended
|
|||||||||||||||
June
30, 2005
|
December
31, 2004
|
|||||||||||||||
(in
thousands)
|
(in
thousands)
|
|||||||||||||||
End
|
High
|
Average
|
Low
|
End
|
High
|
Average
|
Low
|
|||||||||
$595
|
$712
|
$347
|
$204
|
$332
|
$1,083
|
$467
|
$160
|
Three
Months Ended
|
Six
Months Ended
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
OPERATING
REVENUES
|
|||||||||||||
Electric
Generation, Transmission and Distribution
|
$
|
339,969
|
$
|
337,387
|
$
|
680,125
|
$
|
681,465
|
|||||
Sales
to AEP Affiliates
|
20,918
|
21,333
|
45,011
|
39,952
|
|||||||||
TOTAL
|
360,887
|
358,720
|
725,136
|
721,417
|
|||||||||
OPERATING
EXPENSES
|
|||||||||||||
Fuel
for Electric Generation
|
46,558
|
51,159
|
107,910
|
92,796
|
|||||||||
Fuel
from Affiliates for Electric Generation
|
-
|
1,755
|
-
|
10,603
|
|||||||||
Purchased
Electricity for Resale
|
8,703
|
4,769
|
17,906
|
9,450
|
|||||||||
Purchased
Electricity from AEP Affiliates
|
95,172
|
85,706
|
174,947
|
167,421
|
|||||||||
Other
Operation
|
58,302
|
59,390
|
107,070
|
117,263
|
|||||||||
Maintenance
|
26,700
|
25,944
|
42,084
|
42,770
|
|||||||||
Depreciation
and Amortization
|
27,333
|
36,445
|
65,531
|
73,263
|
|||||||||
Taxes
Other Than Income Taxes
|
32,913
|
32,726
|
69,075
|
68,052
|
|||||||||
Income
Taxes
|
18,047
|
16,197
|
38,469
|
40,662
|
|||||||||
TOTAL
|
313,728
|
314,091
|
622,992
|
622,280
|
|||||||||
OPERATING
INCOME
|
47,159
|
44,629
|
102,144
|
99,137
|
|||||||||
Nonoperating
Income
|
578
|
650
|
5,788
|
5,617
|
|||||||||
Carrying
Costs Income
|
4,158
|
120
|
6,916
|
231
|
|||||||||
Nonoperating
Expenses
|
986
|
859
|
1,742
|
1,593
|
|||||||||
Nonoperating
Income Tax Expense (Credit)
|
590
|
(628
|
)
|
2,407
|
291
|
||||||||
Interest
Charges
|
15,668
|
14,413
|
28,580
|
27,227
|
|||||||||
NET
INCOME
|
34,651
|
30,755
|
82,119
|
75,874
|
|||||||||
Preferred
Stock Dividend Requirements including Capital Stock
Expense and Other Expense
|
1,858
|
254
|
2,112
|
508
|
|||||||||
EARNINGS
APPLICABLE TO COMMON STOCK
|
$
|
32,793
|
$
|
30,501
|
$
|
80,007
|
$
|
75,366
|
Common
Stock
|
Paid-in
Capital
|
Retained
Earnings
|
Accumulated
Other Comprehensive Income (Loss)
|
Total
|
||||||||||||
DECEMBER
31, 2003
|
$
|
41,026
|
$
|
576,400
|
$
|
326,782
|
$
|
(46,327
|
)
|
$
|
897,881
|
|||||
Common
Stock Dividends
|
(62,500
|
)
|
(62,500
|
)
|
||||||||||||
Capital
Stock Expense
|
508
|
(508
|
)
|
-
|
||||||||||||
TOTAL
|
835,381
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $1,290
|
(2,397
|
)
|
(2,397
|
)
|
||||||||||||
NET
INCOME
|
75,874
|
75,874
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
73,477
|
|||||||||||||||
JUNE
30, 2004
|
$
|
41,026
|
$
|
576,908
|
$
|
339,648
|
$
|
(48,724
|
)
|
$
|
908,858
|
|||||
DECEMBER
31, 2004
|
$
|
41,026
|
$
|
577,415
|
$
|
341,025
|
$
|
(60,816
|
)
|
$
|
898,650
|
|||||
Common
Stock Dividends
|
(57,000
|
)
|
(57,000
|
)
|
||||||||||||
Capital
Stock Expense and Other
|
2,112
|
(2,112
|
)
|
-
|
||||||||||||
TOTAL
|
841,650
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $2,307
|
(4,285
|
)
|
(4,285
|
)
|
||||||||||||
NET
INCOME
|
82,119
|
82,119
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
77,834
|
|||||||||||||||
JUNE
30, 2005
|
$
|
41,026
|
$
|
579,527
|
$
|
364,032
|
$
|
(65,101
|
)
|
$
|
919,484
|
2005
|
2004
|
||||||
ELECTRIC
UTILITY PLANT
|
|||||||
Production
|
$
|
1,716,269
|
$
|
1,658,552
|
|||
Transmission
|
444,161
|
432,714
|
|||||
Distribution
|
1,323,790
|
1,300,252
|
|||||
General
|
164,354
|
167,985
|
|||||
Construction
Work in Progress
|
102,952
|
131,743
|
|||||
Total
|
3,751,526
|
3,691,246
|
|||||
Accumulated
Depreciation and Amortization
|
1,510,315
|
1,471,950
|
|||||
TOTAL
- NET
|
2,241,211
|
2,219,296
|
|||||
OTHER
PROPERTY AND INVESTMENTS
|
|||||||
Nonutility
Property, Net
|
21,817
|
22,322
|
|||||
Other
Investments
|
4,105
|
5,147
|
|||||
TOTAL
|
25,922
|
27,469
|
|||||
CURRENT
ASSETS
|
|||||||
Cash
and Cash Equivalents
|
694
|
25
|
|||||
Other
Cash Deposits
|
-
|
33
|
|||||
Advances
to Affiliates
|
62,172
|
141,550
|
|||||
Accounts
Receivable:
|
|||||||
Customers
|
42,718
|
41,130
|
|||||
Affiliated
Companies
|
57,540
|
72,854
|
|||||
Accrued
Unbilled Revenues
|
11,527
|
19,580
|
|||||
Miscellaneous
|
1,117
|
1,145
|
|||||
Allowance
for Uncollectible Accounts
|
(555
|
)
|
(674
|
)
|
|||
Fuel
|
35,671
|
34,026
|
|||||
Materials
and Supplies
|
33,835
|
37,137
|
|||||
Risk
Management Assets
|
47,005
|
46,631
|
|||||
Margin
Deposits
|
6,769
|
4,848
|
|||||
Prepayments
and Other
|
16,234
|
11,499
|
|||||
TOTAL
|
314,727
|
409,784
|
|||||
DEFERRED
DEBITS AND OTHER ASSETS
|
|||||||
Regulatory
Assets:
|
|||||||
SFAS
109 Regulatory Asset, Net
|
17,591
|
16,481
|
|||||
Transition
Regulatory Assets
|
159,269
|
156,676
|
|||||
Unamortized
Loss on Reacquired Debt
|
12,772
|
13,155
|
|||||
Other
|
47,414
|
25,691
|
|||||
Long-term
Risk Management Assets
|
84,142
|
46,735
|
|||||
Deferred
Property Taxes
|
32,544
|
64,754
|
|||||
Deferred
Charges and Other
|
47,762
|
49,855
|
|||||
TOTAL
|
401,494
|
373,347
|
|||||
TOTAL
ASSETS
|
$
|
2,983,354
|
$
|
3,029,896
|
2005
|
2004
|
||||||
CAPITALIZATION
|
(in
thousands)
|
||||||
Common
Shareholder’s Equity:
|
|||||||
Common
Stock - No par value:
|
|||||||
Authorized
- 24,000,000 shares
|
|||||||
Outstanding
- 16,410,426 shares
|
$
|
41,026
|
$
|
41,026
|
|||
Paid-in
Capital
|
579,527
|
577,415
|
|||||
Retained
Earnings
|
364,032
|
341,025
|
|||||
Accumulated
Other Comprehensive Income (Loss)
|
(65,101
|
)
|
(60,816
|
)
|
|||
Total
Common Shareholder’s Equity
|
919,484
|
898,650
|
|||||
Preferred
Stock - No Shares Outstanding
|
-
|
-
|
|||||
Authorized
- 2,500,000 shares at $100 par value
|
|||||||
Authorized
- 7,000,000 shares at $25 par value
|
|||||||
Total
Shareholder’s Equity
|
919,484
|
898,650
|
|||||
Long-term
Debt:
|
|||||||
Nonaffiliated
|
851,757
|
851,626
|
|||||
Affiliated
|
100,000
|
100,000
|
|||||
Total
Long-term Debt
|
951,757
|
951,626
|
|||||
TOTAL
|
1,871,241
|
1,850,276
|
|||||
CURRENT
LIABILITIES
|
|||||||
Long-term
Debt Due Within One Year - Nonaffiliated
|
36,000
|
36,000
|
|||||
Accounts
Payable:
|
|||||||
General
|
51,674
|
63,606
|
|||||
Affiliated
Companies
|
54,920
|
45,745
|
|||||
Customer
Deposits
|
32,508
|
24,890
|
|||||
Taxes
Accrued
|
102,195
|
195,284
|
|||||
Interest
Accrued
|
16,615
|
16,320
|
|||||
Risk
Management Liabilities
|
50,682
|
42,172
|
|||||
Obligations
Under Capital Leases
|
3,402
|
3,854
|
|||||
Other
|
25,451
|
24,338
|
|||||
TOTAL
|
373,447
|
452,209
|
|||||
DEFERRED
CREDITS AND OTHER LIABILITIES
|
|||||||
Deferred
Income Taxes
|
446,650
|
464,545
|
|||||
Regulatory
Liabilities:
|
|||||||
Asset
Removal Costs
|
106,850
|
103,104
|
|||||
Deferred
Investment Tax Credits
|
26,612
|
27,933
|
|||||
Other
|
22,104
|
-
|
|||||
Employee
Benefits and Pension Obligations
|
37,813
|
62,778
|
|||||
Long-term
Risk Management Liabilities
|
62,531
|
32,731
|
|||||
Obligations
Under Capital Leases
|
7,488
|
8,660
|
|||||
Asset
Retirement Obligations
|
12,006
|
11,585
|
|||||
Deferred
Credits and Other
|
16,612
|
16,075
|
|||||
TOTAL
|
738,666
|
727,411
|
|||||
Commitments
and Contingencies (Note 5)
|
|||||||
TOTAL
CAPITALIZATION
AND LIABILITIES
|
$
|
2,983,354
|
$
|
3,029,896
|
|||
2005
|
2004
|
||||||
OPERATING
ACTIVITIES
|
|||||||
Net
Income
|
$
|
82,119
|
$
|
75,874
|
|||
Adjustments
to Reconcile Net Income to Net Cash Flows
From
Operating Activities:
|
|||||||
Depreciation
and Amortization
|
65,531
|
73,263
|
|||||
Deferred
Income Taxes
|
(1,593
|
)
|
8,642
|
||||
Deferred
Investment Tax Credits
|
(1,321
|
)
|
(1,473
|
)
|
|||
Pension
and Postemployment Benefit Reserves
|
257
|
(2,674
|
)
|
||||
Deferred
Property Taxes
|
32,210
|
30,763
|
|||||
Mark-to-Market
of Risk Management Contracts
|
(5,171
|
)
|
1,611
|
||||
Carrying
Costs Income
|
(6,916
|
)
|
(231
|
)
|
|||
Pension
Contributions
|
(25,222
|
)
|
(8
|
)
|
|||
Gain
on Sale of Assets
|
(1,352
|
)
|
(1,786
|
)
|
|||
Change
in Other Noncurrent Assets
|
(19,416
|
)
|
(19,464
|
)
|
|||
Change
in Other Noncurrent Liabilities
|
3,536
|
(809
|
)
|
||||
Changes
in Components of Working Capital:
|
|||||||
Accounts
Receivable, Net
|
21,688
|
20,483
|
|||||
Fuel,
Materials and Supplies
|
1,657
|
(13,704
|
)
|
||||
Accounts
Payable
|
(2,180
|
)
|
(20,128
|
)
|
|||
Taxes
Accrued
|
(93,089
|
)
|
(18,790
|
)
|
|||
Customer
Deposits
|
7,618
|
6,745
|
|||||
Interest
Accrued
|
295
|
5
|
|||||
Other
Current Assets
|
(6,656
|
)
|
3,230
|
||||
Other
Current Liabilities
|
661
|
(2,894
|
)
|
||||
Net
Cash Flows From Operating Activities
|
52,656
|
138,655
|
|||||
INVESTING
ACTIVITIES
|
|||||||
Construction
Expenditures
|
(78,061
|
)
|
(66,693
|
)
|
|||
Change
in Other Cash Deposits, Net
|
33
|
18
|
|||||
Proceeds
from Sale of Assets
|
3,663
|
2,244
|
|||||
Net
Cash Flows Used For Investing Activities
|
(74,365
|
)
|
(64,431
|
)
|
|||
FINANCING
ACTIVITIES
|
|||||||
Changes
in Advances to/from Affiliates, Net
|
79,378
|
(558
|
)
|
||||
Dividends
Paid on Common Stock
|
(57,000
|
)
|
(62,500
|
)
|
|||
Issuance
of Long-term Debt
|
-
|
43,095
|
|||||
Retirement
of Long-term Debt
|
-
|
(54,695
|
)
|
||||
Net
Cash Flows From (Used For) Financing Activities
|
22,378
|
(74,658
|
)
|
||||
Net
Increase (Decrease) in Cash and Cash Equivalents
|
669
|
(434
|
)
|
||||
Cash
and Cash Equivalents at Beginning of Period
|
25
|
3,377
|
|||||
Cash
and Cash Equivalents at End of Period
|
$
|
694
|
$
|
2,943
|
SUPPLEMENTAL
DISCLOSURE:
|
Cash
paid (received) for interest net of capitalized amounts was
$27,390,000
and $25,131,000 and for income taxes was $78,019,000 and $(3,747,000)
in
2005 and 2004, respectively. Noncash capital lease acquisitions
were
$343,000 and $162,000 in 2005 and 2004, respectively. Construction
Expenditures include the change in construction-related Accounts
Payable
of $(577,000) and $44,000 in 2005 and 2004,
respectively.
|
Footnote
Reference
|
|
Significant
Accounting Matters
|
Note
1
|
New
Accounting Pronouncements
|
Note
2
|
Rate
Matters
|
Note
3
|
Customer
Choice and Industry Restructuring
|
Note
4
|
Commitments
and Contingencies
|
Note
5
|
Guarantees
|
Note
6
|
Acquisitions,
Dispositions and Assets Held for Sale
|
Note
7
|
Benefit
Plans
|
Note
8
|
Business
Segments
|
Note
9
|
Income
Taxes
|
Note
10
|
Financing
Activities
|
Note
11
|
Company-wide
Staffing and Budget Review
|
Note
12
|
Second
Quarter of 2004 Net Income
|
$
|
27
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins
|
11
|
||||||
Transmission
Revenues
|
(5
|
)
|
|||||
Total
Change in Gross Margin
|
6
|
||||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
4
|
||||||
Interest
Charges
|
2
|
||||||
Total
Change in Operating Expenses and Other
|
6
|
||||||
Income
Tax Expense
|
(3
|
)
|
|||||
Second
Quarter of 2005 Net Income
|
$
|
36
|
·
|
Retail
Margins increased $11 million primarily due to an increase
in capacity
settlement payments received under the Interconnection Agreement
related
to the increase in an affiliate’s peak.
|
·
|
Transmission
Revenues decreased $5 million primarily due to the loss of
through and out
rates, net of replacement SECA rates. See “FERC Order on Regional Through
and Out Rates” for additional discussion of these FERC rate
changes.
|
·
|
Other
Operation and Maintenance expenses decreased $4 million primarily
due to
lower distribution maintenance expense reflecting the effect
of 2004 storm
damage.
|
·
|
Interest
Charges decreased $2 million primarily due to lower long-term
debt
outstanding and lower interest
rates.
|
Six
Months Ended June 30, 2004 Net Income
|
$
|
70
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins
|
16
|
||||||
Transmission
Revenues
|
(12
|
)
|
|||||
Off-system
Sales and Other Revenues
|
3
|
||||||
Total
Change in Gross Margin
|
7
|
||||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
(3
|
)
|
|||||
Taxes
Other Than Income Taxes
|
(2
|
)
|
|||||
Nonoperating
Income and Expenses, Net
|
(4
|
)
|
|||||
Interest
Charges
|
4
|
||||||
Total
Change in Operating Expenses and Other
|
(5
|
)
|
|||||
Income
Tax Expense
|
3
|
||||||
Six
Months Ended June 30, 2005 Net Income
|
$
|
75
|
·
|
Retail
Margins increased $16 million primarily due to a $21 million
increase in
capacity settlement payments received under the Interconnection
Agreement
related to the increase in an affiliate’s peak partially offset by an
increase in unrecovered fuel costs due to fuel caps in our
Indiana
jurisdiction.
|
·
|
Transmission
Revenues decreased $12 million primarily due to the loss of
through and
out rates, net of replacement SECA
rates.
|
·
|
Other
Operation and Maintenance expenses increased $3 million primarily
due to a
$6 million increase in distribution maintenance mainly for
January 2005
storm damage expenses and $4 million of accruals for employee
severance
costs partially offset by the settlement and cancellation of
COLI policies
in February 2005.
|
·
|
Taxes
Other Than Income Taxes increased $2 million primarily due
to a $1 million
increase in property taxes and a $1 million increase in payroll-related
taxes.
|
·
|
Nonoperating
Income and Expenses, Net declined $4 million reflecting lower
margins on
risk management transactions.
|
·
|
Interest
Charges decreased $4 million primarily due to lower long-term
debt
outstanding and lower interest
rates.
|
Moody’s
|
S&P
|
Fitch
|
|||
Senior
Unsecured Debt
|
Baa2
|
BBB
|
BBB
|
2005
|
2004
|
||||||
(in
thousands)
|
|||||||
Cash
and Cash Equivalents at Beginning of Period
|
$
|
465
|
$
|
3,899
|
|||
Cash
Flows From (Used For):
|
|||||||
Operating
Activities
|
67,046
|
266,994
|
|||||
Investing
Activities
|
(111,578
|
)
|
(84,403
|
)
|
|||
Financing
Activities
|
44,605
|
(183,319
|
)
|
||||
Net
Increase (Decrease) in Cash and Cash Equivalents
|
73
|
(728
|
)
|
||||
Cash
and Cash Equivalents at End of Period
|
$
|
538
|
$
|
3,171
|
Total
MTM Risk Management Contract Net Assets at December 31,
2004
|
$
|
34,573
|
||
(Gain)
Loss from Contracts Realized/Settled During the Period (a)
|
62
|
|||
Fair
Value of New Contracts When Entered During the Period (b)
|
-
|
|||
Net
Option Premiums Paid/(Received) (c)
|
(221
|
)
|
||
Change
in Fair Value Due to Valuation Methodology Changes
|
-
|
|||
Changes
in Fair Value of Risk Management Contracts (d)
|
263
|
|||
Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions (e)
|
1,067
|
|||
Total
MTM Risk Management Contract Net Assets
|
35,744
|
|||
Net
Cash Flow and
Fair Value Hedge
Contracts (f)
|
(5,740
|
)
|
||
DETM
Assignment (g)
|
(10,839
|
)
|
||
Total
MTM Risk Management Contract Net Assets at June 30, 2005
|
$
|
19,165
|
(a)
|
“(Gain)
Loss from Contracts Realized/Settled During the Period” includes realized
risk management contracts and related derivatives that settled
during 2005
where
we entered into the contract prior
to 2005.
|
(b)
|
“Fair
Value of New Contracts When Entered During the Period” represents the fair
value at inception of long-term contracts entered into with
customers
during 2005. Most of the fair value comes from longer term
fixed price
contracts with customers that seek to limit their risk against
fluctuating
energy prices. Inception value is only recorded if observable
market data
can be obtained for valuation inputs for the entire contract
term. The
contract prices are valued against market curves associated
with the
delivery location and delivery term.
|
(c)
|
“Net
Option Premiums Paid/(Received)” reflects the net option premiums
paid/(received) as they relate to unexercised and unexpired
option
contracts that were entered in 2005.
|
(d)
|
“Changes
in Fair Value of Risk Management Contracts” represents the fair value
change in the risk management portfolio due to market fluctuations
during
the current period. Market fluctuations are attributable to
various
factors such as supply/demand, weather, etc.
|
(e)
|
“Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions” relates to the net gains (losses) of those contracts that
are not reflected in the Condensed Consolidated Statements
of Income.
These net gains (losses) are recorded as regulatory assets/liabilities
for
those subsidiaries that operate in regulated
jurisdictions.
|
(f)
|
“Net
Cash Flow and
Fair Value Hedge
Contracts” (pretax) are discussed below in Accumulated Other Comprehensive
Income (Loss).
|
(g)
|
See
“Natural Gas Contracts with DETM” section in Note 17 of the 2004 Annual
Report.
|
MTM
Risk Management Contracts (a)
|
Hedges
|
DETM
Assignment (b)
|
Total
(c)
|
||||||||||
Current
Assets
|
$
|
52,473
|
$
|
197
|
$
|
-
|
$
|
52,670
|
|||||
Noncurrent
Assets
|
94,069
|
57
|
-
|
94,126
|
|||||||||
Total
MTM Derivative Contract Assets
|
146,542
|
254
|
-
|
146,796
|
|||||||||
Current
Liabilities
|
(48,293
|
)
|
(5,378
|
)
|
(3,646
|
)
|
(57,317
|
)
|
|||||
Noncurrent
Liabilities
|
(62,505
|
)
|
(616
|
)
|
(7,193
|
)
|
(70,314
|
)
|
|||||
Total
MTM Derivative Contract Liabilities
|
(110,798
|
)
|
(5,994
|
)
|
(10,839
|
)
|
(127,631
|
)
|
|||||
Total
MTM Derivative Contract Net Assets
(Liabilities)
|
$
|
35,744
|
$
|
(5,740
|
)
|
$
|
(10,839
|
)
|
$
|
19,165
|
(a)
|
Does
not include Cash Flow and Fair Value Hedges.
|
(b)
|
See
“Natural Gas Contracts with DETM” section in Note 17 of the 2004 Annual
Report.
|
(c)
|
Represents
amount of total MTM derivative contracts recorded within Risk
Management
Assets, Long-term Risk Management Assets, Risk Management Liabilities
and
Long-term Risk Management Liabilities on our Condensed Consolidated
Balance Sheets.
|
·
|
The
source of fair value used in determining the carrying amount
of our total
MTM asset or liability (external sources or modeled
internally).
|
·
|
The
maturity, by year, of our net assets/liabilities, giving an
indication of
when these MTM amounts will settle and generate
cash.
|
Remainder
of 2005
|
2006
|
2007
|
2008
|
2009
|
After
2009
(c)
|
Total
(d)
|
||||||||||||||||
Prices
Actively Quoted - Exchange Traded
Contracts
|
$
|
(6,034
|
)
|
$
|
(49
|
)
|
$
|
4,785
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
(1,298
|
)
|
|||||
Prices
Provided by Other External Sources
- OTC
Broker Quotes (a)
|
13,069
|
18,926
|
6,445
|
6,719
|
-
|
-
|
45,159
|
|||||||||||||||
Prices
Based on Models and Other Valuation
Methods (b)
|
(6,707
|
)
|
(9,820
|
)
|
(2,787
|
)
|
902
|
5,705
|
4,590
|
(8,117
|
)
|
|||||||||||
Total
|
$
|
328
|
$
|
9,057
|
$
|
8,443
|
$
|
7,621
|
$
|
5,705
|
$
|
4,590
|
$
|
35,744
|
(a)
|
“Prices
Provided by Other External Sources - OTC Broker Quotes” reflects
information obtained from over-the-counter brokers, industry
services, or
multiple-party on-line platforms.
|
(b)
|
“Prices
Based on Models and Other Valuation Methods” is in absence of pricing
information from external sources. Modeled information is derived
using
valuation models developed by the reporting entity, reflecting
when
appropriate, option pricing theory, discounted cash flow concepts,
valuation adjustments, etc. and may require projection of prices
for
underlying commodities beyond the period that prices are available
from
third-party sources. In addition, where external pricing information
or
market liquidity are limited, such valuations are classified
as modeled.
The determination of the point at which a market is no longer
liquid for
placing it in the modeled category varies by market.
|
(c)
|
There
is mark-to-market value in excess of 10 percent of our total
mark-to-market value in individual periods beyond 2009. $4.9
million of
this mark-to-market value is in 2010.
|
(d)
|
Amounts
exclude Cash Flow and Fair Value
Hedges.
|
Power
|
Interest
Rate
|
Total
|
||||||||
Beginning
Balance December 31, 2004
|
$
|
1,558
|
$
|
(5,634
|
)
|
$
|
(4,076
|
)
|
||
Changes
in Fair Value (a)
|
(2,285
|
)
|
(186
|
)
|
(2,471
|
)
|
||||
Reclassifications
from AOCI to Net Income
(b)
|
(2,506
|
)
|
285
|
(2,221
|
)
|
|||||
Ending
Balance June 30, 2005
|
$
|
(3,233
|
)
|
$
|
(5,535
|
)
|
$
|
(8,768
|
)
|
(a)
|
“Changes
in Fair Value” shows changes in the fair value of derivatives designated
as cash flow hedges during the reporting period that are not
yet settled
at June 30, 2005. Amounts are reported net of related income
taxes.
|
(b)
|
“Reclassifications
from AOCI to Net Income” represents gains or losses from derivatives used
as hedging instruments in cash flow hedges that were reclassified
into net
income during the reporting period. Amounts are reported net
of related
income taxes.
|
Six
Months Ended
|
Twelve
Months Ended
|
|||||||||||||||
June
30, 2005
|
December
31, 2004
|
|||||||||||||||
(in
thousands)
|
(in
thousands)
|
|||||||||||||||
End
|
High
|
Average
|
Low
|
End
|
High
|
Average
|
Low
|
|||||||||
$665
|
$796
|
$388
|
$228
|
$371
|
$1,211
|
$522
|
$178
|
Three
Months Ended
|
Six
Months Ended
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
OPERATING
REVENUES
|
|||||||||||||
Electric
Generation, Transmission and Distribution
|
$
|
357,500
|
$
|
340,766
|
$
|
719,092
|
$
|
694,588
|
|||||
Sales
to AEP Affiliates
|
79,858
|
65,025
|
160,409
|
122,670
|
|||||||||
TOTAL
|
437,358
|
405,791
|
879,501
|
817,258
|
|||||||||
OPERATING
EXPENSES
|
|||||||||||||
Fuel
for Electric Generation
|
78,342
|
65,582
|
156,166
|
129,623
|
|||||||||
Purchased
Electricity for Resale
|
12,730
|
6,191
|
24,002
|
12,554
|
|||||||||
Purchased
Electricity from AEP Affiliates
|
71,984
|
65,665
|
145,993
|
128,793
|
|||||||||
Other
Operation
|
100,026
|
106,116
|
191,002
|
206,966
|
|||||||||
Maintenance
|
48,366
|
46,276
|
102,688
|
84,318
|
|||||||||
Depreciation
and Amortization
|
42,224
|
42,696
|
84,969
|
85,411
|
|||||||||
Taxes
Other Than Income Taxes
|
15,110
|
15,472
|
32,617
|
30,688
|
|||||||||
Income
Taxes
|
18,326
|
14,798
|
38,260
|
39,097
|
|||||||||
TOTAL
|
387,108
|
362,796
|
775,697
|
717,450
|
|||||||||
OPERATING
INCOME
|
50,250
|
42,995
|
103,804
|
99,808
|
|||||||||
Nonoperating
Income
|
21,709
|
19,866
|
39,206
|
40,454
|
|||||||||
Nonoperating
Expenses
|
19,238
|
17,176
|
35,251
|
32,027
|
|||||||||
Nonoperating
Income Tax Expense
|
650
|
878
|
413
|
2,491
|
|||||||||
Interest
Charges
|
16,478
|
17,777
|
32,084
|
35,706
|
|||||||||
NET
INCOME
|
35,593
|
27,030
|
75,262
|
70,038
|
|||||||||
Preferred
Stock Dividend Requirements including Capital Stock
Expense
|
107
|
119
|
225
|
237
|
|||||||||
EARNINGS
APPLICABLE TO COMMON STOCK
|
$
|
35,486
|
$
|
26,911
|
$
|
75,037
|
$
|
69,801
|
Common
Stock
|
Paid-in
Capital
|
Retained
Earnings
|
Accumulated
Other Comprehensive Income (Loss)
|
Total
|
||||||||||||
DECEMBER
31, 2003
|
$
|
56,584
|
$
|
858,694
|
$
|
187,875
|
$
|
(25,106
|
)
|
$
|
1,078,047
|
|||||
Common
Stock Dividends
|
(59,293
|
)
|
(59,293
|
)
|
||||||||||||
Preferred
Stock Dividends
|
(169
|
)
|
(169
|
)
|
||||||||||||
Capital
Stock Expense
|
67
|
(67
|
)
|
-
|
||||||||||||
TOTAL
|
1,018,585
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net
of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $1,603
|
(2,978
|
)
|
(2,978
|
)
|
||||||||||||
NET
INCOME
|
70,038
|
70,038
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
67,060
|
|||||||||||||||
JUNE
30, 2004
|
$
|
56,584
|
$
|
858,761
|
$
|
198,384
|
$
|
(28,084
|
)
|
$
|
1,085,645
|
|||||
DECEMBER
31, 2004
|
$
|
56,584
|
$
|
858,835
|
$
|
221,330
|
$
|
(45,251
|
)
|
$
|
1,091,498
|
|||||
Common
Stock Dividends
|
(42,000
|
)
|
(42,000
|
)
|
||||||||||||
Preferred
Stock Dividends
|
(169
|
)
|
(169
|
)
|
||||||||||||
Capital
Stock Expense and Other
|
2,455
|
(56
|
)
|
2,399
|
||||||||||||
TOTAL
|
1,051,728
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net
of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $2,527
|
(4,692
|
)
|
(4,692
|
)
|
||||||||||||
NET
INCOME
|
75,262
|
75,262
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
70,570
|
|||||||||||||||
JUNE
30, 2005
|
$
|
56,584
|
$
|
861,290
|
$
|
254,367
|
$
|
(49,943
|
)
|
$
|
1,122,298
|
2005
|
2004
|
||||||
ELECTRIC
UTILITY PLANT
|
|||||||
Production
|
$
|
3,133,714
|
$
|
3,122,883
|
|||
Transmission
|
1,012,817
|
1,009,551
|
|||||
Distribution
|
1,012,925
|
990,826
|
|||||
General
(including nuclear fuel)
|
273,264
|
275,622
|
|||||
Construction
Work in Progress
|
215,354
|
163,515
|
|||||
Total
|
5,648,074
|
5,562,397
|
|||||
Accumulated
Depreciation and Amortization
|
2,663,174
|
2,603,479
|
|||||
TOTAL
- NET
|
2,984,900
|
2,958,918
|
|||||
OTHER
PROPERTY AND INVESTMENTS
|
|||||||
Nuclear
Decommissioning and Spent Nuclear Fuel Disposal Trust
Funds
|
1,095,165
|
1,053,439
|
|||||
Nonutility
Property, Net
|
49,375
|
50,440
|
|||||
Other
Investments
|
13,245
|
21,848
|
|||||
TOTAL
|
1,157,785
|
1,125,727
|
|||||
CURRENT
ASSETS
|
|||||||
Cash
and Cash Equivalents
|
538
|
465
|
|||||
Other
Cash Deposits
|
-
|
46
|
|||||
Advances
to Affiliates
|
-
|
5,093
|
|||||
Accounts
Receivable:
|
|||||||
Customers
|
61,968
|
62,608
|
|||||
Affiliated
Companies
|
100,326
|
124,134
|
|||||
Miscellaneous
|
3,557
|
4,339
|
|||||
Allowance
for Uncollectible Accounts
|
(15
|
)
|
(187
|
)
|
|||
Fuel
|
25,667
|
27,218
|
|||||
Materials
and Supplies
|
104,332
|
103,342
|
|||||
Risk
Management Assets
|
52,670
|
52,141
|
|||||
Margin
Deposits
|
7,569
|
5,400
|
|||||
Prepayments
and Other
|
15,428
|
10,541
|
|||||
TOTAL
|
372,040
|
395,140
|
|||||
DEFERRED
DEBITS AND OTHER ASSETS
|
|||||||
Regulatory
Assets:
|
|||||||
SFAS
109 Regulatory Asset, Net
|
136,468
|
147,167
|
|||||
Incremental
Nuclear Refueling Outage Expenses, Net
|
45,002
|
44,244
|
|||||
Unamortized
Loss on Reacquired Debt
|
22,712
|
21,039
|
|||||
DOE
Decontamination Fund
|
11,640
|
14,215
|
|||||
Other
|
48,440
|
31,015
|
|||||
Long-term
Risk Management Assets
|
94,126
|
52,256
|
|||||
Emission
Allowances
|
31,301
|
27,093
|
|||||
Deferred
Property Taxes
|
22,009
|
22,372
|
|||||
Deferred
Charges and Other Assets
|
16,816
|
28,955
|
|||||
TOTAL
|
428,514
|
388,356
|
|||||
TOTAL
ASSETS
|
$
|
4,943,239
|
$
|
4,868,141
|
2005
|
2004
|
||||||
CAPITALIZATION
|
(in
thousands)
|
||||||
Common
Shareholder’s Equity:
|
|||||||
Common
Stock - No Par Value:
|
|||||||
Authorized
- 2,500,000 Shares
|
|||||||
Outstanding
- 1,400,000 Shares
|
$
|
56,584
|
$
|
56,584
|
|||
Paid-in
Capital
|
861,290
|
858,835
|
|||||
Retained
Earnings
|
254,367
|
221,330
|
|||||
Accumulated
Other Comprehensive Income (Loss)
|
(49,943
|
)
|
(45,251
|
)
|
|||
Total
Common Shareholder’s Equity
|
1,122,298
|
1,091,498
|
|||||
Cumulative
Preferred Stock Not Subject to Mandatory Redemption
|
8,084
|
8,084
|
|||||
Total
Shareholders’ Equity
|
1,130,382
|
1,099,582
|
|||||
Long-term
Debt
|
1,315,927
|
1,312,843
|
|||||
TOTAL
|
2,446,309
|
2,412,425
|
|||||
CURRENT
LIABILITIES
|
|||||||
Cumulative
Preferred Stock Due Within One Year
|
-
|
61,445
|
|||||
Advances
from Affiliates
|
143,126
|
-
|
|||||
Accounts
Payable:
|
|||||||
General
|
83,109
|
91,472
|
|||||
Affiliated
Companies
|
45,996
|
51,066
|
|||||
Customer
Deposits
|
35,079
|
29,366
|
|||||
Taxes
Accrued
|
54,263
|
123,159
|
|||||
Interest
Accrued
|
13,152
|
12,465
|
|||||
Risk
Management Liabilities
|
57,317
|
47,174
|
|||||
Obligations
Under Capital Leases
|
6,009
|
6,124
|
|||||
Other
|
57,067
|
70,237
|
|||||
TOTAL
|
495,118
|
492,508
|
|||||
DEFERRED
CREDITS AND OTHER LIABILITIES
|
|||||||
Deferred
Income Taxes
|
306,028
|
315,730
|
|||||
Regulatory
Liabilities:
|
|||||||
Asset
Removal Costs
|
287,280
|
280,054
|
|||||
Deferred
Investment Tax Credits
|
79,138
|
82,802
|
|||||
Excess
ARO for Nuclear Decommissioning
|
259,103
|
245,175
|
|||||
Unrealized
Gain on Forward Commitments
|
45,611
|
35,534
|
|||||
Other
|
33,097
|
33,695
|
|||||
Deferred
Gain on Sale and Leaseback - Rockport Plant Unit 2
|
64,618
|
66,472
|
|||||
Long-term
Risk Management Liabilities
|
70,314
|
36,815
|
|||||
Obligations
Under Capital Leases
|
38,544
|
44,608
|
|||||
Asset
Retirement Obligations
|
735,401
|
711,769
|
|||||
Employee
Benefits and Pension Obligations
|
43,694
|
70,027
|
|||||
Deferred
Credits and Other
|
38,984
|
40,527
|
|||||
TOTAL
|
2,001,812
|
1,963,208
|
|||||
Commitments
and Contingencies (Note 5)
|
|||||||
TOTAL
CAPITALIZATION AND LIABILITIES
|
$
|
4,943,239
|
$
|
4,868,141
|
2005
|
2004
|
||||||
OPERATING
ACTIVITIES
|
|||||||
Net
Income
|
$
|
75,262
|
$
|
70,038
|
|||
Adjustments
to Reconcile Net Income to Net Cash Flows
From
Operating Activities:
|
|||||||
Depreciation
and Amortization
|
84,969
|
85,411
|
|||||
Accretion
Expense
|
23,632
|
19,567
|
|||||
Amortization,
net of Deferrals of Incremental Nuclear
|
|||||||
Refueling
Outage Expenses
|
(758
|
)
|
26,004
|
||||
Deferred
Income Taxes
|
3,476
|
(524
|
)
|
||||
Deferred
Investment Tax Credits
|
(3,664
|
)
|
(3,664
|
)
|
|||
Pension
Contributions
|
(30,701
|
)
|
(972
|
)
|
|||
Mark-to-Market
of Risk Management Contracts
|
(5,598
|
)
|
1,461
|
||||
Change
in Other Noncurrent Assets
|
(246
|
)
|
(1,933
|
)
|
|||
Change
in Other Noncurrent Liabilities
|
(11,947
|
)
|
490
|
||||
Changes
in Components of Working Capital:
|
|||||||
Accounts
Receivable, Net
|
25,058
|
42,682
|
|||||
Fuel,
Materials and Supplies
|
561
|
(9,463
|
)
|
||||
Accounts
Payable
|
(10,161
|
)
|
(22,740
|
)
|
|||
Taxes
Accrued
|
(68,896
|
)
|
44,323
|
||||
Customer
Deposits
|
5,713
|
8,911
|
|||||
Other
Current Assets
|
(7,056
|
)
|
5,542
|
||||
Other
Current Liabilities
|
(12,598
|
)
|
1,861
|
||||
Net
Cash Flows From Operating Activities
|
67,046
|
266,994
|
|||||
INVESTING
ACTIVITIES
|
|||||||
Construction
Expenditures
|
(121,092
|
)
|
(84,363
|
)
|
|||
Change
in Other Cash Deposits, Net
|
46
|
(40
|
)
|
||||
Proceeds
from Sale of Assets
|
9,468
|
-
|
|||||
Net
Cash Flows Used For Investing Activities
|
(111,578
|
)
|
(84,403
|
)
|
|||
FINANCING
ACTIVITIES
|
|||||||
Retirement
of Cumulative Preferred Stock
|
(61,445
|
)
|
(2,000
|
)
|
|||
Retirement
of Long-term Debt
|
-
|
(55,000
|
)
|
||||
Changes
in Advances to/from Affiliates, Net
|
148,219
|
(66,857
|
)
|
||||
Dividends
Paid on Common Stock
|
(42,000
|
)
|
(59,293
|
)
|
|||
Dividends
Paid on Cumulative Preferred Stock
|
(169
|
)
|
(169
|
)
|
|||
Net
Cash Flows From (Used For) Financing Activities
|
44,605
|
(183,319
|
)
|
||||
Net
Increase (Decrease) in Cash and Cash Equivalents
|
73
|
(728
|
)
|
||||
Cash
and Cash Equivalents at Beginning of Period
|
465
|
3,899
|
|||||
Cash
and Cash Equivalents at End of Period
|
$
|
538
|
$
|
3,171
|
SUPPLEMENTAL
DISCLOSURE:
|
Cash
paid for interest net of capitalized amounts was $29,427,000
and
$34,825,000 and for income taxes was $106,891,000 and $189,000
in 2005 and
2004, respectively. Noncash acquisitions under capital leases
were
$652,000 and $1,165,000 in 2005 and 2004, respectively. Construction
Expenditures include the change in construction-related Accounts
Payable
of $(3,272,000) and $(9,365,000) in 2005 and 2004,
respectively.
|
Footnote
Reference
|
|
Significant
Accounting Matters
|
Note
1
|
New
Accounting Pronouncements
|
Note
2
|
Rate
Matters
|
Note
3
|
Commitments
and Contingencies
|
Note
5
|
Guarantees
|
Note
6
|
Benefit
Plans
|
Note
8
|
Business
Segments
|
Note
9
|
Financing
Activities
|
Note
11
|
Company-wide
Staffing and Budget Review
|
Note
12
|
Second
Quarter of 2004 Net Income
|
$
|
4
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins
|
(7
|
)
|
|||||
Off-system
Sales
|
3
|
||||||
Transmission
Revenues
|
(1
|
)
|
|||||
Other
Revenues
|
2
|
||||||
Total
Change in Gross Margin
|
(3
|
)
|
|||||
Total
Change in Operating Expenses and Other
|
-
|
||||||
Income
Tax Expense
|
1
|
||||||
Second
Quarter of 2005 Net Income
|
$
|
2
|
|||||
·
|
Retail
Margins decreased by $7 million in comparison to 2004 primarily
due to a
$5 million increase in capacity settlement payments under the
Interconnection Agreement resulting from our higher MLR share
caused by
the increase in our peak demand established in January 2005.
|
·
|
Margins
from Off-system Sales for 2005 increased by $3 million in comparison
to
2004 primarily due to higher physical sales as well as higher
optimization
activity.
|
·
|
Transmission
Revenues decreased $1 million primarily due to the elimination
of revenues
related to through and out rates, net of replacement SECA rates.
See “FERC
Order on Regional Through and Out Rates” additional discussion of these
FERC rate changes.
|
·
|
Other
Revenues increased $2 million primarily due to a gain on sales
of emission
allowances.
|
Six
Months Ended June 30, 2004 Net Income
|
$
|
16
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins
|
(11
|
)
|
|||||
Off-system
Sales
|
7
|
||||||
Transmission
Revenues
|
(3
|
)
|
|||||
Total
Change in Gross Margin
|
(7
|
)
|
|||||
Total
Change in Operating Expenses and Other
|
-
|
||||||
Income
Tax Expense
|
3
|
||||||
Six
Months Ended June 30, 2005 Net Income
|
$
|
12
|
·
|
Retail
Margins decreased by $11 million in comparison to 2004 primarily
due to a
$9 million increase in capacity settlement payments under the
Interconnection Agreement resulting from our higher MLR share
caused by
the increase in our peak demand established in both December
2004 and
January 2005.
|
·
|
Margins
from Off-system Sales for 2005 increased by $7 million in comparison
to
2004 primarily due to higher physical sales as well as higher
optimization
activity.
|
·
|
Transmission
Revenues decreased $3 million primarily due to the elimination
of revenues
related to through and out rates, net of replacement SECA rates.
|
Moody’s
|
S&P
|
Fitch
|
|||
Senior
Unsecured Debt
|
Baa2
|
BBB
|
BBB
|
Principal
|
Interest
|
Due
|
||||
Type
of Debt
|
Amount
|
Rate
|
Date
|
|||
(in
thousands)
|
(%)
|
|||||
Notes
Payable-Affiliated
|
$20,000
|
6.501
|
2006
|
Total
MTM Risk Management Contract Net Assets at December 31,
2004
|
$
|
12,691
|
||
(Gain)
Loss from Contracts Realized/Settled During the Period (a)
|
(26
|
)
|
||
Fair
Value of New Contracts When Entered During the Period (b)
|
-
|
|||
Net
Option Premiums Paid/(Received) (c)
|
(67
|
)
|
||
Change
in Fair Value Due to Valuation Methodology Changes
|
-
|
|||
Changes
in Fair Value of Risk Management Contracts (d)
|
487
|
|||
Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions (e)
|
1,875
|
|||
Total
MTM Risk Management Contract Net Assets
|
14,960
|
|||
Net
Cash Flow and
Fair Value Hedge
Contracts (f)
|
(2,120
|
)
|
||
DETM
Assignment (g)
|
(4,509
|
)
|
||
Total
MTM Risk Management Contract Net Assets at June 30, 2005
|
$
|
8,331
|
(a)
|
“(Gain)
Loss from Contracts Realized/Settled During the Period” includes realized
risk management contracts and related derivatives that settled
during 2005
where
we entered into the contract prior
to 2005.
|
(b)
|
“Fair
Value of New Contracts When Entered During the Period” represents the fair
value at inception of long-term contracts entered into with
customers
during 2005. Most of the fair value comes from longer term
fixed price
contracts with customers that seek to limit their risk against
fluctuating
energy prices. Inception value is only recorded if observable
market data
can be obtained for valuation inputs for the entire contract
term. The
contract prices are valued against market curves associated
with the
delivery location and delivery term.
|
(c)
|
“Net
Option Premiums Paid/(Received)” reflects the net option premiums
paid/(received) as they relate to unexercised and unexpired
option
contracts that were entered in 2005.
|
(d)
|
“Changes
in Fair Value of Risk Management Contracts” represents the fair value
change in the risk management portfolio due to market fluctuations
during
the current period. Market fluctuations are attributable to
various
factors such as supply/demand, weather, storage, etc.
|
(e)
|
“Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions” relates to the net gains (losses) of those contracts that
are not reflected in the Condensed Statements of Income. These
net gains
(losses) are recorded as regulatory assets/liabilities
for
those subsidiaries that operate in regulated
jurisdictions.
|
(f)
|
“Net
Cash Flow and
Fair Value Hedge
Contracts” (pretax) are discussed below in Accumulated Other Comprehensive
Income (Loss).
|
(g)
|
See
“Natural Gas Contracts with DETM” section in Note 17 of the 2004 Annual
Report.
|
MTM
Risk Management Contracts (a)
|
Hedges
|
DETM
Assignment (b)
|
Total
(c)
|
||||||||||
Current
Assets
|
$
|
21,769
|
$
|
211
|
$
|
-
|
$
|
21,980
|
|||||
Noncurrent
Assets
|
39,105
|
24
|
-
|
39,129
|
|||||||||
Total
MTM Derivative Contract Assets
|
60,874
|
235
|
-
|
61,109
|
|||||||||
Current
Liabilities
|
(20,035
|
)
|
(2,010
|
)
|
(1,517
|
)
|
(23,562
|
)
|
|||||
Noncurrent
Liabilities
|
(25,879
|
)
|
(345
|
)
|
(2,992
|
)
|
(29,216
|
)
|
|||||
Total
MTM Derivative Contract Liabilities
|
(45,914
|
)
|
(2,355
|
)
|
(4,509
|
)
|
(52,778
|
)
|
|||||
Total
MTM Derivative Contract Net
Assets (Liabilities)
|
$
|
14,960
|
$
|
(2,120
|
)
|
$
|
(4,509
|
)
|
$
|
8,331
|
(a)
|
Does
not include Cash Flow and Fair Value Hedges.
|
(b)
|
See
“Natural Gas Contracts with DETM” section in Note 17 of the 2004 Annual
Report.
|
(c)
|
Represents
amount of total MTM derivative contracts recorded within Risk
Management
Assets, Long-term Risk Management Assets, Risk Management Liabilities
and
Long-term Risk Management Liabilities on our Condensed Balance
Sheets.
|
·
|
The
source of fair value used in determining the carrying amount
of our total
MTM asset or liability (external sources or modeled
internally).
|
·
|
The
maturity, by year, of our net assets/liabilities, giving an
indication of
when these MTM amounts will settle and generate
cash.
|
Remainder
of 2005
|
2006
|
2007
|
2008
|
2009
|
After
2009
(c)
|
Total
(d)
|
||||||||||||||||
Prices
Actively Quoted - Exchange Traded
Contracts
|
$
|
(2,510
|
)
|
$
|
(20
|
)
|
$
|
1,990
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
(540
|
)
|
|||||
Prices
Provided by Other External Sources
- OTC
Broker Quotes (a)
|
5,442
|
7,832
|
2,733
|
2,794
|
-
|
-
|
18,801
|
|||||||||||||||
Prices
Based on Models and Other Valuation
Methods (b)
|
(2,785
|
)
|
(4,045
|
)
|
(1,127
|
)
|
375
|
2,372
|
1,909
|
(3,301
|
)
|
|||||||||||
Total
|
$
|
147
|
$
|
3,767
|
$
|
3,596
|
$
|
3,169
|
$
|
2,372
|
$
|
1,909
|
$
|
14,960
|
(a)
|
“Prices
Provided by Other External Sources - OTC Broker Quotes” reflects
information obtained from over-the-counter brokers, industry
services, or
multiple-party on-line platforms.
|
(b)
|
“Prices
Based on Models and Other Valuation Methods” is in absence of pricing
information from external sources. Modeled information is derived
using
valuation models developed by the reporting entity, reflecting
when
appropriate, option pricing theory, discounted cash flow concepts,
valuation adjustments, etc. and may require projection of prices
for
underlying commodities beyond the period that prices are available
from
third-party sources. In addition, where external pricing information
or
market liquidity are limited, such valuations are classified
as modeled.
The determination of the point at which a market is no longer
liquid for
placing it in the modeled category varies by market.
|
(c)
|
There
is mark-to-market value in excess of 10 percent of our total
mark-to-market value in individual periods beyond 2009. $2.0
million of
this mark-to-market value is in 2010.
|
(d)
|
Amounts
exclude Cash Flow and Fair Value
Hedges.
|
Power
|
Interest
Rate
|
Total
|
||||||||
Beginning
Balance December 31, 2004
|
$
|
569
|
$
|
244
|
$
|
813
|
||||
Changes
in Fair Value (a)
|
(876
|
)
|
-
|
(876
|
)
|
|||||
Reclassifications
from AOCI to Net
Income
(b)
|
(1,037
|
)
|
(43
|
)
|
(1,080
|
)
|
||||
Ending
Balance June 30, 2005
|
$
|
(1,344
|
)
|
$
|
201
|
$
|
(1,143
|
)
|
(a)
|
“Changes
in Fair Value” shows changes in the fair value of derivatives designated
as cash flow hedges during the reporting period that are not
yet settled
at June 30, 2005. Amounts are reported net of related income
taxes.
|
(b)
|
“Reclassifications
from AOCI to Net Income” represents gains or losses from derivatives used
as hedging instruments in cash flow hedges that were reclassified
into net
income during the reporting period. Amounts are reported net
of related
income taxes.
|
Six
Months Ended
|
Twelve
Months Ended
|
|||||||||||||||
June
30, 2005
|
December
31, 2004
|
|||||||||||||||
(in
thousands)
|
(in
thousands)
|
|||||||||||||||
End
|
High
|
Average
|
Low
|
End
|
High
|
Average
|
Low
|
|||||||||
$277
|
$331
|
$162
|
$95
|
$135
|
$442
|
$191
|
$65
|
Three
Months Ended
|
Six
Months Ended
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
OPERATING
REVENUES
|
|||||||||||||
Electric
Generation, Transmission and Distribution
|
$
|
109,294
|
$
|
94,380
|
$
|
224,954
|
$
|
201,426
|
|||||
Sales
to AEP Affiliates
|
13,007
|
12,373
|
25,196
|
18,985
|
|||||||||
TOTAL
|
122,301
|
106,753
|
250,150
|
220,411
|
|||||||||
OPERATING
EXPENSES
|
|||||||||||||
Fuel
for Electric Generation
|
30,692
|
25,224
|
58,584
|
46,118
|
|||||||||
Purchased
Electricity for Resale
|
44,796
|
31,817
|
89,659
|
65,123
|
|||||||||
Other
Operation
|
15,417
|
13,499
|
29,977
|
26,771
|
|||||||||
Maintenance
|
8,482
|
10,214
|
14,398
|
17,539
|
|||||||||
Depreciation
and Amortization
|
11,225
|
10,905
|
22,377
|
21,764
|
|||||||||
Taxes
Other Than Income Taxes
|
2,219
|
2,395
|
4,644
|
4,723
|
|||||||||
Income
Taxes
|
279
|
1,094
|
4,287
|
7,554
|
|||||||||
TOTAL
|
113,110
|
95,148
|
223,926
|
189,592
|
|||||||||
OPERATING
INCOME
|
9,191
|
11,605
|
26,224
|
30,819
|
|||||||||
Nonoperating
Income
|
621
|
482
|
1,066
|
1,434
|
|||||||||
Nonoperating
Expenses
|
141
|
274
|
312
|
1,587
|
|||||||||
Nonoperating
Income Tax Expense (Credit)
|
157
|
33
|
209
|
(94
|
)
|
||||||||
Interest
Charges
|
7,068
|
7,712
|
14,438
|
15,081
|
|||||||||
NET
INCOME
|
$
|
2,446
|
$
|
4,068
|
$
|
12,331
|
$
|
15,679
|
Common
Stock
|
Paid-in
Capital
|
Retained
Earnings
|
Accumulated
Other Comprehensive Income (Loss)
|
Total
|
||||||||||||
DECEMBER
31, 2003
|
$
|
50,450
|
$
|
208,750
|
$
|
64,151
|
$
|
(6,213
|
)
|
$
|
317,138
|
|||||
Common
Stock Dividends
|
(12,500
|
)
|
(12,500
|
)
|
||||||||||||
TOTAL
|
304,638
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $518
|
(962
|
)
|
(962
|
)
|
||||||||||||
NET
INCOME
|
15,679
|
15,679
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
14,717
|
|||||||||||||||
JUNE
30, 2004
|
$
|
50,450
|
$
|
208,750
|
$
|
67,330
|
$
|
(7,175
|
)
|
$
|
319,355
|
|||||
DECEMBER
31, 2004
|
$
|
50,450
|
$
|
208,750
|
$
|
70,555
|
$
|
(8,775
|
)
|
$
|
320,980
|
|||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $1,053
|
(1,956
|
)
|
(1,956
|
)
|
||||||||||||
NET
INCOME
|
12,331
|
12,331
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
10,375
|
|||||||||||||||
JUNE
30, 2005
|
$
|
50,450
|
$
|
208,750
|
$
|
82,886
|
$
|
(10,731
|
)
|
$
|
331,355
|
2005
|
2004
|
||||||
ELECTRIC
UTILITY PLANT
|
|||||||
Production
|
$
|
466,370
|
$
|
462,641
|
|||
Transmission
|
387,910
|
385,667
|
|||||
Distribution
|
446,449
|
438,766
|
|||||
General
|
59,475
|
57,929
|
|||||
Construction
Work in Progress
|
19,336
|
16,544
|
|||||
Total
|
1,379,540
|
1,361,547
|
|||||
Accumulated
Depreciation and Amortization
|
414,048
|
398,455
|
|||||
TOTAL
- NET
|
965,492
|
963,092
|
|||||
OTHER
PROPERTY AND INVESTMENTS
|
|||||||
Nonutility
Property, Net
|
5,434
|
5,438
|
|||||
Other
Investments
|
351
|
422
|
|||||
TOTAL
|
5,785
|
5,860
|
|||||
CURRENT
ASSETS
|
|||||||
Cash
and Cash Equivalents
|
237
|
127
|
|||||
Other
Cash Deposits
|
11
|
5
|
|||||
Advances
to Affiliates
|
12,647
|
16,127
|
|||||
Accounts
Receivable:
|
|||||||
Customers
|
23,885
|
22,130
|
|||||
Affiliated
Companies
|
18,314
|
23,046
|
|||||
Accrued
Unbilled Revenues
|
2,620
|
7,340
|
|||||
Miscellaneous
|
106
|
94
|
|||||
Allowance
for Uncollectible Accounts
|
(2
|
)
|
(34
|
)
|
|||
Fuel
|
10,663
|
6,551
|
|||||
Materials
and Supplies
|
8,103
|
9,385
|
|||||
Risk
Management Assets
|
21,980
|
19,845
|
|||||
Margin
Deposits
|
3,148
|
1,960
|
|||||
Prepayments
and Other
|
4,014
|
1,782
|
|||||
TOTAL
|
105,726
|
108,358
|
|||||
DEFERRED
DEBITS AND OTHER ASSETS
|
|||||||
Regulatory
Assets:
|
|||||||
SFAS
109 Regulatory Asset, Net
|
101,714
|
103,849
|
|||||
Other
|
23,163
|
14,558
|
|||||
Long-term
Risk Management Assets
|
39,129
|
19,067
|
|||||
Emission
Allowances
|
12,077
|
9,666
|
|||||
Deferred
Property Taxes
|
3,605
|
7,036
|
|||||
Deferred
Charges and Other
|
7,848
|
11,761
|
|||||
TOTAL
|
187,536
|
165,937
|
|||||
TOTAL
ASSETS
|
$
|
1,264,539
|
$
|
1,243,247
|
2005
|
2004
|
||||||
CAPITALIZATION
|
(in
thousands)
|
||||||
Common
Shareholder’s Equity:
|
|||||||
Common
Stock - $50 par value per share:
|
|||||||
Authorized
- 2,000,000 shares
|
|||||||
Outstanding
- 1,009,000 shares
|
$
|
50,450
|
$
|
50,450
|
|||
Paid-in
Capital
|
208,750
|
208,750
|
|||||
Retained
Earnings
|
82,886
|
70,555
|
|||||
Accumulated
Other Comprehensive Income (Loss)
|
(10,731
|
)
|
(8,775
|
)
|
|||
Total
Common Shareholder’s Equity
|
331,355
|
320,980
|
|||||
Long-term
Debt:
|
|||||||
Nonaffiliated
|
427,716
|
428,310
|
|||||
Affiliated
|
20,000
|
80,000
|
|||||
Total
Long-term Debt
|
447,716
|
508,310
|
|||||
TOTAL
|
779,071
|
829,290
|
|||||
CURRENT
LIABILITIES
|
|||||||
Long-term
Debt Due Within One Year - Affiliated
|
40,000
|
-
|
|||||
Accounts
Payable:
|
|||||||
General
|
30,311
|
20,080
|
|||||
Affiliated
Companies
|
24,766
|
24,899
|
|||||
Risk
Management Liabilities
|
23,562
|
17,205
|
|||||
Taxes
Accrued
|
7,717
|
9,248
|
|||||
Interest
Accrued
|
6,795
|
6,754
|
|||||
Customer
Deposits
|
16,304
|
12,309
|
|||||
Obligations
Under Capital Leases
|
1,356
|
1,561
|
|||||
Other
|
7,505
|
9,038
|
|||||
TOTAL
|
158,316
|
101,094
|
|||||
DEFERRED
CREDITS AND OTHER LIABILITIES
|
|||||||
Deferred
Income Taxes
|
226,829
|
227,536
|
|||||
Regulatory
Liabilities:
|
|||||||
Asset
Removal Costs
|
29,441
|
28,232
|
|||||
Deferred
Investment Tax Credits
|
6,137
|
6,722
|
|||||
Other
Regulatory Liabilities
|
20,464
|
15,622
|
|||||
Employee
Benefits and Pension Obligations
|
12,198
|
17,729
|
|||||
Long-term
Risk Management Liabilities
|
29,216
|
13,484
|
|||||
Obligations
Under Capital Leases
|
2,366
|
2,802
|
|||||
Deferred
Credits
|
501
|
736
|
|||||
TOTAL
|
327,152
|
312,863
|
|||||
Commitments
and Contingencies (Note 5)
|
|||||||
TOTAL
CAPITALIZATION
AND LIABILITIES
|
$
|
1,264,539
|
$
|
1,243,247
|
2005
|
2004
|
||||||
OPERATING
ACTIVITIES
|
|||||||
Net
Income
|
$
|
12,331
|
$
|
15,679
|
|||
Adjustments
to Reconcile Net Income to Net Cash Flows
From
Operating Activities:
|
|||||||
Depreciation
and Amortization
|
22,377
|
21,764
|
|||||
Deferred
Income Taxes
|
2,482
|
4,616
|
|||||
Deferred
Investment Tax Credits
|
(585
|
)
|
(585
|
)
|
|||
Deferred
Property Taxes
|
3,431
|
3,336
|
|||||
Pension
Contributions
|
(6,092
|
)
|
(113
|
)
|
|||
Pension
and Postemployment Benefit Reserves
|
561
|
(814
|
)
|
||||
Mark-to-Market
of Risk Management Contracts
|
(3,330
|
)
|
1,064
|
||||
Over/Under
Fuel Recovery
|
(7,181
|
)
|
(1,514
|
)
|
|||
(Gain)/Loss
on Sale of Assets
|
(8
|
)
|
1,051
|
||||
Change
in Other Noncurrent Assets
|
(731
|
)
|
(8,360
|
)
|
|||
Change
in Other Noncurrent Liabilities
|
3,725
|
9,035
|
|||||
Changes
in Components of Working Capital:
|
|||||||
Accounts
Receivable, Net
|
7,653
|
3,774
|
|||||
Fuel,
Materials and Supplies
|
(2,830
|
)
|
(2,398
|
)
|
|||
Accounts
Payable
|
10,960
|
(2,173
|
)
|
||||
Taxes
Accrued
|
(1,531
|
)
|
3,670
|
||||
Customer
Deposits
|
3,995
|
2,777
|
|||||
Interest
Accrued
|
41
|
(132
|
)
|
||||
Other
Current Assets
|
(3,421
|
)
|
1,430
|
||||
Other
Current Liabilities
|
(1,736
|
)
|
(737
|
)
|
|||
Net
Cash Flows From Operating Activities
|
40,111
|
51,370
|
|||||
INVESTING
ACTIVITIES
|
|||||||
Construction
Expenditures
|
(23,484
|
)
|
(18,964
|
)
|
|||
Change
in Other Cash Deposits, Net
|
(6
|
)
|
6
|
||||
Proceeds
from Sale of Assets
|
9
|
1,538
|
|||||
Net
Cash Flows Used For Investing Activities
|
(23,481
|
)
|
(17,420
|
)
|
|||
FINANCING
ACTIVITIES
|
|||||||
Issuance
of Long-term Debt - Affiliated
|
-
|
20,000
|
|||||
Retirement
of Long-term Debt - Affiliated
|
(20,000
|
)
|
-
|
||||
Changes
in Advances to/from Affiliates, Net
|
3,480
|
(41,618
|
)
|
||||
Dividends
Paid on Common Stock
|
-
|
(12,500
|
)
|
||||
Net
Cash Flows Used For Financing Activities
|
(16,520
|
)
|
(34,118
|
)
|
|||
Net
Increase (Decrease) in Cash and Cash Equivalents
|
110
|
(168
|
)
|
||||
Cash
and Cash Equivalents at Beginning of Period
|
127
|
863
|
|||||
Cash
and Cash Equivalents at End of Period
|
$
|
237
|
$
|
695
|
SUPPLEMENTAL
DISCLOSURE:
|
Cash
paid for interest net of capitalized amounts was $13,942,000
and
$14,625,000 and for income taxes was $3,761,000 and $658,000
in 2005 and
2004, respectively. Noncash capital lease acquisitions in 2005
and 2004
were $230,000 and $387,000, respectively. Construction Expenditures
include the change in construction-related Accounts Payable
of $(862,000)
and $(984,000) in 2005 and 2004,
respectively.
|
Footnote
Reference
|
|
Significant
Accounting Matters
|
Note
1
|
New
Accounting Pronouncements
|
Note
2
|
Rate
Matters
|
Note
3
|
Commitments
and Contingencies
|
Note
5
|
Guarantees
|
Note
6
|
Benefit
Plans
|
Note
8
|
Business
Segments
|
Note
9
|
Financing
Activities
|
Note
11
|
Company-wide
Staffing and Budget Review
|
Note
12
|
Second
Quarter of 2004 Net Income
|
$
|
39
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins
|
36
|
||||||
Transmission
Revenues
|
(6
|
)
|
|||||
Off-system
Sales
|
6
|
||||||
Other
Revenues
|
2
|
||||||
Total
Change in Gross Margin
|
38
|
||||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
8
|
||||||
Depreciation
and Amortization
|
(9
|
)
|
|||||
Nonoperating
Income and Expenses, Net
|
6
|
||||||
Interest
Charges
|
5
|
||||||
Total
Change in Operating Expenses and Other
|
10
|
||||||
Income
Tax Expense
|
(16
|
)
|
|||||
Second
Quarter of 2005 Net Income
|
$
|
71
|
·
|
Retail
Margins were $36 million higher than the prior period primarily
due
to:
|
|
-
|
a
favorable variance of $16 million from the receipt of SO2
allowances from Buckeye Power, Inc. under the Cardinal Station
Allowance
Agreement,
|
|
-
|
increased
retail sales of $17 million due to increased industrial and
residential
sales from higher usage
|
|
-
|
and
an increase of $8 million from capacity settlements under
the
Interconnection Agreement related to the increase in an affiliate’s
peak,
|
|
-
|
partially
offset by decreased fuel margins of $5 million as a result
of increased
fuel costs.
|
|
·
|
Transmission
Revenues decreased $6 million primarily due to the loss of
through and out
rates, net of replacement SECA rates. See “FERC Order on Regional Through
and Out Rates” for additional discussion of these FERC rate
changes.
|
|
·
|
Margins
from Off-system Sales increased $6 million primarily due
to favorable
price margins.
|
·
|
Depreciation
and Amortization expense increased $9 million primarily due
to the
establishment of a $7 million regulatory liability to benefit
low income
customers and for economic development, as ordered in the rate
stabilization plan.
|
·
|
Other
Operation and Maintenance expenses decreased $8 million primarily
due to
$4 million of expenses from the 2004 Amos Plant outage and
$3 million of
expenses related to major storms in the second quarter of
2004.
|
·
|
Nonoperating
Income and Expenses, Net increased $6 million primarily due
to the
establishment of a regulatory asset for carrying costs on environmental
capital expenditures as a result of the rate stabilization
plan
order.
|
·
|
Interest
Charges decreased by $5 million primarily due to capitalized
interest
related to construction of the Mitchell and Cardinal plant
scrubbers and
the Mitchell plant Selective Catalytic Reduction (SCR) project
that began
after June 2004 in addition to refinancing debt maturities
and optional
redemptions with lower cost debt.
|
Six
Months Ended June 30, 2004 Net Income
|
$
|
119
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins
|
29
|
||||||
Transmission
Revenues
|
(13
|
)
|
|||||
Off-system
Sales
|
11
|
||||||
Other
Revenues
|
2
|
||||||
Total
Change in Gross Margin
|
29
|
||||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
14
|
||||||
Depreciation
and Amortization
|
(11
|
)
|
|||||
Nonoperating
Income and Expenses, Net
|
29
|
||||||
Interest
Charges
|
11
|
||||||
Total
Change in Operating Expenses and Other
|
43
|
||||||
Income
Tax Expense
|
(20
|
)
|
|||||
Six
Months Ended June 30, 2005 Net Income
|
$
|
171
|
·
|
Retail
Margins were $29 million higher than the prior period primarily
due
to:
|
|
-
|
a
favorable variance of $18 million from the receipt of SO2
allowances from Buckeye Power, Inc. under the Cardinal Station
Allowance
Agreement,
|
|
-
|
increased
retail sales of $16 million due to increased industrial and
residential
sales from higher usage
|
|
-
|
and
an increase of $11 million from capacity settlements under
the
Interconnection Agreement related to the increase in an affiliate’s
peak,
|
|
-
|
partially
offset by decreased fuel margins of $16 million as a result
of increased
fuel costs.
|
|
·
|
Transmission
Revenues decreased $13 million primarily due to the loss
of through and
out rates, net of replacement SECA rates. See “FERC Order on Regional
Through and Out Rates” for additional discussion of these FERC rate
changes.
|
|
·
|
Margins
from Off-system Sales increased $11 million primarily due
to favorable
price margins.
|
·
|
Nonoperating
Income and Expenses, Net increased $29 million primarily due
to the
establishment of a regulatory asset for carrying costs on environmental
capital expenditures as a result of the rate stabilization
plan
order.
|
·
|
Other
Operation and Maintenance expenses decreased $14 million primarily
due to
the settlement and cancellation of the COLI policy of $7 million
in
February 2005 and a decrease in administrative expenses of
$7 million
related to the Gavin scrubber.
|
·
|
Interest
Charges decreased by $11 million primarily due to capitalized
interest
related to construction of the Mitchell and Cardinal plant
scrubbers and
the Mitchell plant SCR project that began after June 2004.
Interest
Charges also decreased due to refinancing debt maturities and
optional
redemptions with lower cost debt.
|
·
|
Depreciation
and Amortization expense increased $11 million due to the establishment
of
a $7 million regulatory liability to benefit low income customers
and for
economic development, as ordered in the rate stabilization
plan. The
increase is also attributable to a higher depreciation base
in electric
utility plants.
|
Moody’s
|
S&P
|
Fitch
|
|||
Senior
Unsecured Debt
|
A3
|
BBB
|
BBB+
|
2005
|
2004
|
||||||
(in
thousands)
|
|||||||
Cash
and Cash Equivalents at Beginning of Period
|
$
|
9,300
|
$
|
7,233
|
|||
Cash
Flows From (Used For):
|
|||||||
Operating
Activities
|
182,835
|
303,385
|
|||||
Investing
Activities
|
(288,713
|
)
|
(78,441
|
)
|
|||
Financing
Activities
|
97,931
|
(225,783
|
)
|
||||
Net
Decrease in Cash and Cash Equivalents
|
(7,947
|
)
|
(839
|
)
|
|||
Cash
and Cash Equivalents at End of Period
|
$
|
1,353
|
$
|
6,394
|
Principal
|
Interest
|
Due
|
||||||||
Type
of Debt
|
Amount
|
Rate
|
Date
|
|||||||
(in
thousands)
|
(%)
|
|||||||||
Installment
Purchase Contracts
|
$
|
54,500
|
Variable
|
2029
|
||||||
Installment
Purchase Contracts
|
54,500
|
Variable
|
2028
|
|||||||
Installment
Purchase Contracts
|
54,500
|
Variable
|
2028
|
|||||||
Installment
Purchase Contracts
|
54,500
|
Variable
|
2028
|
Principal
|
Interest
|
Due
|
||||||||
Type
of Debt
|
Amount
|
Rate
|
Date
|
|||||||
(in
thousands)
|
(%)
|
|||||||||
Installment
Purchase Contracts
|
$
|
51,000
|
6.375
|
2029
|
||||||
Installment
Purchase Contracts
|
51,000
|
6.375
|
2029
|
|||||||
Installment
Purchase Contracts
|
40,000
|
Variable
|
2028
|
|||||||
Installment
Purchase Contracts
|
40,000
|
Variable
|
2028
|
|||||||
Installment
Purchase Contracts
|
18,000
|
Variable
|
2029
|
|||||||
Installment
Purchase Contracts
|
18,000
|
Variable
|
2029
|
|||||||
Notes
Payable
|
2,927
|
6.81
|
2008
|
|||||||
Notes
Payable
|
3,250
|
6.27
|
2009
|
Total
MTM Risk Management Contract Net Assets at December 31,
2004
|
$
|
47,777
|
||
(Gain)
Loss from Contracts Realized/Settled During the Period (a)
|
(13,297
|
)
|
||
Fair
Value of New Contracts When Entered During the Period (b)
|
835
|
|||
Net
Option Premiums Paid/(Received) (c)
|
(372
|
)
|
||
Change
in Fair Value Due to Valuation Methodology Changes
|
-
|
|||
Changes
in Fair Value of Risk Management Contracts (d)
|
9,576
|
|||
Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions (e)
|
-
|
|||
Total
MTM Risk Management Contract Net Assets
|
44,519
|
|||
Net
Cash Flow Hedge Contracts (f)
|
(8,836
|
)
|
||
DETM
Assignment (g)
|
(13,536
|
)
|
||
Total
MTM Risk Management Contract Net Assets at June 30, 2005
|
$
|
22,147
|
(a)
|
“(Gain)
Loss from Contracts Realized/Settled During the Period” includes realized
risk management contracts and related derivatives that settled
during 2005
where
we entered into the contract prior
to 2005.
|
(b)
|
“Fair
Value of New Contracts When Entered During the Period” represents the fair
value at inception of long-term contracts entered into with
customers
during 2005. Most of the fair value comes from longer term
fixed price
contracts with customers that seek to limit their risk against
fluctuating
energy prices. Inception value is only recorded if observable
market data
can be obtained for valuation inputs for the entire contract
term. The
contract prices are valued against market curves associated
with the
delivery location and delivery term.
|
(c)
|
“Net
Option Premiums Paid/(Received)” reflects the net option premiums
paid/(received) as they relate to unexercised and unexpired
option
contracts that were entered in 2005.
|
(d)
|
“Changes
in Fair Value of Risk Management Contracts” represents the fair value
change in the risk management portfolio due to market fluctuations
during
the current period. Market fluctuations are attributable to
various
factors such as supply/demand, weather, storage, etc.
|
(e)
|
“Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions” relates to the net gains (losses) of those contracts that
are not reflected in the Condensed Consolidated Statements
of Income.
These net gains (losses) are recorded as regulatory assets/liabilities
for
those subsidiaries that operate in regulated
jurisdictions.
|
(f)
|
“Net
Cash Flow Hedge Contracts” (pretax) are discussed below in Accumulated
Other Comprehensive Income (Loss).
|
(g)
|
See
“Natural Gas Contracts with DETM” section in Note 17 of the 2004 Annual
Report.
|
MTM
Risk Management Contracts (a)
|
Cash
Flow
Hedges
|
DETM
Assignment
(b)
|
Total
(c)
|
|||||||||||
Current
Assets
|
$
|
73,367
|
$
|
669
|
$
|
-
|
$
|
74,036
|
||||||
Noncurrent
Assets
|
119,965
|
72
|
-
|
120,037
|
||||||||||
Total
MTM Derivative Contract Assets
|
193,332
|
741
|
-
|
194,073
|
||||||||||
Current
Liabilities
|
(67,887
|
)
|
(9,007
|
)
|
(4,554
|
)
|
(81,448
|
)
|
||||||
Noncurrent
Liabilities
|
(80,926
|
)
|
(570
|
)
|
(8,982
|
)
|
(90,478
|
)
|
||||||
Total MTM Derivative Contract Liabilities |
(148,813
|
)
|
(9,577
|
)
|
(13,536
|
)
|
(171,926
|
)
|
||||||
Total MTM Derivative Contract Net Assets (Liabilities) | $ | 44,519 | $ | (8,836 | ) | $ |
(13,536
|
) | $ |
22,147
|
(a)
|
Does
not include Cash Flow Hedges.
|
(b)
|
See
“Natural Gas Contracts with DETM” section in Note 17 of the 2004 Annual
Report.
|
(c)
|
Represents
amount of total MTM derivative contracts recorded within Risk
Management
Assets, Long-term Risk Management Assets, Risk Management Liabilities
and
Long-term Risk Management Liabilities on our Condensed Consolidated
Balance Sheets.
|
·
|
The
source of fair value used in determining the carrying amount
of our total
MTM asset or liability (external sources or modeled
internally).
|
·
|
The
maturity, by year, of our net assets/liabilities, giving an
indication of
when these MTM amounts will settle and generate
cash.
|
Remainder
of 2005
|
2006
|
2007
|
2008
|
2009
|
After
2009
(c)
|
Total
(d)
|
||||||||||||||||
Prices
Actively Quoted - Exchange Traded
Contracts
|
$
|
(7,535
|
)
|
$
|
(61
|
)
|
$
|
5,975
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
(1,621
|
)
|
|||||
Prices
Provided by Other External Sources
- OTC Broker Quotes (a)
|
17,902
|
22,301
|
8,397
|
8,390
|
-
|
-
|
56,990
|
|||||||||||||||
Prices
Based on Models and Other Valuation
Methods (b)
|
(8,485
|
)
|
(12,533
|
)
|
(3,813
|
)
|
1,126
|
7,124
|
5,731
|
(10,850
|
)
|
|||||||||||
Total
|
$
|
1,882
|
$
|
9,707
|
$
|
10,559
|
$
|
9,516
|
$
|
7,124
|
$
|
5,731
|
$
|
44,519
|
(a)
|
“Prices
Provided by Other External Sources - OTC Broker Quotes” reflects
information obtained from over-the-counter brokers, industry
services, or
multiple-party on-line platforms.
|
(b)
|
“Prices
Based on Models and Other Valuation Methods” is in absence of pricing
information from external sources. Modeled information is derived
using
valuation models developed by the reporting entity, reflecting
when
appropriate, option pricing theory, discounted cash flow concepts,
valuation adjustments, etc. and may require projection of prices
for
underlying commodities beyond the period that prices are available
from
third-party sources. In addition, where external pricing information
or
market liquidity are limited, such valuations are classified
as modeled.
The determination of the point at which a market is no longer
liquid for
placing it in the modeled category varies by market.
|
(c)
|
There
is mark-to-market value in excess of 10 percent of our total
mark-to-market value in individual periods beyond 2009. $6.1
million of
this mark-to-market value is in 2010.
|
(d)
|
Amounts
exclude Cash Flow Hedges.
|
Power
|
Interest
Rate
|
Foreign
Currency
|
Total
|
||||||||||
Beginning
Balance December 31, 2004
|
$
|
1,599
|
$
|
-
|
$
|
(358
|
)
|
$
|
1,241
|
||||
Changes
in Fair Value (a)
|
(3,130
|
)
|
(1,001
|
)
|
-
|
(4,131
|
)
|
||||||
Reclassifications
from AOCI to Net Income
(b)
|
(2,975
|
)
|
-
|
7
|
(2,968
|
)
|
|||||||
Ending
Balance June 30, 2005
|
$
|
(4,506
|
)
|
$
|
(1,001
|
)
|
$
|
(351
|
)
|
$
|
(5,858
|
)
|
(a)
|
“Changes
in Fair Value” shows changes in the fair value of derivatives designated
as cash flow hedges during the reporting period that are not
yet settled
at June 30, 2005. Amounts are reported net of related income
taxes.
|
(b)
|
“Reclassifications
from AOCI to Net Income” represents gains or losses from derivatives used
as hedging instruments in cash flow hedges that were reclassified
into net
income during the reporting period. Amounts are reported net
of related
income taxes above.
|
Six
Months Ended
|
Twelve
Months Ended
|
|||||||||||||||
June
30, 2005
|
December
31, 2004
|
|||||||||||||||
(in
thousands)
|
(in
thousands)
|
|||||||||||||||
End
|
High
|
Average
|
Low
|
End
|
High
|
Average
|
Low
|
|||||||||
$831
|
$994
|
$485
|
$285
|
$464
|
$1,513
|
$652
|
$223
|
Three
Months Ended
|
Six
Months Ended
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
OPERATING
REVENUES
|
|||||||||||||
Electric
Generation, Transmission and Distribution
|
$
|
450,122
|
$
|
399,535
|
$
|
906,353
|
$
|
843,264
|
|||||
Sales
to AEP Affiliates
|
156,607
|
135,413
|
308,446
|
281,901
|
|||||||||
TOTAL
|
606,729
|
534,948
|
1,214,799
|
1,125,165
|
|||||||||
OPERATING
EXPENSES
|
|||||||||||||
Fuel
for Electric Generation
|
168,693
|
145,503
|
348,954
|
311,774
|
|||||||||
Purchased
Electricity for Resale
|
22,423
|
14,155
|
41,185
|
26,338
|
|||||||||
Purchased
Electricity from AEP Affiliates
|
25,093
|
23,169
|
50,711
|
42,472
|
|||||||||
Other
Operation
|
92,950
|
96,224
|
166,733
|
187,320
|
|||||||||
Maintenance
|
51,355
|
56,733
|
97,110
|
90,784
|
|||||||||
Depreciation
and Amortization
|
79,941
|
70,388
|
153,888
|
142,170
|
|||||||||
Taxes
Other Than Income Taxes
|
43,686
|
43,646
|
90,828
|
90,836
|
|||||||||
Income
Taxes
|
32,064
|
22,220
|
70,635
|
62,202
|
|||||||||
TOTAL
|
516,205
|
472,038
|
1,020,044
|
953,896
|
|||||||||
OPERATING
INCOME
|
90,524
|
62,910
|
194,755
|
171,269
|
|||||||||
Nonoperating
Income
|
50,231
|
52,704
|
105,203
|
69,455
|
|||||||||
Carrying
Costs Income
|
7,511
|
178
|
29,548
|
357
|
|||||||||
Nonoperating
Expenses
|
48,027
|
49,231
|
93,054
|
57,300
|
|||||||||
Nonoperating
Income Tax Expense (Credit)
|
2,920
|
(3,120
|
)
|
13,487
|
1,967
|
||||||||
Interest
Charges
|
25,838
|
30,898
|
52,001
|
62,867
|
|||||||||
NET
INCOME
|
71,481
|
38,783
|
170,964
|
118,947
|
|||||||||
Preferred
Stock Dividend Requirements (Including Other
Expense)
|
357
|
183
|
540
|
366
|
|||||||||
EARNINGS
APPLICABLE TO COMMON STOCK
|
$
|
71,124
|
$
|
38,600
|
$
|
170,424
|
$
|
118,581
|
Common
Stock
|
Paid-in
Capital
|
Retained
Earnings
|
Accumulated
Other Comprehensive Income (Loss)
|
Total
|
||||||||||||
DECEMBER
31, 2003
|
$
|
321,201
|
$
|
462,484
|
$
|
729,147
|
$
|
(48,807
|
)
|
$
|
1,464,025
|
|||||
Common
Stock Dividends
|
(114,115
|
)
|
(114,115
|
)
|
||||||||||||
Preferred
Stock Dividends
|
(366
|
)
|
(366
|
)
|
||||||||||||
TOTAL
|
1,349,544
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $1,746
|
(3,242
|
)
|
(3,242
|
)
|
||||||||||||
Minimum
Pension Liability, Net of Tax of $2,123
|
(3,942
|
)
|
(3,942
|
)
|
||||||||||||
NET
INCOME
|
118,947
|
118,947
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
111,763
|
|||||||||||||||
JUNE
30, 2004
|
$
|
321,201
|
$
|
462,484
|
$
|
733,613
|
$
|
(55,991
|
)
|
$
|
1,461,307
|
|||||
DECEMBER
31, 2004
|
$
|
321,201
|
$
|
462,485
|
$
|
764,416
|
$
|
(74,264
|
)
|
$
|
1,473,838
|
|||||
Common
Stock Dividends
|
(14,999
|
)
|
(14,999
|
)
|
||||||||||||
Preferred
Stock Dividends
|
(366
|
)
|
(366
|
)
|
||||||||||||
Other
|
4,151
|
(174
|
)
|
3,977
|
||||||||||||
TOTAL
|
1,462,450
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $3,823
|
(7,099
|
)
|
(7,099
|
)
|
||||||||||||
NET
INCOME
|
170,964
|
170,964
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
163,865
|
|||||||||||||||
JUNE
30, 2005
|
$
|
321,201
|
$
|
466,636
|
$
|
919,841
|
$
|
(81,363
|
)
|
$
|
1,626,315
|
2005
|
2004
|
||||||
ELECTRIC
UTILITY PLANT
|
|||||||
Production
|
$
|
4,240,563
|
$
|
4,127,284
|
|||
Transmission
|
995,634
|
978,492
|
|||||
Distribution
|
1,228,611
|
1,202,550
|
|||||
General
|
240,018
|
248,749
|
|||||
Construction
Work in Progress
|
342,832
|
240,957
|
|||||
Total
|
7,047,658
|
6,798,032
|
|||||
Accumulated
Depreciation and Amortization
|
2,657,146
|
2,617,238
|
|||||
TOTAL
- NET
|
4,390,512
|
4,180,794
|
|||||
OTHER
PROPERTY AND INVESTMENTS
|
|||||||
Nonutility
Property, Net
|
44,438
|
44,774
|
|||||
Other
|
8,856
|
13,409
|
|||||
TOTAL
|
53,294
|
58,183
|
|||||
CURRENT
ASSETS
|
|||||||
Cash
and Cash Equivalents
|
1,353
|
9,300
|
|||||
Other
Cash Deposits
|
31
|
37
|
|||||
Advances
to Affiliates
|
-
|
125,971
|
|||||
Accounts
Receivable:
|
|||||||
Customers
|
108,026
|
98,951
|
|||||
Affiliated
Companies
|
144,638
|
144,175
|
|||||
Accrued
Unbilled Revenues
|
14,754
|
10,641
|
|||||
Miscellaneous
|
453
|
7,626
|
|||||
Allowance
for Uncollectible Accounts
|
(114
|
)
|
(93
|
)
|
|||
Fuel
|
111,013
|
70,309
|
|||||
Materials
and Supplies
|
58,962
|
55,569
|
|||||
Emissions
Allowances
|
38,170
|
95,303
|
|||||
Risk
Management Assets
|
74,036
|
79,541
|
|||||
Margin
Deposits
|
10,174
|
7,056
|
|||||
Prepayments
and Other
|
14,642
|
10,492
|
|||||
TOTAL
|
576,138
|
714,878
|
|||||
DEFERRED
DEBITS AND OTHER ASSETS
|
|||||||
Regulatory
Assets:
|
|||||||
SFAS
109 Regulatory Asset, Net
|
172,933
|
169,866
|
|||||
Transition
Regulatory Assets
|
182,469
|
225,273
|
|||||
Unamortized
Loss on Reacquired Debt
|
14,197
|
11,046
|
|||||
Other
|
74,122
|
22,189
|
|||||
Long-term
Risk Management Assets
|
120,037
|
66,727
|
|||||
Deferred
Property Taxes
|
37,960
|
70,214
|
|||||
Deferred
Charges and Other Assets
|
62,845
|
74,095
|
|||||
TOTAL
|
664,563
|
639,410
|
|||||
TOTAL
ASSETS
|
$
|
5,684,507
|
$
|
5,593,265
|
2005
|
2004
|
||||||
CAPITALIZATION
|
(in
thousands)
|
||||||
Common
Shareholder’s Equity
|
|||||||
Common
Stock - No par value:
|
|||||||
Authorized
- 40,000,000 shares
|
|||||||
Outstanding
- 27,952,473 shares
|
$
|
321,201
|
$
|
321,201
|
|||
Paid-in
Capital
|
466,636
|
462,485
|
|||||
Retained
Earnings
|
919,841
|
764,416
|
|||||
Accumulated
Other Comprehensive Income (Loss)
|
(81,363
|
)
|
(74,264
|
)
|
|||
Total
Common Shareholder’s Equity
|
1,626,315
|
1,473,838
|
|||||
Cumulative
Preferred Stock Not Subject to Mandatory Redemption
|
16,641
|
16,641
|
|||||
Total
Shareholders’ Equity
|
1,642,956
|
1,490,479
|
|||||
Long-term
Debt:
|
|||||||
Nonaffiliated
|
1,593,273
|
1,598,706
|
|||||
Affiliated
|
200,000
|
400,000
|
|||||
Total
Long-term Debt
|
1,793,273
|
1,998,706
|
|||||
TOTAL
|
3,436,229
|
3,489,185
|
|||||
Minority
Interest
|
12,906
|
14,083
|
|||||
CURRENT
LIABILITIES
|
|||||||
Short-term
Debt - Nonaffiliated
|
14,352
|
23,498
|
|||||
Long-term
Debt Due Within One Year - Affiliated
|
200,000
|
-
|
|||||
Long-term
Debt Due Within One Year - Nonaffiliated
|
12,354
|
12,354
|
|||||
Cumulative
Preferred Stock Subject to Mandatory Redemption
|
-
|
5,000
|
|||||
Advances
from Affiliates
|
11,528
|
-
|
|||||
Accounts
Payable:
|
|||||||
General
|
164,615
|
143,247
|
|||||
Affiliated
Companies
|
76,171
|
116,615
|
|||||
Customer
Deposits
|
32,258
|
22,620
|
|||||
Taxes
Accrued
|
139,726
|
233,026
|
|||||
Interest
Accrued
|
37,249
|
39,254
|
|||||
Risk
Management Liabilities
|
81,448
|
70,311
|
|||||
Obligations
Under Capital Leases
|
8,847
|
9,081
|
|||||
Other
|
91,531
|
74,977
|
|||||
TOTAL
|
870,079
|
749,983
|
|||||
DEFERRED
CREDITS AND OTHER LIABILITIES
|
|||||||
Deferred
Income Taxes
|
910,767
|
943,465
|
|||||
Regulatory
Liabilities:
|
|||||||
Asset
Removal Costs
|
107,043
|
102,875
|
|||||
Deferred
Investment Tax Credits
|
12,040
|
12,539
|
|||||
Other
|
48,864
|
-
|
|||||
Long-term
Risk Management Liabilities
|
90,478
|
46,261
|
|||||
Deferred
Credits
|
23,057
|
24,377
|
|||||
Employee
Benefits and Pension Obligations
|
86,939
|
126,825
|
|||||
Obligations
Under Capital Leases
|
33,037
|
31,652
|
|||||
Asset
Retirement Obligations
|
47,402
|
45,606
|
|||||
Other
|
5,666
|
6,414
|
|||||
TOTAL
|
1,365,293
|
1,340,014
|
|||||
Commitments
and Contingencies (Note 5)
|
|||||||
TOTAL
CAPITALIZATION AND LIABILITIES
|
$
|
5,684,507
|
$
|
5,593,265
|
2005
|
2004
|
||||||
OPERATING
ACTIVITIES
|
|||||||
Net
Income
|
$
|
170,964
|
$
|
118,947
|
|||
Adjustments
to Reconcile Net Income to Net Cash Flows From
Operating Activities:
|
|||||||
Depreciation
and Amortization
|
153,888
|
142,170
|
|||||
Accretion
Expense
|
1,796
|
1,682
|
|||||
Deferred
Income Taxes
|
9,923
|
4,400
|
|||||
Deferred
Investment Tax Credits
|
(499
|
)
|
(1,523
|
)
|
|||
Deferred
Property Taxes
|
32,254
|
30,792
|
|||||
Pension
and Postemployment Benefit Reserves
|
128
|
1,528
|
|||||
Mark-to-Market
of Risk Management Contracts
|
(2,271
|
)
|
4,819
|
||||
Pension
Contributions
|
(40,013
|
)
|
(191
|
)
|
|||
Carrying
Costs Income
|
(29,548
|
)
|
(357
|
)
|
|||
Change
in Other Noncurrent Assets
|
(13,611
|
)
|
(20,362
|
)
|
|||
Change
in Other Noncurrent Liabilities
|
(1,810
|
)
|
(5,217
|
)
|
|||
Changes
in Components of Working Capital:
|
|||||||
Accounts
Receivable, Net
|
(6,457
|
)
|
(1,616
|
)
|
|||
Fuel,
Materials and Supplies
|
(44,097
|
)
|
(12,888
|
)
|
|||
Accounts
Payable
|
(28,330
|
)
|
4,921
|
||||
Taxes
Accrued
|
(93,300
|
)
|
20,692
|
||||
Customer
Deposits
|
9,638
|
10,791
|
|||||
Interest
Accrued
|
(2,005
|
)
|
(359
|
)
|
|||
Other
Current Assets
|
49,864
|
11,050
|
|||||
Other
Current Liabilities
|
16,321
|
(5,894
|
)
|
||||
Net
Cash Flows From Operating Activities
|
182,835
|
303,385
|
|||||
INVESTING
ACTIVITIES
|
|||||||
Construction
Expenditures
|
(296,048
|
)
|
(130,495
|
)
|
|||
Change
in Other Cash Deposits, Net
|
6
|
50,952
|
|||||
Proceeds
from Sale of Assets
|
7,329
|
1,102
|
|||||
Net
Cash Flows Used For Investing Activities
|
(288,713
|
)
|
(78,441
|
)
|
|||
FINANCING
ACTIVITIES
|
|||||||
Change
in Short-term Debt, Net
|
(9,146
|
)
|
(4,402
|
)
|
|||
Issuance
of Long-term Debt - Nonaffiliated
|
214,120
|
-
|
|||||
Issuance
of Long-term Debt - Affiliated
|
-
|
200,000
|
|||||
Retirement
of Long-term Debt - Nonaffiliated
|
(224,177
|
)
|
(204,427
|
)
|
|||
Retirement
of Cumulative Preferred Stock
|
(5,000
|
)
|
(2,251
|
)
|
|||
Changes
in Advances to/from Affiliates, Net
|
137,499
|
(100,222
|
)
|
||||
Dividends
Paid on Common Stock
|
(14,999
|
)
|
(114,115
|
)
|
|||
Dividends
Paid on Cumulative Preferred Stock
|
(366
|
)
|
(366
|
)
|
|||
Net
Cash Flows From (Used For) Financing Activities
|
97,931
|
(225,783
|
)
|
||||
Net
Decrease in Cash and Cash Equivalents
|
(7,947
|
)
|
(839
|
)
|
|||
Cash
and Cash Equivalents at Beginning of Period
|
9,300
|
7,233
|
|||||
Cash
and Cash Equivalents at End of Period
|
$
|
1,353
|
$
|
6,394
|
SUPPLEMENTAL
DISCLOSURE:
|
Cash
paid (received) for interest net of capitalized amounts was
$52,403,000
and $59,407,000 and for income taxes was $114,782,000 and $(8,420,000)
in
2005 and 2004, respectively. Noncash capital lease acquisitions
were
$7,210,000 and $6,846,000 in 2005 and 2004, respectively. Construction
Expenditures include the change in construction-related Accounts
Payable
of $9,253,000 and $(3,280,000) in 2005 and 2004,
respectively.
|
Footnote
Reference
|
|
Significant
Accounting Matters
|
Note
1
|
New
Accounting Pronouncements
|
Note
2
|
Rate
Matters
|
Note
3
|
Customer
Choice and Industry Restructuring
|
Note
4
|
Commitments
and Contingencies
|
Note
5
|
Guarantees
|
Note
6
|
Benefit
Plans
|
Note
8
|
Business
Segments
|
Note
9
|
Income
Taxes
|
Note
10
|
Financing
Activities
|
Note
11
|
Company-wide
Staffing and Budget Review
|
Note
12
|
Second
Quarter of 2004 Net Income
|
$
|
7
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins
|
(1
|
)
|
|||||
Off-system
Sales
|
1
|
||||||
Total
Change in Gross Margin
|
-
|
||||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
9
|
||||||
Taxes
Other Than Income Taxes
|
4
|
||||||
Interest
Charges
|
1
|
||||||
Total
Change in Operating Expenses and Other
|
14
|
||||||
Income
Tax Expense
|
(3
|
)
|
|||||
Second
Quarter of 2005 Net Income
|
$
|
18
|
·
|
Retail
Margins decreased by $1 million primarily
due to a $3 million decrease in net fuel revenue/fuel expense,
offset by a
$2 million increase in retail base revenue due to slightly
higher
volumes.
|
·
|
Margins
from Off-system Sales increased by $1 million primarily due
to higher
capacity sales and by slightly higher optimization
activity.
|
·
|
Other
Operation and Maintenance expenses decreased $9 million primarily
attributed to the higher cost of scheduled plant maintenance
and overhead
line maintenance due to storm damage, both in 2004.
|
·
|
Taxes
Other Than Income Taxes decreased $4 million primarily due
to a prior year
adjustment of property related taxes.
|
·
|
Interest
Charges decreased $1 million primarily due to the retirement
of higher
rate First Mortgage Bonds and Trust Preferred Securities in
2004 replaced
by lower rate Senior Unsecured
Notes.
|
Six
Months Ended June 30, 2004 Net Loss
|
$
|
(2
|
)
|
||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins
|
(5
|
)
|
|||||
Off-system
Sales
|
4
|
||||||
Total
Change in Gross Margin
|
(1
|
)
|
|||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
24
|
||||||
Taxes
Other Than Income Taxes
|
4
|
||||||
Interest
Charges
|
3
|
||||||
Nonoperating
Income and Expense, Net
|
1
|
||||||
Total
Change in Operating Expenses and Other
|
32
|
||||||
Income
Tax Expense
|
(10
|
)
|
|||||
Six
Months Ended June 30, 2005 Net Income
|
$
|
19
|
·
|
Retail
Margins decreased by $5 primarily
due to a $6 million decrease in net fuel revenue/fuel expense,
offset by a
$1 million increase in retail base revenue due to slightly
higher
volumes.
|
·
|
Margins
from Off-system Sales increased by $4 million primarily due
to higher
margins of $3 million and higher capacity sales of $1
million.
|
·
|
Other
Operation and Maintenance expenses decreased $24 million. Transmission
related expenses decreased $7 million primarily due to adjustments
in 2004
for affiliated OATT and ancillary services resulting from revised
ERCOT
data for the years 2001 through 2003 of approximately $5 million.
Distribution expenses decreased $3 million resulting primarily
from a 2004
labor settlement. Administrative and general expenses decreased
approximately $7 million due to lower outside services and
employee
related expenses, offset in part by increased customer related
expense of
$2 million. Maintenance decreased $10 million primarily attributed
to the
higher cost of scheduled power plant maintenance and overhead
line
maintenance due to storm damage, both in 2004.
|
·
|
Interest
Charges decreased $3 million primarily due to the retirement
of higher
rate First Mortgage Bonds and Trust Preferred Securities in
2004 replaced
by lower rate Senior Unsecured
Notes.
|
Moody’s
|
S&P
|
Fitch
|
|||
First
Mortgage Bonds
|
A3
|
A-
|
A
|
||
Senior
Unsecured Debt
|
Baa1
|
BBB
|
A-
|
Principal
|
Interest
|
Due
|
||||||||
Type
of Debt
|
Amount
|
Rate
|
Date
|
|||||||
(in
thousands)
|
(%)
|
|||||||||
Senior
Unsecured Notes
|
$
|
75,000
|
4.70
|
2011
|
Principal
|
Interest
|
Due
|
||||||||
Type
of Debt
|
Amount
|
Rate
|
Date
|
|||||||
(in
thousands)
|
(%)
|
|||||||||
First
Mortgage Bonds
|
$
|
50,000
|
6.50
|
2005
|
Total
MTM Risk Management Contract Net Assets at December 31,
2004
|
$
|
14,771
|
||
(Gain)
Loss from Contracts Realized/Settled During the Period (a)
|
172
|
|||
Fair
Value of New Contracts When Entered During the Period (b)
|
-
|
|||
Net
Option Premiums Paid/(Received) (c)
|
(56
|
)
|
||
Change
in Fair Value Due to Valuation Methodology Changes
|
-
|
|||
Changes
in Fair Value of Risk Management Contracts (d)
|
-
|
|||
Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions (e)
|
(11,050
|
)
|
||
Total
MTM Risk Management Contract Net Assets
|
3,837
|
|||
Net
Cash Flow Hedge Contracts (f)
|
(849
|
)
|
||
Total
MTM Risk Management Contract Net Assets at June 30, 2005
|
$
|
2,988
|
(a)
|
“(Gain)
Loss from Contracts Realized/Settled During the Period” includes realized
risk management contracts and related derivatives that settled
during 2005
where
we entered into the contract prior
to 2005.
|
(b)
|
“Fair
Value of New Contracts When Entered During the Period” represents the fair
value at inception of long-term contracts entered into with
customers
during 2005. Most of the fair value comes from longer term
fixed price
contracts with customers that seek to limit their risk against
fluctuating
energy prices. Inception value is only recorded if observable
market data
can be obtained for valuation inputs for the entire contract
term. The
contract prices are valued against market curves associated
with the
delivery location and delivery term.
|
(c)
|
“Net
Option Premiums Paid/(Received)” reflects the net option premiums
paid/(received) as they relate to unexercised and unexpired
option
contracts that were entered in 2005.
|
(d)
|
“Changes
in Fair Value of Risk Management Contracts” represents the fair value
change in the risk management portfolio due to market fluctuations
during
the current period. Market fluctuations are attributable to
various
factors such as supply/demand, weather, storage, etc.
|
(e)
|
“Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions” relates to the net gains (losses) of those contracts that
are not reflected in the Condensed Statements of Operations.
These net
gains (losses) are recorded as regulatory assets/liabilities
for
those subsidiaries that operate in regulated
jurisdictions.
|
(f)
|
“Net
Cash Flow Hedge Contracts” (pretax) are discussed below in Accumulated
Other Comprehensive Income (Loss).
|
MTM
Risk Management Contracts (a)
|
Cash
Flow Hedges
|
Total
(b)
|
||||||||
Current
Assets
|
$
|
6,171
|
$
|
33
|
$
|
6,204
|
||||
Noncurrent
Assets
|
7,613
|
9
|
7,622
|
|||||||
Total
MTM Derivative Contract Assets
|
13,784
|
42
|
13,826
|
|||||||
Current
Liabilities
|
(5,772
|
)
|
(814
|
)
|
(6,586
|
)
|
||||
Noncurrent
Liabilities
|
(4,175
|
)
|
(77
|
)
|
(4,252
|
)
|
||||
Total
MTM Derivative Contract Liabilities
|
(9,947
|
)
|
(891
|
)
|
(10,838
|
)
|
||||
Total
MTM Derivative Contract Net Assets (Liabilities)
|
$
|
3,837
|
$
|
(849
|
)
|
$
|
2,988
|
(a)
|
Does
not include Cash Flow Hedges.
|
(b)
|
Represents
amount of total MTM derivative contracts recorded within Risk
Management
Assets, Long-term Risk Management Assets, Risk Management Liabilities
and
Long-term Risk Management Liabilities on our Condensed Balance
Sheets.
|
·
|
The
source of fair value used in determining the carrying amount
of our total
MTM asset or liability (external sources or modeled
internally).
|
·
|
The
maturity, by year, of our net assets/liabilities, giving an
indication of
when these MTM amounts will settle and generate
cash.
|
Remainder
of 2005
|
2006
|
2007
|
2008
|
2009
|
After
2009
(c)
|
Total
(d)
|
||||||||||||||||
Prices
Actively Quoted - Exchange Traded
Contracts
|
$
|
(1,016
|
)
|
$
|
(8
|
)
|
$
|
805
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
(219
|
)
|
|||||
Prices
Provided by Other External Sources
- OTC Broker Quotes (a)
|
2,162
|
2,815
|
830
|
987
|
-
|
-
|
6,794
|
|||||||||||||||
Prices
Based on Models and Other Valuation
Methods (b)
|
(1,109
|
)
|
(2,028
|
)
|
(869
|
)
|
(88
|
)
|
620
|
736
|
(2,738
|
)
|
||||||||||
Total
|
$
|
37
|
$
|
779
|
$
|
766
|
$
|
899
|
$
|
620
|
$
|
736
|
$
|
3,837
|
(a)
|
“Prices
Provided by Other External Sources - OTC Broker Quotes” reflects
information obtained from over-the-counter brokers, industry
services, or
multiple-party on-line platforms.
|
(b)
|
“Prices
Based on Models and Other Valuation Methods” is in absence of pricing
information from external sources. Modeled information is derived
using
valuation models developed by the reporting entity, reflecting
when
appropriate, option pricing theory, discounted cash flow concepts,
valuation adjustments, etc. and may require projection of prices
for
underlying commodities beyond the period that prices are available
from
third-party sources. In addition, where external pricing information
or
market liquidity are limited, such valuations are classified
as modeled.
The determination of the point at which a market is no longer
liquid for
placing it in the modeled category varies by market.
|
(c)
|
There
is mark-to-market value in excess of 10 percent of our total
mark-to-market value in individual periods beyond 2009. $442
thousand of
this mark-to-market value is in 2010.
|
(d)
|
Amounts
exclude Cash Flow Hedges.
|
Power
|
Interest
Rate
|
Total
|
||||||||
Beginning
Balance December 31, 2004
|
$
|
1,000
|
$
|
(600
|
)
|
$
|
400
|
|||
Changes
in Fair Value (a)
|
(1,122
|
)
|
48
|
(1,074
|
)
|
|||||
Reclassifications
from AOCI to Net Income
(b)
|
(422
|
)
|
13
|
(409
|
)
|
|||||
Ending
Balance June 30, 2005
|
$
|
(544
|
)
|
$
|
(539
|
)
|
$
|
(1,083
|
)
|
(a)
|
“Changes
in Fair Value” shows changes in the fair value of derivatives designated
as cash flow hedges during the reporting period that are not
yet settled
at June 30, 2005. Amounts are reported net of related income
taxes.
|
(b)
|
“Reclassifications
from AOCI to Net Income” represents gains or losses from derivatives used
as hedging instruments in cash flow hedges that were reclassified
into net
income during the reporting period. Amounts are reported net
of related
income taxes.
|
Six
Months Ended
|
Twelve
Months Ended
|
|||||||||||||||
June
30, 2005
|
December
31, 2004
|
|||||||||||||||
(in
thousands)
|
(in
thousands)
|
|||||||||||||||
End
|
High
|
Average
|
Low
|
End
|
High
|
Average
|
Low
|
|||||||||
$112
|
$134
|
$65
|
$38
|
$238
|
$778
|
$335
|
$115
|
Three
Months Ended
|
Six
Months Ended
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
OPERATING
REVENUES
|
|||||||||||||
Electric
Generation, Transmission and Distribution
|
$
|
272,693
|
$
|
228,864
|
$
|
523,061
|
$
|
432,907
|
|||||
Sales
to AEP Affiliates
|
13,650
|
2,954
|
16,282
|
6,096
|
|||||||||
TOTAL
|
286,343
|
231,818
|
539,343
|
439,003
|
|||||||||
OPERATING
EXPENSES
|
|||||||||||||
Fuel
for Electric Generation
|
129,536
|
87,006
|
263,707
|
176,080
|
|||||||||
Fuel
from Affiliates for Electric Generation
|
-
|
-
|
-
|
11
|
|||||||||
Purchased
Energy for Resale
|
30,132
|
5,583
|
44,925
|
14,751
|
|||||||||
Purchased
Electricity from AEP Affiliates
|
15,389
|
28,200
|
38,234
|
55,099
|
|||||||||
Other
Operation
|
36,287
|
36,979
|
66,472
|
80,374
|
|||||||||
Maintenance
|
14,153
|
22,875
|
25,512
|
35,997
|
|||||||||
Depreciation
and Amortization
|
22,247
|
22,159
|
44,866
|
44,335
|
|||||||||
Taxes
Other Than Income Taxes
|
6,061
|
9,727
|
15,738
|
19,544
|
|||||||||
Income
Taxes (Credits)
|
5,657
|
2,429
|
4,805
|
(4,904
|
)
|
||||||||
TOTAL
|
259,462
|
214,958
|
504,259
|
421,287
|
|||||||||
OPERATING
INCOME
|
26,881
|
16,860
|
35,084
|
17,716
|
|||||||||
Nonoperating
Income
|
524
|
127
|
1,002
|
371
|
|||||||||
Nonoperating
Expenses
|
385
|
762
|
936
|
1,304
|
|||||||||
Nonoperating
Income Tax Credit
|
171
|
467
|
421
|
859
|
|||||||||
Interest
Charges
|
8,621
|
9,301
|
16,496
|
19,254
|
|||||||||
NET
INCOME (LOSS)
|
18,570
|
7,391
|
19,075
|
(1,612
|
)
|
||||||||
Preferred
Stock Dividend Requirements
|
53
|
53
|
106
|
106
|
|||||||||
EARNINGS
(LOSS) APPLICABLE TO COMMON STOCK
|
$
|
18,517
|
$
|
7,338
|
$
|
18,969
|
$
|
(1,718
|
)
|
Common
Stock
|
Paid-in
Capital
|
Retained
Earnings
|
Accumulated
Other Comprehensive Income (Loss)
|
Total
|
||||||||||||
DECEMBER
31, 2003
|
$
|
157,230
|
$
|
230,016
|
$
|
139,604
|
$
|
(43,842
|
)
|
$
|
483,008
|
|||||
Gain
on Reacquired Preferred Stock
|
2
|
2
|
||||||||||||||
Common
Stock Dividends
|
(17,500
|
)
|
(17,500
|
)
|
||||||||||||
Preferred
Stock Dividends
|
(106
|
)
|
(106
|
)
|
||||||||||||
TOTAL
|
465,404
|
|||||||||||||||
COMPREHENSIVE
LOSS
|
||||||||||||||||
Other
Comprehensive Loss, Net of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $283
|
(526
|
)
|
(526
|
)
|
||||||||||||
NET
LOSS
|
(1,612
|
)
|
(1,612
|
)
|
||||||||||||
TOTAL
COMPREHENSIVE LOSS
|
(2,138
|
)
|
||||||||||||||
JUNE
30, 2004
|
$
|
157,230
|
$
|
230,016
|
$
|
120,388
|
$
|
(44,368
|
)
|
$
|
463,266
|
|||||
DECEMBER
31, 2004
|
$
|
157,230
|
$
|
230,016
|
$
|
141,935
|
$
|
75
|
$
|
529,256
|
||||||
Common
Stock Dividends
|
(17,000
|
)
|
(17,000
|
)
|
||||||||||||
Preferred
Stock Dividends
|
(106
|
)
|
(106
|
)
|
||||||||||||
TOTAL
|
512,150
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $798
|
(1,483
|
)
|
(1,483
|
)
|
||||||||||||
NET
INCOME
|
19,075
|
19,075
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
17,592
|
|||||||||||||||
JUNE
30, 2005
|
$
|
157,230
|
$
|
230,016
|
$
|
143,904
|
$
|
(1,408
|
)
|
$
|
529,742
|
2005
|
2004
|
||||||
ELECTRIC
UTILITY PLANT
|
|||||||
Production
|
$
|
1,069,477
|
$
|
1,072,022
|
|||
Transmission
|
472,944
|
468,735
|
|||||
Distribution
|
1,114,572
|
1,089,187
|
|||||
General
|
200,682
|
200,044
|
|||||
Construction
Work in Progress
|
54,459
|
41,028
|
|||||
Total
|
2,912,134
|
2,871,016
|
|||||
Accumulated
Depreciation and Amortization
|
1,131,114
|
1,117,113
|
|||||
TOTAL
- NET
|
1,781,020
|
1,753,903
|
|||||
OTHER
PROPERTY AND INVESTMENTS
|
|||||||
Nonutility
Property, Net
|
4,594
|
4,401
|
|||||
Other
Investments
|
-
|
81
|
|||||
TOTAL
|
4,594
|
4,482
|
|||||
CURRENT
ASSETS
|
|||||||
Cash
and Cash Equivalents
|
778
|
91
|
|||||
Other
Cash Deposits
|
6
|
188
|
|||||
Advances
to Affiliates
|
7,084
|
-
|
|||||
Accounts
Receivable:
|
|||||||
Customers
|
18,358
|
34,002
|
|||||
Affiliated
Companies
|
39,598
|
46,399
|
|||||
Miscellaneous
|
7,798
|
6,984
|
|||||
Allowance
for Uncollectible Accounts
|
-
|
(76
|
)
|
||||
Fuel
Inventory
|
17,711
|
14,268
|
|||||
Materials
and Supplies
|
38,797
|
35,485
|
|||||
Risk
Management Assets
|
6,204
|
21,388
|
|||||
Regulatory
Asset for Under-Recovered Fuel Costs
|
-
|
366
|
|||||
Margin
Deposits
|
1,128
|
2,881
|
|||||
Prepayments
and Other
|
2,786
|
1,378
|
|||||
TOTAL
|
140,248
|
163,354
|
|||||
DEFERRED
DEBITS AND OTHER ASSETS
|
|||||||
Regulatory
Assets:
|
|||||||
Unamortized
Loss on Reacquired Debt
|
13,581
|
14,705
|
|||||
Other
|
20,470
|
17,246
|
|||||
Long-term
Risk Management Assets
|
7,622
|
14,477
|
|||||
Prepaid
Pension Obligations
|
82,411
|
82,419
|
|||||
Deferred
Property Taxes
|
16,245
|
-
|
|||||
Deferred
Charges and Other Assets
|
16,841
|
18,232
|
|||||
TOTAL
|
157,170
|
147,079
|
|||||
TOTAL
ASSETS
|
$
|
2,083,032
|
$
|
2,068,818
|
2005
|
2004
|
||||||
CAPITALIZATION
|
(in
thousands)
|
||||||
Common
Shareholder’s Equity:
|
|||||||
Common
Stock - $15 par value per share:
|
|||||||
Authorized
- 11,000,000 shares
|
|||||||
Issued
- 10,482,000 shares
|
|||||||
Outstanding
- 9,013,000 shares
|
$
|
157,230
|
$
|
157,230
|
|||
Paid-in
Capital
|
230,016
|
230,016
|
|||||
Retained
Earnings
|
143,904
|
141,935
|
|||||
Accumulated
Other Comprehensive Income (Loss)
|
(1,408
|
)
|
75
|
||||
Total
Common Shareholder’s Equity
|
529,742
|
529,256
|
|||||
Cumulative
Preferred Stock Not Subject to Mandatory Redemption
|
5,262
|
5,262
|
|||||
Total
Shareholders’ Equity
|
535,004
|
534,518
|
|||||
Long-term
Debt:
|
|||||||
Nonaffiliated
|
521,041
|
446,092
|
|||||
Affiliated
|
-
|
50,000
|
|||||
Total
Long-term Debt
|
521,041
|
496,092
|
|||||
TOTAL
|
1,056,045
|
1,030,610
|
|||||
CURRENT
LIABILITIES
|
|||||||
Long-term
Debt Due Within One Year - Nonaffiliated
|
-
|
50,000
|
|||||
Long-term
Debt Due Within One Year - Affiliated
|
50,000
|
-
|
|||||
Advances
from Affiliates
|
-
|
55,002
|
|||||
Accounts
Payable:
|
|||||||
General
|
112,435
|
71,442
|
|||||
Affiliated
Companies
|
67,002
|
58,632
|
|||||
Customer
Deposits
|
34,774
|
33,757
|
|||||
Taxes
Accrued
|
29,996
|
18,835
|
|||||
Interest
Accrued
|
3,324
|
4,023
|
|||||
Risk
Management Liabilities
|
6,586
|
13,705
|
|||||
Regulatory
Liability for Over-Recovered Fuel Costs
|
1,185
|
-
|
|||||
Obligations
Under Capital Leases
|
603
|
537
|
|||||
Other
|
21,083
|
30,477
|
|||||
TOTAL
|
326,988
|
336,410
|
|||||
DEFERRED
CREDITS AND OTHER LIABILITIES
|
|||||||
Deferred
Income Taxes
|
387,520
|
384,090
|
|||||
Long-term
Risk Management Liabilities
|
4,252
|
7,455
|
|||||
Regulatory
Liabilities:
|
|||||||
Asset
Removal Costs
|
233,774
|
220,298
|
|||||
Deferred
Investment Tax Credits
|
27,724
|
28,620
|
|||||
SFAS
109 Regulatory Liability, Net
|
20,734
|
21,963
|
|||||
Unrealized
Gain on Forward Commitments
|
6,703
|
19,676
|
|||||
Obligations
Under Capital Leases
|
1,111
|
747
|
|||||
Deferred
Credits and Other
|
18,181
|
18,949
|
|||||
TOTAL
|
699,999
|
701,798
|
|||||
Commitments
and Contingencies (Note 5)
|
|||||||
TOTAL
CAPITALIZATION AND LIABILITIES
|
$
|
2,083,032
|
$
|
2,068,818
|
2005
|
2004
|
||||||
OPERATING
ACTIVITIES
|
|||||||
Net
Income (Loss)
|
$
|
19,075
|
$
|
(1,612
|
)
|
||
Adjustments
to Reconcile Net Income to Net Cash Flows From
Operating Activities:
|
|||||||
Depreciation
and Amortization
|
44,866
|
44,335
|
|||||
Deferred
Property Taxes
|
(16,245
|
)
|
(17,295
|
)
|
|||
Deferred
Income Taxes
|
2,998
|
11,043
|
|||||
Deferred
Investment Tax Credits
|
(896
|
)
|
(895
|
)
|
|||
Mark-to-Market
of Risk Management Contracts
|
10,934
|
10,237
|
|||||
Fuel
Recovery
|
1,551
|
(12,683
|
)
|
||||
Change
in Other Noncurrent Assets
|
(16,856
|
)
|
(4,152
|
)
|
|||
Change
in Other Noncurrent Liabilities
|
(1,943
|
)
|
(4,605
|
)
|
|||
Changes
in Components of Working Capital:
|
|||||||
Accounts
Receivable, Net
|
21,555
|
(5,441
|
)
|
||||
Fuel,
Materials and Supplies
|
(6,755
|
)
|
(3,534
|
)
|
|||
Accounts
Payable
|
49,958
|
20,508
|
|||||
Customer
Deposits
|
1,017
|
2,952
|
|||||
Taxes
Accrued
|
11,161
|
7,911
|
|||||
Interest
Accrued
|
(699
|
)
|
(259
|
)
|
|||
Other
Current Assets
|
343
|
3,513
|
|||||
Other
Current Liabilities
|
(9,326
|
)
|
(13,898
|
)
|
|||
Net
Cash Flows From Operating Activities
|
110,738
|
36,125
|
|||||
INVESTING
ACTIVITIES
|
|||||||
Construction
Expenditures
|
(55,449
|
)
|
(36,713
|
)
|
|||
Change
in Other Cash Deposits, Net
|
182
|
3,565
|
|||||
Proceeds
from Sale of Assets
|
-
|
458
|
|||||
Net
Cash Flows Used For Investing Activities
|
(55,267
|
)
|
(32,690
|
)
|
|||
FINANCING
ACTIVITIES
|
|||||||
Issuance
of Long-term Debt
|
74,408
|
83,129
|
|||||
Retirement
of Long-term Debt
|
(50,000
|
)
|
(111,020
|
)
|
|||
Reacquired
Preferred Stock
|
-
|
(3
|
)
|
||||
Changes
in Advances to/from Affiliates, Net
|
(62,086
|
)
|
42,170
|
||||
Dividends
Paid on Common Stock
|
(17,000
|
)
|
(17,500
|
)
|
|||
Dividends
Paid on Cumulative Preferred Stock
|
(106
|
)
|
(106
|
)
|
|||
Net
Cash Flows Used For Financing Activities
|
(54,784
|
)
|
(3,330
|
)
|
|||
Net
Increase in Cash and Cash Equivalents
|
687
|
105
|
|||||
Cash
and Cash Equivalents at Beginning of Period
|
91
|
3,738
|
|||||
Cash
and Cash Equivalents at End of Period
|
$
|
778
|
$
|
3,843
|
SUPPLEMENTAL
DISCLOSURE:
|
Cash
paid (received) for interest net of capitalized amounts was
$15,028,000
and $17,600,000 and for income taxes was $3,590,000 and $(2,695,000)
in
2005 and 2004, respectively. Noncash capital lease acquisitions
were
$738,000 and $337,000 in 2005 and 2004, respectively. Construction
Expenditures include the change in construction-related Accounts
Payable
of $(595,000) and $(174,000) in 2005 and 2004,
respectively.
|
Footnote
Reference
|
|
Significant
Accounting Matters
|
Note
1
|
New
Accounting Pronouncements
|
Note
2
|
Rate
Matters
|
Note
3
|
Commitments
and Contingencies
|
Note
5
|
Guarantees
|
Note
6
|
Benefit
Plans
|
Note
8
|
Business
Segments
|
Note
9
|
Income
Taxes
|
Note
10
|
Financing
Activities
|
Note
11
|
Company-wide
Staffing and Budget Review
|
Note
12
|
Second
Quarter of 2004 Net Income
|
$
|
28
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins (a)
|
(14
|
)
|
|||||
Off-system
Sales
|
3
|
||||||
Other
Revenues
|
1
|
||||||
Total
Change in Gross Margin
|
(10
|
)
|
|||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
(6
|
)
|
|||||
Depreciation
and Amortization
|
(1
|
)
|
|||||
Taxes
Other Than Income Taxes
|
(1
|
)
|
|||||
Interest
Charges
|
1
|
||||||
Total
Change in Operating Expenses and Other:
|
(7
|
)
|
|||||
Income
Tax Expense
|
8
|
||||||
Second
Quarter of 2005 Net Income
|
$
|
19
|
(a)
|
Includes
firm wholesale sales to municipals and
cooperatives.
|
·
|
Retail
Margins decreased $14 million primarily
due to a $22 million decrease in net fuel revenue/fuel expense,
of which
$11 million is increased capacity expense, offset by an increase
in retail
base revenue of $5 million and an increase of $3 million in
wholesale base
revenue, due to higher volumes.
|
·
|
Margins
from Off-system Sales increased $3 million primarily due to
increased
capacity and affiliated sales
margins.
|
·
|
Other
Operation and Maintenance expenses increased $6 million primarily
due to
increased maintenance expense of $4 million resulting from
extended power
plant outages, increased production related expense and higher
administrative and general expenses.
|
Six
Months Ended June 30, 2004 Net Income
|
$
|
33
|
|||||
Changes
in Gross Margin:
|
|||||||
Retail
Margins (a)
|
(9
|
)
|
|||||
Off-system
Sales
|
2
|
||||||
Transmission
Revenues
|
(1
|
)
|
|||||
Other
Revenues
|
2
|
||||||
Total
Change in Gross Margin
|
(6
|
)
|
|||||
Changes
in Operating Expenses and Other:
|
|||||||
Other
Operation and Maintenance
|
-
|
||||||
Depreciation
and Amortization
|
(2
|
)
|
|||||
Interest
Charges
|
3
|
||||||
Total
Change in Operating Expenses and Other:
|
1
|
||||||
Income
Tax Expense
|
4
|
||||||
Six
Months Ended June 30, 2005 Net Income
|
$
|
32
|
(a)
|
Includes
firm wholesale sales to municipals and
cooperatives.
|
·
|
Retail
Margins decreased $9 million primarily
due to a $24 million decrease in net fuel revenue/fuel expense,
of which
$13 million is increased capacity expense, offset by an increase
in retail
base revenue of $5 million and an increase of $10 million in
wholesale
base revenue, due to higher volumes.
|
·
|
Margins
from Off-system Sales increased $2 million primarily due to
higher
optimization activity.
|
·
|
Transmission
Revenues decreased $1 million primarily due to reduced SPP
revenues.
|
·
|
Operation
expenses decreased $3 million primarily due to a $6 million
adjustment in
2004 for affiliated OATT and ancillary services resulting from
revised
ERCOT data for the years 2001 through 2003, offset in part
by $3 million
of higher production plant related expenses. Maintenance expense
increased
$4 million primarily due to major power plant outages in
2005.
|
·
|
Interest
Charges decreased $3 million primarily due to refinancing debt
maturities
and optional redemptions with lower cost
debt.
|
Moody’s
|
S&P
|
Fitch
|
|||
First
Mortgage Bonds
|
A3
|
A-
|
A
|
||
Senior
Unsecured Debt
|
Baa1
|
BBB
|
A-
|
2005
|
2004
|
||||||
(in
thousands)
|
|||||||
Cash
and Cash Equivalents at Beginning of Period
|
$
|
2,308
|
$
|
5,676
|
|||
Cash
Flows From (Used For):
|
|||||||
Operating
Activities
|
98,139
|
112,966
|
|||||
Investing
Activities
|
(65,750
|
)
|
(42,760
|
)
|
|||
Financing
Activities
|
(30,106
|
)
|
(64,280
|
)
|
|||
Net
Increase in Cash and Cash Equivalents
|
2,283
|
5,926
|
|||||
Cash
and Cash Equivalents at End of Period
|
$
|
4,591
|
$
|
11,602
|
Principal
|
Interest
|
Due
|
||||||||
Type
of Debt
|
Amount
|
Rate
|
Date
|
|||||||
(in
thousands)
|
(%)
|
|||||||||
Senior
Unsecured Notes
|
$
|
150,000
|
(a) |
4.90
|
2015
|
Principal
|
Interest
|
Due
|
||||||||
Type
of Debt
|
Amount
|
Rate
|
Date
|
|||||||
(in
thousands)
|
(%)
|
|||||||||
Note
Payable
|
$
|
3,415
|
4.47
|
2011
|
||||||
Note
Payable
|
1,500
|
Variable
|
2008
|
Total
MTM Risk Management Contract Net Assets at December 31,
2004
|
$
|
17,527
|
||
(Gain)
Loss from Contracts Realized/Settled During the Period (a)
|
(3,428
|
)
|
||
Fair
Value of New Contracts When Entered During the Period (b)
|
47
|
|||
Net
Option Premiums Paid/(Received) (c)
|
(84
|
)
|
||
Change
in Fair Value Due to Valuation Methodology Changes
|
-
|
|||
Changes
in Fair Value of Risk Management Contracts (d)
|
(1,087
|
)
|
||
Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions (e)
|
(8,479
|
)
|
||
Total
MTM Risk Management Contract Net Assets
|
4,496
|
|||
Net
Cash Flow Hedge Contracts (f)
|
(1,311
|
)
|
||
Total
MTM Risk Management Contract Net Assets at June 30, 2005
|
$
|
3,185
|
(a)
|
“(Gain)
Loss from Contracts Realized/Settled During the Period” includes realized
risk management contracts and related derivatives that settled
during 2005
where
we entered into the contract prior
to 2005.
|
(b)
|
“Fair
Value of New Contracts When Entered During the Period” represents the fair
value at inception of long-term contracts entered into with
customers
during 2005. Most of the fair value comes from longer term
fixed price
contracts with customers that seek to limit their risk against
fluctuating
energy prices. Inception value is only recorded if observable
market data
can be obtained for valuation inputs for the entire contract
term. The
contract prices are valued against market curves associated
with the
delivery location and delivery term.
|
(c)
|
“Net
Option Premiums Paid/(Received)” reflects the net option premiums
paid/(received) as they relate to unexercised and unexpired
option
contracts that were entered in 2005.
|
(d)
|
“Changes
in Fair Value of Risk Management Contracts” represents the fair value
change in the risk management portfolio due to market fluctuations
during
the current period. Market fluctuations are attributable to
various
factors such as supply/demand, weather, storage, etc.
|
(e)
|
“Changes
in Fair Value of Risk Management Contracts Allocated to Regulated
Jurisdictions” relates to the net gains (losses) of those contracts that
are not reflected in the Condensed Consolidated Statements
of Income.
These net gains (losses) are recorded as regulatory assets/liabilities
for
those subsidiaries that operate in regulated
jurisdictions.
|
(f)
|
“Net
Cash Flow Hedge Contracts” (pretax) are discussed below in Accumulated
Other Comprehensive Income (Loss).
|
MTM
Risk Management Contracts (a)
|
Cash
Flow Hedges
|
Total
(b)
|
||||||||
Current
Assets
|
$
|
7,417
|
$
|
39
|
$
|
7,456
|
||||
Noncurrent
Assets
|
9,084
|
11
|
9,095
|
|||||||
Total
MTM Derivative Contract Assets
|
16,501
|
50
|
16,551
|
|||||||
Current
Liabilities
|
(6,940
|
)
|
(1,098
|
)
|
(8,038
|
)
|
||||
Noncurrent
Liabilities
|
(5,065
|
)
|
(263
|
)
|
(5,328
|
)
|
||||
Total
MTM Derivative Contract Liabilities
|
(12,005
|
)
|
(1,361
|
)
|
(13,366
|
)
|
||||
Total
MTM Derivative Contract Net Assets (Liabilities)
|
$
|
4,496
|
$
|
(1,311
|
)
|
$
|
3,185
|
(a)
|
Does
not include Cash Flow Hedges.
|
(b)
|
Represents
amount of total MTM derivative contracts recorded within Risk
Management
Assets, Long-term Risk Management Assets, Risk Management Liabilities
and
Long-term Risk Management Liabilities on our Condensed Consolidated
Balance Sheets.
|
·
|
The
source of fair value used in determining the carrying amount
of our total
MTM asset or liability (external sources or modeled
internally).
|
·
|
The
maturity, by year, of our net assets/liabilities, giving an
indication of
when these MTM amounts will settle and generate
cash.
|
Remainder
of 2005
|
2006
|
2007
|
2008
|
2009
|
After
2009
(c)
|
Total
(d)
|
||||||||||||||||
Prices
Actively Quoted - Exchange Traded
Contracts
|
$
|
(1,207
|
)
|
$
|
(10
|
)
|
$
|
957
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
(260
|
)
|
|||||
Prices
Provided by Other External Sources
- OTC Broker Quotes (a)
|
2,564
|
3,373
|
950
|
1,174
|
-
|
-
|
8,061
|
|||||||||||||||
Prices
Based on Models and Other Valuation
Methods (b)
|
(1,319
|
)
|
(2,439
|
)
|
(1,055
|
)
|
(104
|
)
|
737
|
875
|
(3,305
|
)
|
||||||||||
Total
|
$
|
38
|
$
|
924
|
$
|
852
|
$
|
1,070
|
$
|
737
|
$
|
875
|
$
|
4,496
|
(a)
|
“Prices
Provided by Other External Sources - OTC Broker Quotes” reflects
information obtained from over-the-counter brokers, industry
services, or
multiple-party on-line platforms.
|
(b)
|
“Prices
Based on Models and Other Valuation Methods” is in absence of pricing
information from external sources. Modeled information is derived
using
valuation models developed by the reporting entity, reflecting
when
appropriate, option pricing theory, discounted cash flow concepts,
valuation adjustments, etc. and may require projection of prices
for
underlying commodities beyond the period that prices are available
from
third-party sources. In addition, where external pricing information
or
market liquidity are limited, such valuations are classified
as modeled.
The determination of the point at which a market is no longer
liquid for
placing it in the modeled category varies by market.
|
(c)
|
There
is mark-to-market value in excess of 10 percent of our total
mark-to-market value in individual periods beyond 2009. $525
thousand of
this mark-to-market value is in 2010.
|
(d)
|
Amounts
exclude Cash Flow Hedges.
|
Power
|
Interest
Rate
|
Total
|
||||||||
Beginning
Balance December 31, 2004
|
$
|
1,188
|
$
|
(2,008
|
)
|
$
|
(820
|
)
|
||
Changes
in Fair Value (a)
|
(1,334
|
)
|
(3,378
|
)
|
(4,712
|
)
|
||||
Reclassifications
from AOCI to Net Income
(b)
|
(500
|
)
|
-
|
(500
|
)
|
|||||
Ending
Balance June 30, 2005
|
$
|
(646
|
)
|
$
|
(5,386
|
)
|
$
|
(6,032
|
)
|
(a)
|
“Changes
in Fair Value” shows changes in the fair value of derivatives designated
as cash flow hedges during the reporting period that are not
yet settled
at June 30, 2005. Amounts are reported net of related income
taxes.
|
(b)
|
“Reclassifications
from AOCI to Net Income” represents gains or losses from derivatives used
as hedging instruments in cash flow hedges that were reclassified
into net
income during the reporting period. Amounts are reported net
of related
income taxes above.
|
Six
Months Ended
|
Twelve
Months Ended
|
|||||||||||||||
June
30, 2005
|
December
31, 2004
|
|||||||||||||||
(in
thousands)
|
(in
thousands)
|
|||||||||||||||
End
|
High
|
Average
|
Low
|
End
|
High
|
Average
|
Low
|
|||||||||
$133
|
$159
|
$78
|
$46
|
$283
|
$923
|
$398
|
$136
|
Three
Months Ended
|
Six
Months Ended
|
||||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
OPERATING
REVENUES
|
|||||||||||||
Electric
Generation, Transmission and Distribution
|
$
|
326,175
|
$
|
251,550
|
$
|
556,049
|
$
|
465,500
|
|||||
Sales
to AEP Affiliates
|
6,837
|
17,498
|
23,959
|
39,709
|
|||||||||
TOTAL
|
333,012
|
269,048
|
580,008
|
505,209
|
|||||||||
OPERATING
EXPENSES
|
|||||||||||||
Fuel
for Electric Generation
|
116,167
|
94,245
|
206,277
|
183,068
|
|||||||||
Purchased
Electricity for Resale
|
32,803
|
(4,008
|
)
|
46,183
|
1,926
|
||||||||
Purchased
Electricity from AEP Affiliates
|
22,003
|
7,113
|
27,867
|
14,420
|
|||||||||
Other
Operation
|
47,115
|
44,593
|
91,564
|
94,861
|
|||||||||
Maintenance
|
27,645
|
24,011
|
43,360
|
39,659
|
|||||||||
Depreciation
and Amortization
|
33,257
|
31,979
|
65,650
|
63,264
|
|||||||||
Taxes
Other Than Income Taxes
|
15,887
|
15,148
|
31,550
|
31,715
|
|||||||||
Income
Taxes
|
5,861
|
14,439
|
10,457
|
14,570
|
|||||||||
TOTAL
|
300,738
|
227,520
|
522,908
|
443,483
|
|||||||||
OPERATING
INCOME
|
32,274
|
41,528
|
57,100
|
61,726
|
|||||||||
Nonoperating
Income
|
991
|
792
|
2,310
|
2,195
|
|||||||||
Nonoperating
Expenses
|
617
|
723
|
1,091
|
1,334
|
|||||||||
Nonoperating
Income Tax Credit
|
371
|
541
|
571
|
897
|
|||||||||
Interest
Charges
|
12,901
|
13,379
|
25,681
|
28,822
|
|||||||||
Minority
Interest
|
(814
|
)
|
(813
|
)
|
(1,700
|
)
|
(1,694
|
)
|
|||||
NET
INCOME
|
19,304
|
27,946
|
31,509
|
32,968
|
|||||||||
Preferred
Stock Dividend Requirements
|
58
|
58
|
115
|
115
|
|||||||||
EARNINGS
APPLICABLE TO COMMON STOCK
|
$
|
19,246
|
$
|
27,888
|
$
|
31,394
|
$
|
32,853
|
Common
Stock
|
Paid-in
Capital
|
Retained
Earnings
|
Accumulated
Other Comprehensive Income (Loss)
|
Total
|
||||||||||||
DECEMBER
31, 2003
|
$
|
135,660
|
$
|
245,003
|
$
|
359,907
|
$
|
(43,910
|
)
|
$
|
696,660
|
|||||
Common
Stock Dividends
|
(30,000
|
)
|
(30,000
|
)
|
||||||||||||
Preferred
Stock Dividends
|
(115
|
)
|
(115
|
)
|
||||||||||||
TOTAL
|
666,545
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Income (Loss), Net of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $333
|
(618
|
)
|
(618
|
)
|
||||||||||||
Minimum
Pension Liability, Net of Tax of $12,420
|
23,066
|
23,066
|
||||||||||||||
NET
INCOME
|
32,968
|
32,968
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
55,416
|
|||||||||||||||
JUNE
30, 2004
|
$
|
135,660
|
$
|
245,003
|
$
|
362,760
|
$
|
(21,462
|
)
|
$
|
721,961
|
|||||
DECEMBER
31, 2004
|
$
|
135,660
|
$
|
245,003
|
$
|
389,135
|
$
|
(1,180
|
)
|
$
|
768,618
|
|||||
Common
Stock Dividends
|
(25,000
|
)
|
(25,000
|
)
|
||||||||||||
Preferred
Stock Dividends
|
(115
|
)
|
(115
|
)
|
||||||||||||
TOTAL
|
743,503
|
|||||||||||||||
COMPREHENSIVE
INCOME
|
||||||||||||||||
Other
Comprehensive Loss, Net of Taxes:
|
||||||||||||||||
Cash
Flow Hedges, Net of Tax of $2,807
|
(5,212
|
)
|
(5,212
|
)
|
||||||||||||
NET
INCOME
|
31,509
|
31,509
|
||||||||||||||
TOTAL
COMPREHENSIVE INCOME
|
26,297
|
|||||||||||||||
JUNE
30, 2005
|
$
|
135,660
|
$
|
245,003
|
$
|
395,529
|
$
|
(6,392
|
)
|
$
|
769,800
|
2005
|
2004
|
||||||
ELECTRIC
UTILITY PLANT
|
|||||||
Production
|
$
|
1,667,723
|
$
|
1,663,161
|
|||
Transmission
|
639,968
|
632,964
|
|||||
Distribution
|
1,133,748
|
1,114,480
|
|||||
General
|
435,127
|
427,910
|
|||||
Construction
Work in Progress
|
70,161
|
48,852
|
|||||
Total
|
3,946,727
|
3,887,367
|
|||||
Accumulated
Depreciation and Amortization
|
1,762,560
|
1,709,758
|
|||||
TOTAL
- NET
|
2,184,167
|
2,177,609
|
|||||
OTHER
PROPERTY AND INVESTMENTS
|
|||||||
Nonutility
Property, Net
|
4,047
|
4,049
|
|||||
Other
Investments
|
4,628
|
4,628
|
|||||
TOTAL
|
8,675
|
8,677
|
|||||
CURRENT
ASSETS
|
|||||||
Cash
and Cash Equivalents
|
4,591
|
2,308
|
|||||
Other
Cash Deposits
|
-
|
6,292
|
|||||
Advances
to Affiliates
|
188,077
|
39,106
|
|||||
Accounts
Receivable:
|
|||||||
Customers
|
39,842
|
39,042
|
|||||
Affiliated
Companies
|
16,447
|
28,817
|
|||||
Miscellaneous
|
5,215
|
5,856
|
|||||
Allowance
for Uncollectible Accounts
|
(5
|
)
|
(45
|
)
|
|||
Fuel
Inventory
|
44,260
|
45,793
|
|||||
Materials
and Supplies
|
36,022
|
36,051
|
|||||
Risk
Management Assets
|
7,456
|
25,379
|
|||||
Regulatory
Asset for Under-Recovered Fuel Costs
|
25,762
|
4,687
|
|||||
Margin
Deposits
|
1,341
|
3,419
|
|||||
Prepayments
and Other
|
17,048
|
18,331
|
|||||
TOTAL
|
386,056
|
255,036
|
|||||
DEFERRED
DEBITS AND OTHER ASSETS
|
|||||||
Regulatory
Assets:
|
|||||||
SFAS
109 Regulatory Asset, Net
|
21,903
|
18,000
|
|||||
Unamortized
Loss on Reacquired Debt
|
19,369
|
20,765
|
|||||
Other
|
13,234
|
16,350
|
|||||
Long-term
Risk Management Assets
|
9,095
|
17,179
|
|||||
Prepaid
Pension Obligations
|
80,599
|
81,132
|
|||||
Deferred
Property Taxes
|
19,047
|
-
|
|||||
Deferred
Charges
|
46,159
|
51,561
|
|||||
TOTAL
|
209,406
|
204,987
|
|||||
TOTAL
ASSETS
|
$
|
2,788,304
|
$
|
2,646,309
|
2005
|
2004
|
||||||
CAPITALIZATION
|
(in
thousands)
|
||||||
Common
Shareholder’s Equity:
|
|||||||
Common
Stock - $18 par value per share:
|
|||||||
Authorized
- 7,600,000 shares
|
|||||||
Outstanding
- 7,536,640 shares
|
$
|
135,660
|
$
|
135,660
|
|||
Paid-in
Capital
|
245,003
|
245,003
|
|||||
Retained
Earnings
|
395,529
|
389,135
|
|||||
Accumulated
Other Comprehensive Income (Loss)
|
(6,392
|
)
|
(1,180
|
)
|
|||
Total
Common Shareholder’s Equity
|
769,800
|
768,618
|
|||||
Cumulative
Preferred Stock Not Subject to Mandatory Redemption
|
4,700
|
4,700
|
|||||
Total
Shareholders’ Equity
|
774,500
|
773,318
|
|||||
Long-term
Debt:
|
|||||||
Nonaffiliated
|
690,546
|
545,395
|
|||||
Affiliated
|
50,000
|
50,000
|
|||||
Total
Long-term Debt
|
740,546
|
595,395
|
|||||
TOTAL
|
1,515,046
|
1,368,713
|
|||||
Minority
Interest
|
1,953
|
1,125
|
|||||
CURRENT
LIABILITIES
|
|||||||
Long-term
Debt Due Within One Year - Nonaffiliated
|
209,954
|
209,974
|
|||||
Accounts
Payable:
|
|||||||
General
|
56,582
|
40,001
|
|||||
Affiliated
Companies
|
42,099
|
33,285
|
|||||
Customer
Deposits
|
30,082
|
30,550
|
|||||
Taxes
Accrued
|
46,433
|
45,474
|
|||||
Interest
Accrued
|
12,049
|
12,509
|
|||||
Risk
Management Liabilities
|
8,038
|
18,607
|
|||||
Obligations
Under Capital Leases
|
4,781
|
3,692
|
|||||
Regulatory
Liability for Over-Recovered Fuel Costs
|
6,076
|
9,891
|
|||||
Other
|
34,419
|
33,417
|
|||||
TOTAL
|
450,513
|
437,400
|
|||||
DEFERRED
CREDITS AND OTHER LIABILITIES
|
|||||||
Deferred
Income Taxes
|
401,158
|
399,756
|
|||||
Long-term
Risk Management Liabilities
|
5,328
|
9,128
|
|||||
Reclamation
Reserve
|
-
|
7,624
|
|||||
Regulatory
Liabilities:
|
|||||||
Asset
Removal Costs
|
251,382
|
249,892
|
|||||
Deferred
Investment Tax Credits
|
33,392
|
35,539
|
|||||
Excess
Earnings
|
3,167
|
3,167
|
|||||
Other
|
6,667
|
21,320
|
|||||
Asset
Retirement Obligations
|
33,461
|
27,361
|
|||||
Obligations
Under Capital Leases
|
33,578
|
30,854
|
|||||
Deferred
Credits and Other
|
52,659
|
54,430
|
|||||
TOTAL
|
820,792
|
839,071
|
|||||
Commitments
and Contingencies (Note 5)
|
|||||||
TOTAL
CAPITALIZATION AND LIABILITIES
|
$
|
2,788,304
|
$
|
2,646,309
|
2005
|
2004
|
||||||
OPERATING
ACTIVITIES
|
|||||||
Net
Income
|
$
|
31,509
|
$
|
32,968
|
|||
Adjustments
to Reconcile Net Income to Net Cash Flows From
Operating Activities:
|
|||||||
Depreciation
and Amortization
|
65,650
|
63,264
|
|||||
Deferred
Property Taxes
|
(19,047
|
)
|
(19,375
|
)
|
|||
Deferred
Income Taxes
|
176
|
(4,519
|
)
|
||||
Deferred
Investment Tax Credits
|
(2,147
|
)
|
(2,163
|
)
|
|||
Mark-to-Market
of Risk Management Contracts
|
13,031
|
12,181
|
|||||
Over/Under
Fuel Recovery
|
(24,890
|
)
|
8,598
|
||||
Change
in Other Noncurrent Assets
|
6,326
|
(12,889
|
)
|
||||
Change
in Other Noncurrent Liabilities
|
(20,982
|
)
|
3,747
|
||||
Changes
in Components of Working Capital:
|
|||||||
Accounts
Receivable, Net
|
12,171
|
(4,473
|
)
|
||||
Fuel,
Materials and Supplies
|
1,562
|
2,110
|
|||||
Accounts
Payable
|
27,772
|
3,352
|
|||||
Taxes
Accrued
|
959
|
46,489
|
|||||
Customer
Deposits
|
(468
|
)
|
2,471
|
||||
Interest
Accrued
|
(460
|
)
|
(5,004
|
)
|
|||
Other
Current Assets
|
3,361
|
5,727
|
|||||
Other
Current Liabilities
|
3,616
|
(19,518
|
)
|
||||
Net
Cash Flows From Operating Activities
|
98,139
|
112,966
|
|||||
INVESTING
ACTIVITIES
|
|||||||
Construction
Expenditures
|
(72,150
|
)
|
(45,879
|
)
|
|||
Change
in Other Cash Deposits, Net
|
6,292
|
803
|
|||||
Proceeds
from Sale of Assets
|
108
|
2,316
|
|||||
Net
Cash Flows Used For Investing Activities
|
(65,750
|
)
|
(42,760
|
)
|
|||
FINANCING
ACTIVITIES
|
|||||||
Issuance
of Long-term Debt
|
148,895
|
92,441
|
|||||
Retirement
of Long-term Debt
|
(4,915
|
)
|
(220,000
|
)
|
|||
Changes
in Advances to/from Affiliates, Net
|
(148,971
|
)
|
93,394
|
||||
Dividends
Paid on Common Stock
|
(25,000
|
)
|
(30,000
|
)
|
|||
Dividends
Paid on Cumulative Preferred Stock
|
(115
|
)
|
(115
|
)
|
|||
Net
Cash Flows Used For Financing Activities
|
(30,106
|
)
|
(64,280
|
)
|
|||
Net
Increase in Cash and Cash Equivalents
|
2,283
|
5,926
|
|||||
Cash
and Cash Equivalents at Beginning of Period
|
2,308
|
5,676
|
|||||
Cash
and Cash Equivalents at End of Period
|
$
|
4,591
|
$
|
11,602
|
SUPPLEMENTAL
DISCLOSURE:
|
Cash
paid for interest net of capitalized amounts was $22,279,000
and
$29,841,000 and for income taxes was $35,969,000 and $3,220,000
in 2005
and 2004, respectively. Noncash capital lease acquisitions
were $2,035,000
and $16,379,000 in 2005 and 2004, respectively. Construction
Expenditures
include the change in construction-related Accounts Payable
of
$(2,377,000) and $164,000 in 2005 and 2004,
respectively.
|
See
Condensed Notes to Financial Statements of Registrant
Subsidiaries.
|
Footnote
Reference
|
|
Significant
Accounting Matters
|
Note
1
|
New
Accounting Pronouncements
|
Note
2
|
Rate
Matters
|
Note
3
|
Commitments
and Contingencies
|
Note
5
|
Guarantees
|
Note
6
|
Benefit
Plans
|
Note
8
|
Business
Segments
|
Note
9
|
Financing
Activities
|
Note
11
|
Company-wide
Staffing and Budget Review
|
Note
12
|
The
condensed notes to financial statements that follow are a combined
presentation for AEP’s registrant subsidiaries. The following list
indicates the registrants to which the footnotes apply:
|
||
1.
|
Significant
Accounting Matters
|
AEGCo,
APCo, CSPCo, I&M, KPCo, OPCo, PSO, SWEPCo, TCC, TNC
|
2.
|
New
Accounting Pronouncements
|
AEGCo,
APCo, CSPCo, I&M, KPCo, OPCo, PSO, SWEPCo, TCC, TNC
|
3.
|
Rate
Matters
|
APCo,
CSPCo, I&M, KPCo, OPCo, PSO, SWEPCo, TCC, TNC
|
4.
|
Customer
Choice and Industry
Restructuring
|
CSPCo,
OPCo, TCC, TNC
|
5.
|
Commitments
and Contingencies
|
AEGCo,
APCo, CSPCo, I&M, KPCo, OPCo, PSO, SWEPCo, TCC, TNC
|
6.
|
Guarantees
|
AEGCo,
APCo, CSPCo, I&M, KPCo, OPCo, PSO, SWEPCo, TCC, TNC
|
7.
|
Acquisitions,
Dispositions and Assets
Held for Sale
|
CSPCo,
TCC
|
8.
|
Benefit
Plans
|
APCo,
CSPCo, I&M, KPCo, OPCo, PSO, SWEPCo, TCC, TNC
|
9.
|
Business
Segments
|
AEGCo,
APCo, CSPCo, I&M, KPCo, OPCo, PSO, SWEPCo, TCC, TNC
|
10.
|
Income
Taxes
|
APCo,
CSPCo, OPCo, PSO, TCC
|
11.
|
Financing
Activities
|
AEGCo,
APCo, CSPCo, I&M, KPCo, OPCo, PSO, SWEPCo, TCC, TNC
|
12.
|
Company-wide
Staffing and Budget Review
|
AEGCo,
APCo, CSPCo, I&M, KPCo, OPCo, PSO, SWEPCo, TCC,
TNC
|
June
30,
|
December
31,
|
||||||
2005
|
2004
|
||||||
(in
thousands)
|
|||||||
Components
|
|||||||
Cash
Flow Hedges:
|
|||||||
APCo
|
$
|
(23,206
|
)
|
$
|
(9,324
|
)
|
|
CSPCo
|
(2,892
|
)
|
1,393
|
||||
I&M
|
(8,768
|
)
|
(4,076
|
)
|
|||
KPCo
|
(1,143
|
)
|
813
|
||||
OPCo
|
(5,858
|
)
|
1,241
|
||||
PSO
|
(1,083
|
)
|
400
|
||||
SWEPCo
|
(6,032
|
)
|
(820
|
)
|
|||
TCC
|
(357
|
)
|
657
|
||||
TNC
|
(154
|
)
|
285
|
||||
Minimum
Pension Liability:
|
|||||||
APCo
|
$
|
(72,348
|
)
|
$
|
(72,348
|
)
|
|
CSPCo
|
(62,209
|
)
|
(62,209
|
)
|
|||
I&M
|
(41,175
|
)
|
(41,175
|
)
|
|||
KPCo
|
(9,588
|
)
|
(9,588
|
)
|
|||
OPCo
|
(75,505
|
)
|
(75,505
|
)
|
|||
PSO
|
(325
|
)
|
(325
|
)
|
|||
SWEPCo
|
(360
|
)
|
(360
|
)
|
|||
TCC
|
(4,816
|
)
|
(4,816
|
)
|
|||
TNC
|
(413
|
)
|
(413
|
)
|
Balance
at January 1, 2005
|
Accretion
|
Liabilities
Incurred
|
Liabilities
Settled
|
Revisions
in Cash Flow Estimates
|
Balance
at June 30, 2005
|
||||||||||||||
(in
millions)
|
|||||||||||||||||||
AEGCo
(a)
|
$
|
1.2
|
$
|
0.1
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
1.3
|
|||||||
APCo
(a)
|
24.6
|
1.0
|
-
|
-
|
-
|
25.6
|
|||||||||||||
CSPCo
(a)
|
11.6
|
0.4
|
-
|
-
|
-
|
12.0
|
|||||||||||||
I&M
(b)
|
711.8
|
23.6
|
-
|
-
|
-
|
735.4
|
|||||||||||||
OPCo
(a)
|
45.6
|
1.8
|
-
|
-
|
-
|
47.4
|
|||||||||||||
SWEPCo
(c)
|
27.4
|
0.6
|
8.8
|
(0.1
|
)
|
-
|
36.7
|
||||||||||||
TCC
(d)
|
248.9
|
7.5
|
-
|
(256.4
|
)
|
-
|
-
|
(a)
|
Consists
of ARO related to ash ponds.
|
(b)
|
Consists
of ARO related to ash ponds ($1.3 million at June 30, 2005) and
nuclear
decommissioning costs for the Cook Plant ($734.1 million at June
30,
2005).
|
(c)
|
Consists
of ARO related to Sabine Mining Company and Dolet Hills Lignite
Company,
LLC (Dolet Hills). The current portion of Dolet Hills ARO, totaling
$3.2
million, is included in Other in the Current Liabilities section
of
SWEPCo’s June 30, 2005 Condensed Consolidated Balance
Sheet.
|
(d)
|
The
ARO for TCC’s share of STP was included in Liabilities Held for Sale -
Texas Generation Plants in TCC’s Consolidated Balance Sheet at December
31, 2004 and was subsequently transferred to the buyer with the
sale in
the second quarter of 2005 (see “Texas Plants - South Texas Project”
section of Note 7).
|
Three
Months Ended
June
30, 2005
|
Six
Months
Ended
June
30, 2005
|
December
2004
|
||||||||
Company
|
(in
millions)
|
|||||||||
APCo
|
$
|
10.4
|
$
|
19.0
|
$
|
3.5
|
||||
CSPCo
|
5.3
|
9.6
|
2.0
|
|||||||
I&M
|
5.9
|
10.8
|
2.3
|
|||||||
KPCo
|
2.5
|
4.5
|
0.8
|
|||||||
OPCo
|
7.4
|
13.5
|
2.8
|
PJM-Billed
Integration Costs
|
Non-PJM
Billed Formation/
Integration
Costs
|
||||||
Company
|
(in
millions)
|
||||||
APCo
|
$
|
4.8
|
$
|
5.1
|
|||
CSPCo
|
2.0
|
2.2
|
|||||
I&M
|
3.8
|
3.8
|
|||||
KPCo
|
1.1
|
1.1
|
|||||
OPCo
|
5.5
|
5.7
|
PJM-Billed
Integration Costs
|
Non-PJM
Billed Formation/
Integration
Costs
|
||||||
Company
|
(in
millions)
|
||||||
APCo
|
$
|
5.0
|
$
|
4.7
|
|||
CSPCo
|
2.1
|
2.0
|
|||||
I&M
|
3.9
|
3.5
|
|||||
KPCo
|
1.2
|
1.0
|
|||||
OPCo
|
5.8
|
5.2
|
TCC
|
|||||||
June
30, 2005
|
December
31, 2004
|
||||||
(in
millions)
|
|||||||
Stranded
Generation Plant Costs
|
$
|
887
|
$
|
897
|
|||
Net
Generation-related Regulatory Asset
|
249
|
249
|
|||||
Unrefunded
Excess Earnings
|
(3
|
)
|
(10
|
)
|
|||
Net
Stranded Generation Costs
|
1,133
|
1,136
|
|||||
Carrying
Costs on Stranded Generation Plant Costs
|
215
|
225
|
|||||
Net
Stranded Generation Costs Designated for
Securitization
|
1,348
|
1,361
|
|||||
Wholesale
Capacity Auction True-up
|
483
|
483
|
|||||
Carrying
Costs on Wholesale Capacity Auction True-up
|
102
|
77
|
|||||
Retail
Clawback
|
(61
|
)
|
(61
|
)
|
|||
Deferred
Over-recovered Fuel Balance
|
(209
|
)
|
(212
|
)
|
|||
Net
Other Recoverable True-up Amounts
|
315
|
287
|
|||||
Total
Recorded Net True-up Regulatory Asset
|
$
|
1,663
|
$
|
1,648
|
TNC
|
|||||||
June
30, 2005
|
December
31, 2004
|
||||||
(in
millions)
|
|||||||
Retail
Clawback
|
$
|
(14
|
)
|
$
|
(14
|
)
|
|
Deferred
Over-recovered Fuel Balance
|
(5
|
)
|
(4
|
)
|
|||
Total
Recorded Net True-up Regulatory Liability
|
$
|
(19
|
)
|
$
|
(18
|
)
|
Maximum
Potential Loss
|
||||
Subsidiary
|
(in
millions)
|
|||
APCo
|
$
|
6
|
||
CSPCo
|
2
|
|||
I&M
|
4
|
|||
KPCo
|
1
|
|||
OPCo
|
5
|
|||
PSO
|
4
|
|||
SWEPCo
|
4
|
|||
TCC
|
6
|
|||
TNC
|
3
|
Texas
Plants
|
|||||||
June
30, 2005
|
December
31, 2004
|
||||||
Assets:
|
(in
millions)
|
||||||
Other
Current Assets
|
$
|
2
|
$
|
24
|
|||
Property,
Plant and Equipment, Net
|
44
|
413
|
|||||
Regulatory
Assets
|
-
|
48
|
|||||
Nuclear
Decommissioning Trust Fund
|
-
|
143
|
|||||
Total
Assets Held for Sale - Texas Generation Plants
|
$
|
46
|
$
|
628
|
|||
Liabilities:
|
|||||||
Regulatory
Liabilities
|
$
|
1
|
$
|
1
|
|||
Asset
Retirement Obligations
|
-
|
249
|
|||||
Total
Liabilities Held for Sale - Texas Generation
Plants
|
$
|
1
|
$
|
250
|
Three
Months Ended June 30, 2005 and 2004
|
Pension
Plans
|
Other
Postretirement Benefit Plans
|
|||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
(in
millions)
|
|||||||||||||
Service
Cost
|
$
|
23
|
$
|
21
|
$
|
10
|
$
|
10
|
|||||
Interest
Cost
|
56
|
56
|
26
|
29
|
|||||||||
Expected
(Return) on Plan Assets
|
(78
|
)
|
(72
|
)
|
(22
|
)
|
(20
|
)
|
|||||
Amortization
of Transition Obligation
|
-
|
1
|
7
|
7
|
|||||||||
Amortization
of Net Actuarial Loss
|
14
|
4
|
7
|
9
|
|||||||||
Net
Periodic Benefit Cost
|
$
|
15
|
$
|
10
|
$
|
28
|
$
|
35
|
Six
Months Ended June 30, 2005 and 2004
|
Pension
Plans
|
Other
Postretirement Benefit Plans
|
|||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
(in
millions)
|
|||||||||||||
Service
Cost
|
$
|
46
|
$
|
43
|
$
|
21
|
$
|
20
|
|||||
Interest
Cost
|
112
|
112
|
53
|
58
|
|||||||||
Expected
(Return) on Plan Assets
|
(155
|
)
|
(144
|
)
|
(45
|
)
|
(40
|
)
|
|||||
Amortization
of Transition Obligation
|
-
|
1
|
14
|
14
|
|||||||||
Amortization
of Net Actuarial Loss
|
27
|
8
|
14
|
18
|
|||||||||
Net
Periodic Benefit Cost
|
$
|
30
|
$
|
20
|
$
|
57
|
$
|
70
|
Three
Months Ended June 30, 2005 and 2004
|
Pension
Plans
|
Other
Postretirement Benefit Plans
|
|||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
(in
thousands)
|
|||||||||||||
APCo
|
$
|
1,848
|
$
|
318
|
$
|
5,147
|
$
|
6,462
|
|||||
CSPCo
|
534
|
(407
|
)
|
2,123
|
2,765
|
||||||||
I&M
|
2,365
|
1,114
|
3,464
|
4,313
|
|||||||||
KPCo
|
376
|
144
|
571
|
742
|
|||||||||
OPCo
|
1,206
|
(105
|
)
|
3,632
|
4,801
|
||||||||
PSO
|
72
|
700
|
1,799
|
2,110
|
|||||||||
SWEPCo
|
364
|
901
|
1,765
|
2,101
|
|||||||||
TCC
|
(219
|
)
|
746
|
1,935
|
2,535
|
||||||||
TNC
|
41
|
338
|
846
|
1,073
|
Six
Months Ended June 30, 2005 and 2004
|
Pension
Plans
|
Other
Postretirement Benefit Plans
|
|||||||||||
2005
|
2004
|
2005
|
2004
|
||||||||||
(in
thousands)
|
|||||||||||||
APCo
|
$
|
3,696
|
$
|
636
|
$
|
10,492
|
$
|
12,924
|
|||||
CSPCo
|
1,068
|
(814
|
)
|
4,345
|
5,530
|
||||||||
I&M
|
4,730
|
2,228
|
7,095
|
8,626
|
|||||||||
KPCo
|
752
|
288
|
1,174
|
1,484
|
|||||||||
OPCo
|
2,412
|
(210
|
)
|
7,459
|
9,602
|
||||||||
PSO
|
144
|
1,400
|
3,668
|
4,220
|
|||||||||
SWEPCo
|
728
|
1,802
|
3,602
|
4,202
|
|||||||||
TCC
|
(438
|
)
|
1,492
|
3,943
|
5,070
|
||||||||
TNC
|
82
|
676
|
1,723
|
2,146
|
Company
|
Amount
(in
thousands)
|
|||
CSPCo
|
$
|
15,104
|
||
OPCo
|
41,864
|
|||
APCo
|
2,769
|
|||
PSO
|
706
|
|||
TCC
|
365
|
Company
|
Type
of Debt
|
Principal
Amount
|
Interest
Rate
|
Due
Date
|
|||||
(in
thousands)
|
(%)
|
||||||||
Issuances:
|
|||||||||
APCo
|
Senior
Unsecured Notes
|
$
|
200,000
|
4.95%
|
2015
|
||||
APCo
|
Senior
Unsecured Notes
|
150,000
|
4.40%
|
2010
|
|||||
APCo
|
Senior
Unsecured Notes
|
250,000
|
5.00%
|
2017
|
|||||
OPCo
|
Installment
Purchase Contracts
|
54,500
|
Variable
|
2029
|
|||||
OPCo
|
Installment
Purchase Contracts
|
163,500
|
Variable
|
2028
|
|||||
PSO
|
Senior
Unsecured Notes
|
75,000
|
4.70%
|
2011
|
|||||
SWEPCo
|
Senior
Unsecured Notes
|
150,000
|
4.90%
|
2015
|
|||||
TCC
|
Installment
Purchase Contracts
|
161,700
|
Variable
|
2030
|
|||||
TCC
|
Installment
Purchase Contracts
|
120,265
|
Variable
|
2028
|
Company
|
Type
of Debt
|
Principal
Amount
|
Interest
Rate
|
Due
Date
|
|||||
(in
thousands)
|
(%)
|
||||||||
Retirements
and Principal
Payments:
|
|||||||||
APCo
|
Other
Debt
|
$
|
5
|
13.718%
|
2026
|
||||
APCo
|
First
Mortgage Bonds
|
50,000
|
8.00%
|
2005
|
|||||
APCo
|
First
Mortgage Bonds
|
30,000
|
6.89%
|
2005
|
|||||
APCo
|
First
Mortgage Bonds
|
45,000
|
8.00%
|
2025
|
|||||
APCo
|
Senior
Unsecured Notes
|
450,000
|
4.80%
|
2005
|
|||||
OPCo
|
Installment
Purchase Contracts
|
102,000
|
6.375%
|
2029
|
|||||
OPCo
|
Installment
Purchase Contracts
|
80,000
|
Variable
|
2028
|
|||||
OPCo
|
Installment
Purchase Contracts
|
36,000
|
Variable
|
2029
|
|||||
OPCo
|
Notes
Payable
|
2,927
|
6.81%
|
2008
|
|||||
OPCo
|
Notes
Payable
|
3,250
|
6.27%
|
2009
|
|||||
PSO
|
First
Mortgage Bonds
|
50,000
|
6.50%
|
2005
|
|||||
SWEPCo
|
Notes
Payable
|
3,415
|
4.47%
|
2011
|
|||||
SWEPCo
|
Notes
Payable
|
1,500
|
Variable
|
2008
|
|||||
TCC
|
Senior
Unsecured Notes
|
150,000
|
3.00%
|
2005
|
|||||
TCC
|
Senior
Unsecured Notes
|
100,000
|
Variable
|
2005
|
|||||
TCC
|
Securitization
Bonds
|
29,386
|
3.54%
|
2005
|
Company
|
Type
of Debt
|
Principal
Amount
|
Interest
Rate
|
Due
Date
|
|||||
(in
thousands)
|
(%)
|
||||||||
Issuances:
|
|||||||||
APCo
|
Notes
Payable
|
$
|
100,000
|
4.708%
|
2010
|
||||
Retirements:
|
|||||||||
KPCo
|
Notes
Payable
|
$
|
20,000
|
6.501%
|
2006
|
Company
|
Series
|
Number
of Shares Redeemed
|
Amount
|
|||||
(in
millions)
|
||||||||
I&M
|
5.900%
|
132,000
|
$
|
13
|
||||
I&M
|
6.250%
|
192,500
|
19
|
|||||
I&M
|
6.875%
|
157,500
|
16
|
|||||
I&M
|
6.300%
|
132,450
|
13
|
|||||
OPCo
|
5.900%
|
50,000
|
5
|
|||||
$
|
66
|
Company
|
Maximum
Borrowings from Utility Money Pool
|
Maximum
Loans to Utility Money Pool
|
Average
Borrowings from Utility Money Pool
|
Average
Loans to Utility Money Pool
|
Loans
(Borrowings) to/from Utility Money Pool as of June 30,
2005
|
SEC
Authorized Short-Term Borrowing Limit
|
|||||||||||||
(in
thousands)
|
|||||||||||||||||||
AEGCo
|
$
|
45,694
|
$
|
9,305
|
$
|
16,070
|
$
|
4,803
|
$
|
(24,621
|
)
|
$
|
125,000
|
||||||
APCo
|
236,798
|
321,977
|
95,331
|
47,143
|
(176,692
|
)
|
600,000
|
||||||||||||
CSPCo
|
-
|
181,238
|
-
|
104,861
|
62,172
|
350,000
|
|||||||||||||
I&M
|
203,248
|
11,768
|
81,472
|
5,797
|
(143,126
|
)
|
500,000
|
||||||||||||
KPCo
|
3,386
|
35,779
|
2,307
|
17,596
|
12,647
|
200,000
|
|||||||||||||
OPCo
|
44,192
|
182,495
|
22,467
|
80,796
|
(11,528
|
)
|
600,000
|
||||||||||||
PSO
|
55,009
|
55,602
|
22,523
|
26,635
|
7,084
|
300,000
|
|||||||||||||
SWEPCo
|
221
|
188,215
|
221
|
42,793
|
188,077
|
350,000
|
|||||||||||||
TCC
|
320,508
|
120,937
|
152,714
|
49,350
|
(120,064
|
)
|
600,000
|
||||||||||||
TNC
|
-
|
75,045
|
-
|
49,428
|
63,665
|
250,000
|
Company
|
Average
Interest Rate for Funds Borrowed from the Utility Money
Pool
|
Average
Interest Rate for Funds Loaned to the Utility Money
Pool
|
|||||
(in
percentages)
|
|||||||
AEGCo
|
2.40
|
3.14
|
|||||
APCo
|
2.65
|
2.69
|
|||||
CSPCo
|
-
|
2.44
|
|||||
I&M
|
2.96
|
2.12
|
|||||
KPCo
|
2.96
|
2.42
|
|||||
OPCo
|
3.32
|
2.39
|
|||||
PSO
|
2.50
|
3.19
|
|||||
SWEPCo
|
3.21
|
2.54
|
|||||
TCC
|
2.91
|
2.12
|
|||||
TNC
|
-
|
2.65
|
Company
|
Amounts
(in
millions)
|
|||
AEGCo
|
$
|
0.2
|
||
APCo
|
3.9
|
|||
CSPCo
|
2.3
|
|||
I&M
|
4.0
|
|||
KPCo
|
0.7
|
|||
OPCo
|
3.4
|
|||
PSO
|
1.2
|
|||
SWEPCo
|
1.6
|
|||
TCC
|
3.8
|
|||
TNC
|
1.1
|
Three
Months Ended June 30, 2005
|
Six
Months
Ended
June 30, 2005
|
December
2004
|
||||||||
Company
|
(in
millions)
|
|||||||||
APCo
|
$
|
10.4
|
$
|
19.0
|
$
|
3.5
|
||||
CSPCo
|
5.3
|
9.6
|
2.0
|
|||||||
I&M
|
5.9
|
10.8
|
2.3
|
|||||||
KPCo
|
2.5
|
4.5
|
0.8
|
|||||||
OPCo
|
7.4
|
13.5
|
2.8
|
·
|
Legislative
and regulatory proposals to adopt stringent controls on sulfur
dioxide
(SO2),
nitrogen oxide (NOx)
and mercury emissions from coal-fired power plants,
|
·
|
Clean
Water Act rules to reduce the impacts of water intake structures
on
aquatic species at certain of our power plants, and
|
·
|
Possible
future requirements to reduce carbon dioxide emissions to address
concerns
about global climatic change.
|
·
|
The
Federal EPA proposed a Clean Air Interstate Rule (CAIR) to reduce
SO2
and NOx
emissions across the Eastern United States (29 states and the District
of
Columbia) and make progress toward attainment of the new fine particulate
matter and ground-level ozone national ambient air quality standards.
These reductions could also satisfy these states’ obligations to make
reasonable progress towards the national visibility goal under
the
regional haze program.
|
·
|
The
Federal EPA proposed to regulate mercury emissions from coal-fired
electric generating units.
|
Period
|
Total
Number
of
Shares
Purchased
(a)
|
Average
Price
Paid
per Share
|
Total
Number Of Shares Purchased as Part of Publicly Announced Plans
or
Programs
|
Maximum
Number (or Approximate Dollar Value) of Shares that May Yet Be
Purchased
Under the Plans or Programs
|
|||||||||
04/01/05
- 04/30/05
|
-
|
$
|
-
|
-
|
$
|
-
|
|||||||
05/01/05
- 05/31/05
|
1
|
82.00
|
-
|
-
|
|||||||||
06/01/05
- 06/30/05
|
-
|
-
|
-
|
-
|
|||||||||
Total
|
1
|
$
|
82.00
|
-
|
$
|
-
|
(a)
|
OPCo repurchased 1 share of its 4.5% cumulative preferred stock, in a privately-negotiated transaction outside of an announced program. |
1. |
Election
of eleven directors to hold office until the next annual meeting
and until
their successors are duly elected. Each nominee for director received
the
votes of shareholders as follows:
|
No.
of Shares Voted For
|
No.
of Shares Abstaining
|
||
E.
R. Brooks
|
263,054,307
|
75,891,318
|
|
Donald
M. Carlton
|
328,620,376
|
10,325,249
|
|
John
P. DesBarres
|
328,782,449
|
10,163,176
|
|
Robert
W. Fri
|
328,507,125
|
10,438,500
|
|
William
R. Howell
|
329,883,269
|
9,062,356
|
|
Lester
A. Hudson, Jr.
|
330,110,186
|
8,835,439
|
|
Michael
G. Morris
|
330,275,243
|
8,670,382
|
|
Lionel
L. Nowell, III
|
332,065,869
|
6,879,756
|
|
Richard
L. Sandor
|
330,065,869
|
8,687,824
|
|
Donald
G. Smith
|
330,181,157
|
8,764,468
|
|
Kathryn
D. Sullivan
|
330,057,810
|
8,887,815
|
2. |
Ratification
of the appointment of the firm of Deloitte & Touche LLP as the
independent registered public accounting firm for 2005. The proposal
was
approved by a vote of the shareholders as
follows:
|
Votes
FOR
|
322,692,857
|
|
Votes
AGAINST
|
12,412,630
|
|
Votes
ABSTAINED
|
3,840,138
|
|
Broker
NON-VOTES*
|
0
|
3. |
Approval
of an amendment to the AEP System Long-term Incentive Plan. The
proposal
was approved by a vote of the shareholders as
follows:
|
Votes
FOR
|
249,862,019
|
|
Votes
AGAINST
|
28,710,198
|
|
Votes
ABSTAINED
|
8,059,517
|
|
Broker
NON-VOTES*
|
52,313,891
|
Carl
L. English
|
Michael
G. Morris
|
|
John
B. Keane
|
Robert
P. Powers
|
|
Holly
K. Koeppel
|
Stephen
P. Smith
|
|
Venita
McCellon-Allen
|
Susan
Tomasky
|
Carl
L. English
|
Michael
G. Morris
|
|
Thomas
M. Hagan
|
Robert
P. Powers
|
|
John
B. Keane
|
Stephen
P. Smith
|
|
Venita
McCellon-Allen
|
Susan
Tomasky
|
Karl
G. Boyd
|
Venita
McCellon-Allen
|
|
John
E. Ehler
|
Susanne
M. Moorman Rowe
|
|
Carl
L. English
|
Michael
G. Morris
|
|
Patrick
C. Hale
|
Robert
P. Powers
|
|
Holly
K. Koeppel
|
John
R. Sampson
|
|
David
L. Lahrman
|
Susan
Tomasky
|
|
Marc
E. Lewis
|
Carl
L. English
|
Michael
G. Morris
|
|
John
B. Keane
|
Robert
P. Powers
|
|
Holly
K. Koeppel
|
Stephen
P. Smith
|
|
Venita
McCellon-Allen
|
Susan
Tomasky
|
Carl
L. English
|
Michael
G. Morris
|
|
Thomas
M. Hagan
|
Robert
P. Powers
|
|
John
B. Keane
|
Stephen
P. Smith
|
|
Venita
McCellon-Allen
|
Susan
Tomasky
|