1
4Q10 Earnings Release Presentation
January 28, 2011
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This presentation contains forward-looking statements within the meaning of Section 21E of the Securities Exchange Act of 1934. Although AEP and each of its Registrant Subsidiaries believe that their expectations are based on reasonable assumptions, any such statements may be influenced by factors that could cause actual outcomes and results to be materially different from those projected. Among the factors that could cause actual results to differ materially from those in the forward-looking statements are: the economic climate and growth in, or contraction within, our service territory and changes in market demand and demographic patterns, inflationary or deflationary interest rate trends, volatility in the financial markets, particularly developments affecting the availability of capital on reasonable terms and developments impairing our ability to finance new capital projects and refinance existing debt at attractive rates, the availability and cost of funds to finance working capital and capital needs, particularly during periods when the time lag between incurring costs and recovery is long and the costs are material, electric load, customer growth and the impact of retail competition, weather conditions, including storms, and our ability to recover significant storm restoration costs through applicable rate mechanisms, available sources and costs of, and transportation for, fuels and the creditworthiness and performance of fuel suppliers and transporters, availability of necessary generating capacity and the performance of our generating plants, our ability to recover I&M’s Donald C. Cook Nuclear Plant Unit 1 restoration costs through warranty, insurance and the regulatory process, our ability to recover regulatory assets and stranded costs in connection with deregulation, our ability to recover increases in fuel and other energy costs through regulated or competitive electric rates, our ability to build or acquire generating capacity, including the Turk Plant, and transmission line facilities (including our ability to obtain any necessary regulatory approvals and permits) when needed at acceptable prices and terms and to recover those costs (including the costs of projects that are cancelled) through applicable rate cases or competitive rates, new legislation, litigation and government regulation including requirements for reduced emissions of sulfur, nitrogen, mercury, carbon, soot or particulate matter and other substances or additional regulation of fly ash and similar combustion products that could impact the continued operation and cost recovery of our plants, timing and resolution of pending and future rate cases, negotiations and other regulatory decisions (including rate or other recovery of new investments in generation, distribution and transmission service and environmental compliance), resolution of litigation (including the dispute with Bank of America), our ability to constrain operation and maintenance costs, 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 of the counterparties with whom we have contractual arrangements, including participants in the energy trading market, actions of rating agencies, including changes in the ratings of debt, volatility and changes in markets for electricity, natural gas, coal, nuclear fuel and other energy-related commodities, changes in utility regulation, including the implementation of ESPs and related regulation in Ohio and theallocation of costs within regional transmission organizations, including PJM and SPP, accounting pronouncements periodically issued by accounting standard-setting bodies, the impact of volatility in the capital markets on the value of the investments held by our pension, other postretirement benefit plans and nuclear decommissioning trust and the impact on future funding requirements, prices and demand 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 and our ability to recover through rates the remaining unrecovered investment, if any, in generating units that may be retired before the end of their previously projected useful lives.
Investor Relations Contacts
“Safe Harbor” Statement under the Private Securities Litigation Reform Act of 1995
Chuck ZebulaTreasurer
SVP Investor Relations614-716-2800
Bette Jo RozsaManaging DirectorInvestor Relations
Julie SherwoodDirector
Investor Relations614-716-2663
Sara MaciochAnalyst
Investor Relations614-716-2835
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2010 Highlights
— 4Q10 and YTD GAAP earnings of $0.37 and $2.53 per share, respectively
— 4Q10 and YTD on-going earnings of $0.38 and $ 3.03 per share, respectively
— $329M in rate changes throughout all jurisdictions, $222M net of offsets
— Overall AEP System on-going ROE of 10.75%
— Increased quarterly dividend 12%
— Total shareholder return of 8.7%
2010 Highlights and 2011 Plan
2011 Plan
― Financial Performance
— Earnings guidance of $3.00 to $3.20 per share
— Maintain fiscal discipline around O&M and capital spending
— Regulatory Plan
— Rate proceedings – $162M of $235M secured (69%)
— Ohio Filings – ESP, Distribution Cases, Environmental Cases, 2010 SEET
— Policy Update
― EPA
― Transmission
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AEP Ohio ESP Filing – Core Policy Issues
Investment in Ohio
Supports economic development and essential tax base
Fundamental barriers must be addressed to attract
investment for Environmental Compliance and New
Generation
Jobs in Ohio
Jobs are a key component of growth
potential in Ohio
Without regulatory assurances over time we could see loss of direct & indirect jobs related to
power generation, and business relocations to
surrounding states
Energy Security
Secure, reliable and predictable electricity
supply is basis for sustained investment and
employment in Ohio
Volatility in power prices can lead to major loss of
economic activity over time
Merged
AEP OhioRate Redesign
Distribution Components
Included
Single merged AEP Ohio company
presumed with supporting
information on an individual OP/CSP
basis
Generation rates redesigned to
resemble market pricing structures
Inclusion of certain distribution
components while pursuing a parallel distribution base
rate case
29-Month ESP Period
ESP period Jan 1, 2012 through May 31,2014 (May 31 date aligns with
PJM annual planning cycle)
Alternative Long Term Option
Alternative longer-term price certainty option offered for
qualifying commercial &
industrial customers
Ohio Growth Fund
Creation of significant private sector economic development to
attract investment and job growth in AEP Ohio service
territory
Primary objective of ESP: Stabilize rates and support economic development in the state of Ohio
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Summary of ESP Filing
The proposed 2012-2014 AEP Ohio ESP contains a balanced set of customer programs, investment proposals, supply options and associated rate mechanisms. The terms of the proposed ESP offer AEP Ohio customers
stable and affordable electricity rates while offering investors reasonable financial stability and returns.
Generation Rate Realignment
Alternative Longer-Term Price Certainty Option
Fuel Adjustment Clause Mechanism
POLR Provision
Recovery of Generation Related Facility Closure Costs
Interruptible Power Tariff
Plug-in Electric Vehicles Tariff
Pool Modification Provision
Partnership with Ohio Fund
Economic Development Rider
Distribution Investment Rider
Storm Damage Recovery
Key Provisions Included in ESP:
Pre-tax earnings impact from proposed ESP (excluding potential earnings impact from trackers): Net base $54MM or 1.4% in year 1 (2012) Net base $106MM or 2.7% in year 2 (2013)
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4Q10 Performance DriversFourth Quarter Reconciliation
4Q10 Performance
Firm Wholesale Margin down $17M due to the loss of two large wholesale customers
SEET refund of $43M related to PUCO order in the 2009 SEET filing for CSPCo
Non-Utility Operations/Parent decreased $37M primarily due to a contribution to the AEP Foundation and a fleet lease buyout
Other Utility Operations, net decreased approximately $88M and primarily includes the absence of accidental outage insurance and higher taxes
Off-System Sales were favorable by $10M due to higher prices and volume and lower sharing, offset by lower trading
Retail Margin up $18M due to increased industrial usage
Weather was favorable by $26M vs. prior year, $15M vs. normal
Rate Changes net of offsets $51M from multiple operating jurisdictions
O&M expense net of offsets decreased $63M primarily due to lower storm restoration expenses and cost savings initiatives.
OngoingEarnings
EPS ($ in millions)4Q09 0.50$ $238
Share Count Effect (0.01)$ Firm Wholesale Margin (0.02)$ SEET Refund (0.06)$ Non-Utility Operations, net (0.07)$ Other Utility Operations, net (0.18)$ Off-System Sales 0.01$ Retail Margin 0.02$ Weather 0.04$ Rate Changes 0.07$ Operations & Maintenance 0.08$ 4Q10 0.38$ $179
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Annual Performance DriversAnnual Reconciliation
December YTD Performance
Non-Utility Operations/Parent decreased $19M primarily due to a contribution to the AEP Foundation and a fleet lease buyout, somewhat offset by favorable tax adjustments
SEET refund of $43M related to PUCO order in the 2009 SEET filing for CSPCo
Firm Wholesale Margin down $74M due to the loss of two large wholesale customers
Share count impact due to 20M weighted average shares outstanding increase (459M to 479M) from equity offering and DRP
Other Utility Operations, net decreased approximately $238M and primarily includes the absence of accidental outage insurance related to the DC Cook nuclear plant and higher interest expense, depreciation and taxes
Retail Margin up $48M, due to economic recovery, primarily in the industrial class
Off-System Sales increase $53M with increased sales in the east offsetting decreased trading/marketing profits
O&M decrease of $97M net of offsets, primarily due to lower storm restoration expenses and cost savings initiatives
Weather was favorable by $229M vs. prior year, $164M vs. normal
Rate Changes net of offsets of $222M from multiple operating jurisdictions
Ongoing Earnings
EPS ($ in millions)2009 2.97$ $1,362
Non-Utility Operations, net (0.05)$ SEET Refund (0.06)$ Firm Wholesale Margin (0.10)$ Share Count Effect (0.14)$ Other Utility Operations, net (0.52)$ Retail Margin 0.07$ Off-System Sales 0.08$ Operations & Maintenance 0.14$ Weather 0.32$ Rate Changes 0.32$ 2010 3.03$ $1,451
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Normalized Load Trends
2.1% 1.3%
-1.2%
0.6%-0.3% 1.9%
-5%
0%
5%
10%
15%
1Q10 2Q10 3Q10 4Q10 YTD 10 2011E
-1.6%
2.0%
-1.6%-0.4%
0.7%
-0.3%-5%
0%
5%
10%
15%
1Q10 2Q10 3Q10 4Q10 YTD 10 2011E
-1.0%
9.4%
6.0%7.0%
5.3%
1.9%
-5%
0%
5%
10%
15%
1Q10 2Q10 3Q10 4Q10 YTD 10 2011E
-1.6%
2.5%0.8%
1.9% 1.1%1.7%
-5%
0%
5%
10%
15%
1Q10 2Q10 3Q10 4Q10 YTD 10 2011E
AEP Residential Normalized GWh Sales%Change vs. Prior Year
AEP Commercial Normalized GWh Sales%Change vs. Prior Year
AEP Industrial Normalized GWh Sales%Change vs. Prior Year
AEP Total Normalized GWh Sales*%Change vs. Prior Year
*includes firm wholesale load
Note: Chart represents connected load
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-
400
800
1,200
1,600
2,000
2,400
Dec -03 Dec -04 Dec -05 Dec -06 Dec -07 Dec -08 Dec -09 Dec -10
GW h
Pr imary Meta l Manuf ac tur ingChemic a l Manuf ac tu r ingPe troleum and Coa l Produc ts Manuf ac tur ingMining (ex c ept O il & Gas )Paper Manuf ac tur ing
AEP Industrial GWh by Sector
Industrial Sales Volumes
These 5 sectors accounted for 60% of
industrial GWh in 4Q10
Industry
4Q10 Recovery vs 4Q09
YTD Recovery
vs 2009Primary Metals 15.5% 6.5%Chemical Manufacturing 1.9% 4.2%Petroleum and Coal Products 6.9% 2.4%Mining (except Oil & Gas) 4.1% 3.4%Paper Manufacturing 5.0% 6.4%
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2011 Guidance and Business Initiatives
Business Initiatives
Operating Transcos in OH, OK and MI; filings pending in other states
AEP Eastern System Interconnection Agreement
Bonus Depreciation Capital Allocation
2011 Guidance: $3.00 - $3.20 per share
2011 Earnings Drivers
Recovering Economy Rate changes (69% secured) Continued O&M discipline -
$34M decrease net of offsets Customer switching – Ohio 2010 SEET at Columbus
Southern Power Off-system sales
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Questions
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4Q10 Earnings
4th Qtr 4th Qtr 4th Qtr 4th Qtr2009 2010 Change 2009 2010 Change
Utility Operations 206$ 180$ (26)$ 0.44$ 0.38$ (0.06)$
Transmission Operations 1 5 4 0.00 0.01 0.01
Non-Utility Operations 33 29 (4) 0.07 0.06 (0.01)
Parent & Other (2) (35) (33) (0.01) (0.07) (0.06)
AEP On-Going Earnings 238 179 (59) 0.50 0.38 (0.12) Cost Reduction Initiative 0 (3) (3) 0.00 (0.01) (0.01)Special Items Total 0 (3) (3) 0 (0.01) (0.01)
Reported Earnings (GAAP) 238$ 176$ (62)$ 0.50$ 0.37$ (0.13)$
$ millions Earnings Per Share
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Quarterly Performance Comparison
Performance Driver ($ millions) EPS Performance Driver ($ millions) EPS
UTILITY OPERATIONS:Gross Margin:
1 East Regulated Integrated Utilities 16,753 GWh @ 37.9$ /MWhr = 635 17,337 GWh @ 41.7$ /MWhr = 723 2 Ohio Companies 11,699 GWh @ 57.3$ /MWhr = 670 12,732 GWh @ 50.8$ /MWhr = 647 3 West Regulated Integrated Utilities 9,017 GWh @ 28.9$ /MWhr = 261 9,359 GWh @ 29.1$ /MWhr = 273 4 Texas Wires 6,480 GWh @ 21.2$ /MWhr = 137 6,024 GWh @ 23.0$ /MWhr = 139 5 Off-System Sales 4,039 GWh @ 11.2$ /MWhr = 45 3,133 GWh @ 17.7$ /MWhr = 55 6 Transmission Revenue - 3rd Party 85 91 7 Other Operating Revenue 175 108
8 Utility Gross Margin 2,008 2,036
9 Operations & Maintenance (1,006) (960) 10 Depreciation & Amortization (388) (393) 11 Taxes Other than Income Taxes (178) (198) 12 Interest Exp & Preferred Dividend (238) (233) 13 Other Income & Deductions 37 40 14 Income Taxes (29) (112) 15 Utility Operations On-Going Earnings 206 0.44 180 0.38
16 Transmission Operations On-Going Earnings 1 - 5 0.01
NON-UTILITY OPERATIONS:17 AEP River Operations 25 0.05 21 0.04 18 Generation & Marketing 8 0.02 8 0.02
PARENT & OTHER:
19 Parent Company On-Going Earnings (12) (43)
20 Other Investments 10 8
21 Parent & Other On-Going Earnings (2) (0.01) (35) (0.07)
22 ON-GOING EARNINGS 238 0.50 179 0.38
Note: For analysis purposes, certain financial statement amounts have been reclassified for this effect on earnings presentation.
2010 Actual2009 Actual
American Electric PowerFinancial Results for 4th Quarter 2010 Actual vs 4th Quarter 2009 Actual
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December YTD Earnings
Dec YTD Dec YTD Dec YTD Dec YTD2009 2010 Change 2009 2010 Change
Utility Operations 1,317$ 1,419$ 102$ 2.87$ 2.97$ 0.10$
Transmission Operations 4 10 6 0.01 0.02 0.01
Non-Utility Operations 88 65 (23) 0.19 0.13 (0.06)
Parent & Other (47) (43) 4 (0.10) (0.09) 0.01
AEP On-Going Earnings 1,362 1,451 89 2.97 3.03 0.06 SWEPCO SFAS 71 (5) 0 5 (0.01) 0.00 0.01 Medicare D Subsidy 0 (21) (21) 0.00 (0.04) (0.04) Cost Reduction Initiative 0 (185) (185) 0.00 (0.39) (0.39) Carbon Capture -- APCo VA 0 (34) (34) 0.00 (0.07) (0.07)Special Items Total (5) (240) (235) (0.01) (0.50) (0.49)
Reported Earnings (GAAP) 1,357$ 1,211$ (146)$ 2.96$ 2.53$ (0.43)$
$ millions Earnings Per Share
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YTD 2010 Performance Comparison
Performance Driver ($ millions) EPS Performance Driver ($ millions) EPS
UTILITY OPERATIONS:Gross Margin:
1 East Regulated Integrated Utilities 66,976 GWh @ 38.0$ /MWhr = 2,544 68,761 GWh @ 41.9$ /MWhr = 2,882 2 Ohio Companies 47,468 GWh @ 57.6$ /MWhr = 2,733 49,465 GWh @ 56.6$ /MWhr = 2,800 3 West Regulated Integrated Utilities 38,947 GWh @ 30.0$ /MWhr = 1,167 42,131 GWh @ 31.4$ /MWhr = 1,322 4 Texas Wires 27,573 GWh @ 20.7$ /MWhr = 571 27,348 GWh @ 22.3$ /MWhr = 611 5 Off-System Sales 14,786 GWh @ 16.7$ /MWhr = 246 19,172 GWh @ 15.6$ /MWhr = 299 6 Transmission Revenue - 3rd Party 354 369 7 Other Operating Revenue 768 511
8 Utility Gross Margin 8,383 8,794
9 Operations & Maintenance (3,410) (3,427) 10 Depreciation & Amortization (1,561) (1,598) 11 Taxes Other than Income Taxes (751) (801) 12 Interest Exp & Preferred Dividend (919) (945) 13 Other Income & Deductions 128 154 14 Income Taxes (553) (758) 15 Utility Operations On-Going Earnings 1,317 2.87 1,419 2.97
16 Transmission Operations On-Going Earnings 4 0.01 10 0.02
NON-UTILITY OPERATIONS:17 AEP River Operations 47 0.10 40 0.08 18 Generation & Marketing 41 0.09 25 0.05
PARENT & OTHER:
19 Parent Company On-Going Earnings (58) (83)
20 Other Investments 11 40
21 Parent & Other On-Going Earnings (47) (0.10) (43) (0.09)
22 ON-GOING EARNINGS 1,362 2.97 1,451 3.03
Note: For analysis purposes, certain financial statement amounts have been reclassified for this effect on earnings presentation.
2010 Actual2009 Actual
American Electric PowerFinancial Results for YTD December 2010 Actual vs YTD December 2009 Actual
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December YTD 2010 Cash Flow
YTD 2010 Cash Flow Drivers:
Operating Activities Changes in working capital largely driven
by coal inventory and accrued taxes.
Investing Activities
Cash outlay for 2010 YTD capital investment.
2010 asset sale proceeds primarily relate to the transfer of assets to ETT.
Financing Activities Changes in long-term debt driven by
reduced capital funding requirements. Changes in short term debt relate to funding
of severance activity and voluntary pension funding.
($ millions) 2009 2010Operating A ctivit ies
N et Inco me -- R epo rted 1,365$ 1,218$
Depreciation, Amortization & Deferred Taxes 2,868 2,556
Pension Contributions - (500) Application of New Accounting Guidance: Securitized Debt for Receivables - (656) Changes in Components of Working Capital (1,212) 279
Over/(Under) Fuel Recovery, Net (474) (253)
Extraordinary Loss 5 -
Other Assets & Liabilities (77) (3)
C ash F lo ws F ro m Operating A ctivit ies 2,475 2,641
Investing A ctivit ies
Capital Expenditures (2,792) (2,318)
Proceeds on Sale of Assets 278 187
Change in Other Temporary Cash Investments, net (89) (103)
Acquisition of Assets (104) (144)
Other Investing, net (209) (124)
C ash F lo ws Used fo r Investing A ctivit ies (2,916) (2,502)
F inancing A ctivit ies
Common Shares Issued, net 1,728 93
Long-term Debt Issuances, net 1,490 (723)
Short-term Debt Increase/(Decrease), net (1,850) 564
Application of New Accounting Guidance: Securitized Debt for Receivables - 656
Other Financing (90) (101)
Dividends Paid (758) (824)
C ash F lo ws F ro m (Used fo r) F inancing A ctivit ies 520 (335)
C ash F ro m C o ntinuing Operat io ns 79$ (196)$
Beginning Cash & Cash Equivalent Balances 411 490
Ending Cash & Cash Equivalent Balances 490$ 294$
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Capitalization & Liquidity
57.2%
59.1%60.7%
62.5%
57.2%58.1% 57.7%57.0%
59.1% 58.5%
40%
45%
50%
55%
60%
65%
70%
2004
A20
05A
2006
A20
07A
2008
A20
09A
1Q201
02Q
2010
3Q201
04Q
2010
Total Debt/Capitalization
Note: Total Debt is calculated according to GAAP and includes securitized debt
1: Effective January 1, 2010 in accordance with Transfers and Servicing accounting guidance (formerly SFAS 166), factored receivables of AEP Credit of $750 million are classified as short-term debt; The 4Q2010 debt/capitalization ratio would be 56.1%, excluding AEP Credit.
Current Liquidity Summary
1
Liquidity Summary Actual(unadited) 12/31/10($ in millions) Amount Maturity
Revolving Credit Facility $1,500 Jun-13Revolving Credit Facility 1,454 Apr-12Revolving Credit Facility 478 Apr-11
Total Credit Facilities 3,432
PlusCash & Cash Equivalents 294
LessCommercial Paper Outstanding (650) Letters of Credit Issued (124) Letters of Credit Issued for VRDNs (477)
Net Available Liquidity $2,475
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Detailed Ongoing Earnings Guidance
2010A: $3.03 2011E: $3.00 - $3.20
2011 Guidance
Performance Driver ($ millions) Performance Driver ($ millions)UTILITY OPERATIONS:
Gross Margin:1 East Regulated Integrated Utilities 68,761 GWh @ 41.9$ /MWhr = 2,882 67,739 GWh @ 43.4$ /MWhr = 2,940 2 Ohio Companies 49,465 GWh @ 56.6$ /MWhr = 2,800 49,747 GWh @ 56.1$ /MWhr = 2,793 3 West Regulated Integrated Utilities 42,131 GWh @ 31.4$ /MWhr = 1,322 41,536 GWh @ 32.8$ /MWhr = 1,361 4 Texas Wires 27,348 GWh @ 22.3$ /MWhr = 611 27,870 GWh @ 22.0$ /MWhr = 614 5 Off-System Sales 19,172 GWh @ 15.6$ /MWhr = 299 21,786 GWh @ 12.0$ /MWhr = 262 6 Transmission Revenue - 3rd Party 369 429 7 Other Operating Revenue 511 481
8 Utility Gross Margin 8,794 8,880
9 Operations & Maintenance (3,427) (3,529) 10 Depreciation & Amortization (1,598) (1,553) 11 Taxes Other than Income Taxes (801) (818) 12 Interest Exp & Preferred Dividend (945) (921) 13 Other Income & Deductions 154 211 14 Income Taxes (758) (787) 15 Utility Operations On-Going Earnings 1,419 1,483
16 Transmission Operations On-Going Earnings 10 17
NON-UTILITY OPERATIONS:17 AEP River Operations 40 51 18 Generation & Marketing 25 6
19 Parent & Other On-Going Earnings (43) (61)
20 ON-GOING EARNINGS 1,451 1,496
2010 Actual
American Electric PowerFinancial Results for 2011 Guidance vs 2010 Actual
19
Cash Flow Guidance
2010A 2011ECash From Operations Income from Continuing Operations 1,218$ 1,499$ Depreciation & Amortization 1,641 1,611 Pension Funding (500) (150) Other Cash Flow Items 659 834 Ligigation Resolution 1 - (449)
Working Capital 2 279 7 Cash From Operations 3,297$ 3,352$
Investing Activities Construction Expenditures (2,318) (2,644) Other Investing Activity (184) (205) Total Investing Activities (2,502)$ (2,849)$
Financing Activities Dividends (824) (892)
Net Debt Issued/(Retired)1 (160) 234 Common Equity 93 150 Other Financing Activities (100) (72) Total from Financing Activities (991)$ (580)$
Beginning Cash Balance 490$ 294$ Ending Cash Balance 294$ 217$
1 Refer to September 30, 2010 10Q Enron Bankruptcy pages 56-57 for futher discussion2 Pro forma to exclude effects of consolidation of AEP Credit ($656M) in 2010
$ in millions
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Capital Expenditures
$377$266 $361
$331
$272
$434
$729
$808
$776
$130$108
$133
$93
$62$256
$319
$457
$303
$223
$2,270
$47$113 $280
$50
$160
$350
$82$263
$77$34
$24 $56
$1
$0
$500
$1,000
$1,500
$2,000
$2,500
$3,000
2009A 2010A 2011E 2012E
$ in
mill
ions
AEP Transco
JV EquityContributions, net
AEP River Ops &Other Non-Utility
Environmental
New Generation
Corporate/Other
NuclearGeneration
Distribution
Transmission
Fossil & HydroGeneration
$2,487
$2,243
$2,615$2,900
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Retail Rate Performance
$0Texas Wires$0Texas Wires
Rate Changes, net of trackers (in millions)
Rate Changes, net of trackers (in millions)
4Q10 vs. 4Q09 YTD10 vs. YTD09
East Regulated Integrated Utilities $46
East Regulated Integrated Utilities
$141
Ohio Companies -$7 Ohio Companies $20
West Regulated Integrated Utilities $12
West Regulated Integrated Utilities
$61
AEP System Total $51 AEP System Total $222
Impact on EPS Impact on EPS $0.32$0.07
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4Q10 Retail Performance
Retail Load*(weather normalized)
Weather Impact(in millions)
4Q10 vs. 4Q09 4Q10 vs. 4Q09
East Regulated Integrated Utilities 1.8%
East Regulated Integrated Utilities
$21
Ohio Companies 4.2% Ohio Companies $8
West Regulated Integrated Utilities 4.2%
West Regulated Integrated Utilities
$1
Texas Wires -4.8% Texas Wires ($3)
Impact on EPS Impact on EPS$0.02
*Excludes Firm Wholesale Load
$0.04
May not foot due to rounding
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YTD 2010 Retail Performance
Retail Load*(weather normalized)
Weather Impact(in millions)
YTD10 vs. YTD09 YTD10 vs. YTD09
East Regulated Integrated Utilities 2.1%
East Regulated Integrated Utilities
$96
Ohio Companies 1.2% Ohio Companies $77
West Regulated Integrated Utilities 3.0%
West Regulated Integrated Utilities
$61
Texas Wires 1.0% Texas Wires ($5)
Impact on EPS Impact on EPS $0.32
*Excludes Firm Wholesale Load
$0.07
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Off System Sales Gross Margin Detail
Physical off-system sales margins exceeded last year by $18M
Volumes down 22% versus last year
Improved AEP/Dayton Hub pricing: 9% increase in liquidation prices
Lower Trading & Marketing results by $14M
Physical off-system sales margins exceeded last year by $129M
Volumes up 30% versus last year
Improved AEP/Dayton Hub pricing: 14% increase in liquidation prices
Lower Trading & Marketing results by $50M
4Q10
YTD10
4Q09 4Q10GWh Realization ($millions) GWh Realization ($millions)
OSS Physical Sales 4,039 8.12$ 33$ 3,133 16.34$ 51$ Marketing/Trading - 35$ - 21$ Pre-Sharing Gross Margin 4,039 68$ 3,133 73$ Margin Shared (23)$ (17)$ Net OSS 45$ 56$
YTD09 YTD10GWh Realization ($millions) GWh Realization ($millions)
OSS Physical Sales 14,786 10.87$ 161$ 19,172 15.12$ 290$ Marketing/Trading - 176$ - 126$ Pre-Sharing Gross Margin 14,786 337$ 19,172 416$ Margin Shared (90)$ (117)$ Net OSS 246$ 299$
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Off-System Sales
4Q10 vs. 4Q09
$/M
Wh
YTD10 vs. YTD09
Hub 2009 2010 $ Change % ChangeAEP Dayton 32.26 35.29 3.03 9%PJM West 37.65 43.56 5.91 16%NiHub 29.1 27.41 -1.69 -6%CinHub 29.67 32.04 2.37 8%SPP 35.38 28.21 -7.17 -20%Natural Gas ($/mmBtu) 4.26 3.78 -0.48 -11%
Q4 2010 Liquidations vs. Q4 2009 Liquidations ($/MWh)
Hub 2009 2010 $ Change % ChangeAEP Dayton 32.98 37.59 4.61 14%PJM West 38.75 46.59 7.84 20%NiHub 28.69 33.13 4.44 15%CinHub 29.46 34.81 5.35 18%SPP 29.11 32.45 3.34 11%Natural Gas ($/mmBtu) 3.92 4.37 0.45 11%
YTD 2010 Liquidations vs. YTD 2009 Liquidations ($/MWh)
Power forwards and NG futures as of January 18, 2011
Hub 2010 2011 $ Change % ChangeAEP Dayton 37.59 37.07 (0.52) -1%PJM West 46.59 45.4 (1.19) -3%NiHub 33.13 30.95 (2.18) -7%CinHub 34.81 32.96 (1.85) -5%SPP 32.45 30.64 (1.81) -6%Natural Gas ($/mmBtu) 4.37 4.63 0.26 6%
2011 Forwards vs. Full Year 2010 Liquidations ($/MWh)
AEP Dayton 7X24 Day Ahead Prices 2010 Liquidations and 2011 Forward
$20.00
$30.00
$40.00
$50.00
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
2010 2011