1

4Q10 Earnings Release Presentation

January 28, 2011

2

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

cezebula@aep.com

Bette Jo RozsaManaging DirectorInvestor Relations

614-716-2840bjrozsa@aep.com

Julie SherwoodDirector

Investor Relations614-716-2663

jasherwood@aep.com

Sara MaciochAnalyst

Investor Relations614-716-2835

semacioch@aep.com

3

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

4

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

5

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

7

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

8

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

9

-

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%

10

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

11

Questions

12

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

13

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

14

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

15

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

16

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$

17

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

18

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

20

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

21

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

22

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

23

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

24

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$

25

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