FERC Form

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

NOTES TO FINANCIAL STATEMENTS

Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement.
Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock.
For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Cormmission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof.
Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts.
Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein.
For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred.
Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.

INDEX OF NOTES TO FINANCIAL STATEMENTS

Glossary of Terms for Notes

1.Organization and Summary of Significant Accounting Policies

2.New Accounting Standards

3.Rate Matters

4.Effects of Regulation

5.Commitments, Guarantees and Contingencies

6.Benefit Plans

7.Business Segments

8.Derivatives and Hedging

9.Fair Value Measurements

10.Income Taxes

11.Leases

12.Financing Activities

13.Related Party Transactions

14.Property, Plant and Equipment

15.Revenue from Contracts with Customers

16.FERC Order NO. 784-A

GLOSSARY OF TERMS FOR NOTES

When the following terms and abbreviations appear in the text of this report, they have the meanings indicated below.


Term						Meaning

AEP						American Electric Power Company, Inc., an investor-owned electric public utility holding company which includes American Electric Power Company, Inc. (Parent) and majority-owned subsidiaries and affiliates.
AEP Credit						AEP Credit, Inc., a subsidiary of AEP which securitizes accounts receivable and accrued utility revenues for affiliated electric utility companies.
AEP East Companies						APCo, I&M, KGPCo, KPCo, OPCo and WPCo.
AEP Energy						AEP Energy, Inc., a wholly-owned retail electric supplier for customers in Ohio, Illinois and other deregulated electricity markets throughout the United States.
AEP System						American Electric Power System, an electric system, owned and operated by AEP subsidiaries.
AEPEP						AEP Energy Partners, Inc., a subsidiary of AEP dedicated to wholesale marketing and trading, hedging activities, asset management and commercial and industrial sales in deregulated markets.
AEPSC						American Electric Power Service Corporation, an AEP service subsidiary providing management and professional services to AEP and its subsidiaries.
AEPTCo						AEP Transmission Company, LLC, a wholly-owned subsidiary of AEP Transmission Holdco, is an intermediate holding company that owns the State Transcos.
AFUDC						Allowance for Equity Funds Used During Construction.
AOCI						Accumulated Other Comprehensive Income.
APCo						Appalachian Power Company, an AEP electric utility subsidiary.
ARAM						Average Rate Assumption Method, an IRS approved method used to calculate the reversal of Excess ADIT for rate-making purposes.
ARO						Asset Retirement Obligations.
COVID-19						Coronavirus 2019, a highly infectious respiratory disease. In March 2020, the World Health Organization declared COVID-19 a worldwide pandemic.
CWIP						Construction Work in Progress.
DIR						Distribution Investment Rider.
EIS						Energy Insurance Services, Inc., a nonaffiliated captive insurance company.
Energy Supply						AEP Energy Supply LLC, a nonregulated holding company for AEP’s competitive generation, wholesale and retail businesses, and a wholly-owned subsidiary of AEP.
ESP						Electric Security Plans, a PUCO requirement for electric utilities to adjust their rates by filing with the PUCO.
Excess ADIT						Excess accumulated deferred income taxes.
FAC						Fuel Adjustment Clause.
FASB						Financial Accounting Standards Board.
Federal EPA						United States Environmental Protection Agency.
FERC						Federal Energy Regulatory Commission.
GAAP						Accounting Principles Generally Accepted in the United States of America.
I&M						Indiana Michigan Power Company, an AEP electric utility subsidiary.


IRA						On August 16, 2022 President Biden signed into law legislation commonly referred to as the “Inflation Reduction Act” (IRA).
IRS						Internal Revenue Service.
ITC						Investment Tax Credit.
KPCo						Kentucky Power Company, an AEP electric utility subsidiary.
MTM						Mark-to-Market.
MWh						Megawatt-hour.
NOL						Net operating losses.
OATT						Open Access Transmission Tariff.
OHTCo						AEP Ohio Transmission Company, Inc., a wholly-owned AEPTCo transmission subsidiary.
OPCo						Ohio Power Company, an AEP electric utility subsidiary.
OPEB						Other Postretirement Benefits.
OTC						Over-the-counter.
OVEC						Ohio Valley Electric Corporation, which is 43.47% owned by AEP.
Parent						American Electric Power Company, Inc., the equity owner of AEP subsidiaries within the AEP consolidation.
PJM						Pennsylvania – New Jersey – Maryland regional transmission organization.
PSO						Public Service Company of Oklahoma, an AEP electric utility subsidiary.
PTC						Production Tax Credit.
PUCO						Public Utilities Commission of Ohio.
Risk Management Contracts						Trading and non-trading derivatives, including those derivatives designated as cash flow and fair value hedges.
RTO						Regional Transmission Organization, responsible for moving electricity over large interstate areas.
SEC						U.S. Securities and Exchange Commission.
Sempra Renewables LLC						Sempra Renewables LLC, acquired in April 2019 (subsequently renamed as AEP Wind Holdings LLC), consists of 724 MWs of wind generation and battery assets in the United States.
SIA						System Integration Agreement, effective June 15, 2000, as amended, provides contractual basis for coordinated planning, operation and maintenance of the power supply sources of the combined AEP.
SSO						Standard service offer.
TA						Transmission Agreement, effective November 2010, among APCo, I&M, KGPCo, KPCo, OPCo and WPCo with AEPSC as agent.
Tax Reform						On December 22, 2017, President Trump signed into law legislation referred to as the “Tax Cuts and Jobs Act” (the TCJA). The TCJA includes significant changes to the Internal Revenue Code of 1986, including a reduction in the corporate federal income tax rate from 35% to 21% effective January 1, 2018.
Utility Money Pool						Centralized funding mechanism AEP uses to meet the short-term cash requirements of certain utility subsidiaries.
Virginia SCC						Virginia State Corporation Commission.
WPCo						Wheeling Power Company, an AEP electric utility subsidiary.

1. ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

ORGANIZATION

As a public utility, OPCo is engaged in the transmission and distribution of electric power to approximately 1,521,000 retail customers in Ohio. OPCo purchases energy and capacity at auction to serve generation service customers who have not switched to a competitive generation supplier. As of December 31, 2022, OPCo had 1,713 employees. Among the principal industries served by OPCo are primary metals, petroleum and coal products manufacturing, plastics and rubber products, chemical manufacturing, pipeline transportation and data centers. OPCo is a member of PJM.

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Rates and Service Regulation

OPCo’s rates are regulated by the FERC and the PUCO. The FERC also regulates OPCo’s affiliated transactions, including AEPSC intercompany service billings which are generally at cost, under the 2005 Public Utility Holding Company Act and the Federal Power Act. The FERC also has jurisdiction over certain issuances and acquisitions of securities of the public utility subsidiaries, the acquisition or sale of certain utility assets and mergers with another electric utility or holding company. The state regulatory commissions also regulate certain intercompany transactions under various orders and affiliate statutes. Both the FERC and state regulatory commissions are permitted to review and audit the relevant books and records of companies within a public utility holding company system.

The FERC regulates wholesale power markets and wholesale power transactions. OPCo’s wholesale power transactions are generally market-based. Wholesale power transactions are cost-based regulated when a cost-based contract is negotiated and filed with the FERC or the FERC determines that OPCo has “market power” in the region where the transaction occurs.

The PUCO regulates all of the retail distribution operations and rates of OPCo’s on a cost basis. For generation in Ohio, customers who have not switched to a CRES provider for generation pay market-based auction rates. In addition, all OPCo distribution customers continue to pay for certain legacy deferred generation-related costs through PUCO approved riders.

The FERC also regulates OPCo’s wholesale transmission operations and rates. Retail transmission rates are based upon the FERC OATT rate when retail rates are unbundled in connection with restructuring. Retail transmission rates are based on formula rates included in the PJM OATT that are cost-based and are unbundled in Ohio for OPCo.

In addition, the FERC regulates the SIA, Operating Agreement and TA all of which allocate shared system costs and revenues among the utility subsidiaries that are parties to each agreement. See Note 14 - Related Party Transactions for additional information.

Basis of Accounting

OPCo’s accounting is subject to the requirements of the PUCO and the FERC. The financial statements have been prepared in accordance with the Uniform System of Accounts prescribed by the FERC. The principal differences from GAAP include:


·			Accounting for subsidiaries on an equity basis.
·			The requirement to report deferred tax assets and liabilities separately rather than as a single amount.
·			The classification of accrued taxes as a single amount rather than as assets and liabilities.
·			The exclusion of current maturities of long-term debt from current liabilities.
·			The classification of accrued non-ARO asset removal costs as accumulated depreciation rather than regulatory liabilities.
·			The classification of finance lease payments as operating activities instead of financing activities.
·			The classification of gains/losses from disposition of allowances as utility operating expenses rather than as operating revenues.
·			The classification of an accrued provision for potential refund as other noncurrent liability rather than a current liability.
·			The classification of regulatory assets and liabilities related to the accounting guidance for “Accounting for Income Taxes” as separate assets and liabilities rather than as a single amount.
·			The presentation of finance leased assets and their associated accumulated amortization as a single amount instead of as separate amounts.
·			The classification of factored accounts receivable expense as a nonoperating expense instead of as an operating expense.
·			The classification of certain nonoperating revenues as miscellaneous nonoperating income instead of as operating revenue.
·			The classification of certain nonoperating expenses as miscellaneous nonoperating expense instead of as operating expense.
·			The separate classification of income tax expense for operating and nonoperating activities instead of as a single income tax expense.
·			The classification of unamortized loss on reacquired debt in deferred debits rather than in regulatory assets.
·			The classification of accumulated deferred investment tax credits in deferred credits rather than in regulatory liabilities and deferred investment tax credits.
·			The classification of certain other assets and liabilities as current instead of noncurrent.
·			The classification of certain other assets and liabilities as noncurrent instead of current.
·			The classification of debt issuance costs as noncurrent assets instead of noncurrent liabilities.
·			The classification of certain wind contractual purchases as purchased power rather than operating revenues.
·			The classification of rents receivable as rents receivable instead of customer accounts receivable.
·			The classification of Non-Service Cost Components of Net Periodic Benefit Cost as Operating Expense instead of Other Income (Expense).
·			The classification of operating lease assets as Utility Plant rather than as a noncurrent asset.
·			The classification of operating lease assets as Other Property and Investments rather than as noncurrent assets.
·			The presentation of obligations under finance and operating leases as a single amount in Obligations Under Capital Leases rather than as separate items.
·			The classification of certain expenses in operating income rather than operating expenses.
·			The classification of interest on regulated finance leases as operating expense instead of other income (expense).
·			The classification of cloud computing implementation costs as Utility Plant rather than as a noncurrent asset.

Accounting for the Effects of Cost-Based Regulation

OPCo’s financial statements reflect the actions of regulators that result in the recognition of certain revenues and expenses in different time periods than enterprises that are not rate-regulated. In accordance with accounting

guidance for “Regulated Operations,” regulatory assets (deferred expenses) and regulatory liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of regulation in the same accounting period by matching expenses with their recovery through regulated revenues and by matching income with its passage to customers in cost-based regulated rates.

Use of Estimates

The preparation of these financial statements requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. These estimates include, but are not limited to, inventory valuation, allowance for doubtful accounts, long-lived asset impairment, unbilled electricity revenue, valuation of long-term energy contracts, the effects of regulation, long-lived asset recovery, storm costs, the effects of contingencies and certain assumptions made in accounting for pension and postretirement benefits. The estimates and assumptions used are based upon management’s evaluation of the relevant facts and circumstances as of the date of the financial statements. Actual results could ultimately differ from those estimates.

Cash and Cash Equivalents

Cash and Cash Equivalents include Cash, Working Fund and Temporary Cash Investments on the balance sheets with original maturities of three months or less.

Supplementary Information


		2022			2021
For the Years Ended December 31,		(in millions)
Cash was Paid (Received) for:
	Interest (Net of Capitalized Amounts)	$	113.1		$	119.5
	Income Taxes (Net of Refunds)			(19.7)			(7.9)
Noncash Acquisitions Under Finance Leases				3.0			2.5
As of December 31,
Construction Expenditures Included in Current and Accrued Liabilities				109.7			97.1

AEP System Tax Allocation

OPCo joins in the filing of a consolidated federal income tax return. Historically, the allocation of the AEP System’s current consolidated federal income tax to the AEP System companies allocated the benefit of current tax loss of the parent company (Parent Company Loss Benefit) to OPCo through a reduction of current tax expense. In the first quarter of 2022, OPCo changed accounting for the Parent Company Loss Benefit from a reduction of current tax expense to an allocation through equity. The impact of this change was immaterial to OPCo’s financial statements. The consolidated NOL of the AEP System is allocated to each company in the consolidated group with taxable loss. With the exception of the allocation of the consolidated AEP System NOL, the loss of the Parent and tax credits, the method of allocation reflects a separate return result for each company in the consolidated group.

Special Deposits

Special Deposits include funds held by trustees primarily for margin deposits for risk management activities.

Inventory

Materials and supplies inventories are carried at average cost.

Accounts Receivable

Customer accounts receivable primarily include receivables from wholesale and retail energy customers, receivables from energy contract counterparties related to risk management activities and customer receivables primarily related to other revenue-generating activities.

Revenue is recognized over time as the performance obligations of delivering energy to customers are satisfied. To the extent that deliveries have occurred but a bill has not been issued, OPCo accrues and recognizes, as Accrued Utility Revenues on the balance sheets, an estimate of the revenues for energy delivered since the last billing.

AEP Credit factors accounts receivable on a daily basis, excluding receivables from risk management activities, through purchase agreements with OPCo. AEP Credit has a receivables securitization agreement with bank conduits. Under the securitization agreement, AEP Credit receives financing from bank conduits for the interest in the billed and unbilled receivables they acquire from affiliated utility subsidiaries. See “Securitized Accounts Receivable – AEP Credit” section of Note 13 for additional information.

Allowance for Uncollectible Accounts

Generally, AEP Credit records bad debt expense based upon a 12-month rolling average of bad debt write-offs in proportion to gross accounts receivable purchased from OPCo. The assessment is performed by OPCo which inherently contemplates any differences in geographical risk characteristics for the allowance. For customer accounts receivables relating to risk management activities, accounts receivables are reviewed for bad debt reserves at a specific counterparty level basis. For miscellaneous accounts receivable, bad debt expense is recorded based upon a 12-month rolling average of bad debt write-offs in proportion to gross accounts receivable, unless specifically identified. In addition to these processes, management contemplates available current information, as well as any reasonable and supportable forecast information, to determine if allowances for uncollectible accounts should be further adjusted in accordance with the accounting guidance for “Credit Losses.” Management’s assessments contemplate expected losses over the life of the accounts receivable.

Concentrations of Credit Risk and Significant Customers

OPCo does not have any significant customers that comprise 10% or more of its operating revenues.

OPCo monitors credit levels and the financial condition of its customers on a continuous basis to minimize credit risk. The PUCO allows recovery in rates for a reasonable level of bad debt costs. Management believes adequate provisions for credit loss have been made in the accompanying financial statements.

Renewable Energy Credits

OPCo records renewable energy credits (RECs) at cost. OPCo follows the inventory model for these RECs. RECs expected to be consumed within one year are reported in Materials and Supplies on the balance sheets. RECs with expected consumption beyond one year are included in Deferred Charges and Other Noncurrent Assets on the balance sheets. The purchases and sales of RECs are reported in the Operating Activities section of the statements of cash flows. RECs that are consumed to meet Ohio’s state renewable portfolio standards are recorded in Operation Expenses at an average cost on the statements of income. The net margin on sales of RECs affects the determination of deferred fuel and REC costs and the amortization of regulatory assets.

Property, Plant and Equipment

Electric utility property, plant and equipment for rate-regulated operations are stated at original cost. Additions, major replacements and betterments are added to the plant accounts. Under the group composite method of depreciation, continuous interim routine replacements of items such as boiler tubes, pumps, motors, etc. result in original cost retirements, less salvage, being charged to accumulated depreciation. The group composite method of depreciation assumes that on average, asset components are retired at the end of their useful lives and thus there is no gain or loss. The equipment in each primary electric plant account is identified as a separate group. The depreciation rates that are established take into account the past history of interim capital replacements and the amount of removal cost incurred and salvage received. These rates and the related lives are subject to periodic review. Removal costs accrued are charged to accumulated depreciation. The costs of labor, materials and overhead incurred to operate and maintain plant and equipment are included in operating expenses.

Long-lived assets are required to be tested for impairment when it is determined that the carrying value of the assets may no longer be recoverable or when the assets meet the held-for-sale criteria under the accounting guidance for “Impairment or Disposal of Long-Lived Assets.” When it becomes probable that an asset in-service or an asset under construction will be abandoned and regulatory cost recovery has been disallowed or is not probable, the cost of that asset shall be written down to its then current estimated fair value, with the change charged to expense, and the asset is removed from plant-in-service or CWIP. The fair value of an asset is the amount at which that asset could be bought or sold in a current transaction between willing parties, as opposed to a forced or liquidation sale. Quoted market prices in active markets are the best evidence of fair value and are used as the basis for the measurement, if available. In the absence of quoted prices for identical or similar assets in active markets, fair value is estimated using various internal and external valuation methods including cash flow analysis and appraisals.

Allowance for Funds Used During Construction

AFUDC represents the estimated cost of borrowed and equity funds used to finance construction projects that is capitalized and recovered through depreciation over the service life of regulated electric utility plant.

Asset Retirement Obligations

OPCo records ARO in accordance with the accounting guidance for “Asset Retirement and Environmental Obligations” for legal obligations for asbestos removal and for the retirement of certain ash disposal facilities, wind farms, solar farms and certain coal-mining facilities. AROs are computed as the present value of the estimated costs associated with the future retirement of an asset and are recorded in the period in which the liability is incurred. Estimates of the timing and amounts of future cash outlays are based on projections of when and how the assets will be decommissioned, inflation, and discount rate, which may change significantly over time. The estimated costs are capitalized as part of the related long-lived asset and depreciated over the asset's useful life. OPCo has identified, but not recognized, ARO liabilities related to electric transmission and distribution assets as a result of certain easements on property on which assets are owned. Generally, such easements are perpetual and require only the retirement and removal of assets upon the cessation of the property’s use. The retirement obligation is not estimable for such easements since OPCo plans to use their facilities indefinitely. The retirement obligation would only be recognized if and when OPCo abandons or ceases the use of specific easements, which is not expected.

Valuation of Nonderivative Financial Instruments

The book values of Cash, Special Deposits, Working Fund, Notes Receivable from Associated Companies, Notes Payable to Associated Companies, accounts receivable and accounts payable approximate fair value because of the short-term maturity of these instruments.

Fair Value Measurements of Assets and Liabilities

The accounting guidance for “Fair Value Measurements and Disclosures” establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2. When quoted market prices are not available, pricing may be completed using comparable securities, dealer values, operating data and general market conditions to determine fair value. Valuation models utilize various inputs such as commodity, interest rate and, to a lesser degree, volatility and credit that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, market corroborated inputs (i.e. inputs derived principally from, or correlated to, observable market data) and other observable inputs for the asset or liability.

For commercial activities, exchange-traded derivatives, namely futures contracts, are generally fair valued based on unadjusted quoted prices in active markets and are classified as Level 1. Level 2 inputs primarily consist of OTC broker quotes in moderately active or less active markets, as well as exchange-traded derivatives where there is insufficient market liquidity to warrant inclusion in Level 1. Management verifies price curves using these broker quotes and classifies these fair values within Level 2 when substantially all of the fair value can be corroborated. Management typically obtains multiple broker quotes, which are nonbinding in nature but are based on recent trades in the marketplace. When multiple broker quotes are obtained, the quoted bid and ask prices are averaged. In certain circumstances, a broker quote may be discarded if it is a clear outlier. Management uses a historical correlation analysis between the broker quoted location and the illiquid locations. If the points are highly correlated, these locations are included within Level 2 as well. Certain OTC and bilaterally executed derivative instruments are executed in less active markets with a lower availability of pricing information. Illiquid transactions, complex structured transactions, FTRs and counterparty credit risk may require nonmarket-based inputs. Some of these inputs may be internally developed or extrapolated and utilized to estimate fair value. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized as Level 3. The main driver of contracts being classified as Level 3 is the inability to substantiate

energy price curves in the market. A portion of the Level 3 instruments have been economically hedged which limits potential earnings volatility.

AEP utilizes its trustee’s external pricing service to estimate the fair value of the underlying investments held in the benefit plan trusts. AEP’s investment managers review and validate the prices utilized by the trustee to determine fair value. AEP’s management performs its own valuation testing to verify the fair values of the securities. AEP receives audit reports of the trustee’s operating controls and valuation processes.

Assets in the benefits trusts are classified using the following methods. Equities are classified as Level 1 holdings if they are actively traded on exchanges. Items classified as Level 1 are investments in money market funds, fixed income and equity mutual funds and equity securities. They are valued based on observable inputs, primarily unadjusted quoted prices in active markets for identical assets. Items classified as Level 2 are primarily investments in individual fixed income securities. Fixed income securities generally do not trade on exchanges and do not have an official closing price but their valuation inputs are based on observable market data. Pricing vendors calculate bond valuations using financial models and matrices. The models use observable inputs including yields on benchmark securities, quotes by securities brokers, rating agency actions, discounts or premiums on securities compared to par prices, changes in yields for U.S. Treasury securities, corporate actions by bond issuers, prepayment schedules and histories, economic events and, for certain securities, adjustments to yields to reflect changes in the rate of inflation. Other securities with model-derived valuation inputs that are observable are also classified as Level 2 investments. Investments with unobservable valuation inputs are classified as Level 3 investments. Investments classified as Other are valued using Net Asset Value as a practical expedient. Items classified as Other are primarily cash equivalent funds, common collective trusts, commingled funds, structured products, private equity, real estate, infrastructure and alternative credit investments. These investments do not have a readily determinable fair value or they contain redemption restrictions which may include the right to suspend redemptions under certain circumstances. Redemption restrictions may also prevent certain investments from being redeemed at the reporting date for the underlying value.

Deferred Fuel Costs

The cost of fuel and related emission allowances and emission control chemicals/consumables is charged to Operation Expenses when the fuel is burned or the allowance or consumable is utilized. Fuel cost over-recoveries (the excess of fuel-related revenues over applicable fuel costs incurred) are generally deferred as regulatory liabilities and under-recoveries (the excess of applicable fuel costs incurred over fuel-related revenues) are generally deferred as regulatory assets. These deferrals are incorporated into the development of future fuel rates billed to or refunded to customers. The amount of an over-recovery or under-recovery can also be affected by actions of the PUCO. On a routine basis, the PUCO reviews and/or audits OPCo’s fuel procurement policies and practices, the fuel cost calculations and FAC deferrals. FAC deferrals are adjusted when costs are no longer probable of recovery or when refunds of fuel reserves are probable. OPCo shares the majority of its Off-system Sales margins to customers either through an active FAC or other rate mechanisms. Where the FAC or Off-system Sales sharing mechanism is capped, frozen or non-existent, changes in fuel costs or sharing of off-system sales impact earnings.

Revenue Recognition

Regulatory Accounting

OPCo’s financial statements reflect the actions of regulators that can result in the recognition of revenues and expenses in different time periods than enterprises that are not rate-regulated. Regulatory assets (deferred expenses or alternative revenues recognized in accordance with the guidance for “Regulated Operations”) and regulatory liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of

regulation in the same accounting period by matching expenses with their recovery through regulated revenues and by matching revenue with its passage to customers in cost-based regulated rates.

When regulatory assets are probable of recovery through regulated rates, assets are recorded on the balance sheets. Regulatory assets are reviewed for probability of recovery at each balance sheet date or whenever new events occur. Examples of new events include the issuance of a regulatory commission order or passage of new legislation. If it is determined that recovery of a regulatory asset is no longer probable, the regulatory asset is derecognized as a charge against income.

Retail and Wholesale Supply and Delivery of Electricity

OPCo recognizes revenues from customers for retail and wholesale electricity sales and electricity transmission and distribution delivery services. OPCo recognizes such revenues on the statements of income as the performance obligations of delivering energy to customers are satisfied. Recognized revenues include both billed and unbilled amounts.

Wholesale transmission revenue is based on FERC-approved formula rate filings made for each calendar year using estimated costs. Revenues initially recognized per the annual rate filing are compared to actual costs, resulting in the subsequent recognition of an over or under-recovered amount, with interest, that is refunded or recovered, respectively, in a future year’s rates. These annual true-ups meet the definition of alternative revenues in accordance with the accounting guidance for “Regulated Operations”. An estimated annual true-up is recorded by OPCo in the fourth quarter of each calendar year and a final annual true-up is recognized by OPCo in the second quarter of each calendar year following the filing of annual FERC reports. Any portion of the true-ups applicable to an affiliated company is recorded as Accounts Receivable from Associated Companies or Accounts Payable to Associated Companies on the balance sheets. Any portion of the true-ups applicable to third-parties is recorded as regulatory assets or regulatory liabilities on the balance sheets. See Note 16 - Revenue from Contracts with Customers for additional information.

Gross versus Net Presentation of Certain Electricity Supply and Delivery Activities

OPCo purchases power from PJM to supply power to customers. Generally, these power sales and purchases are reported on a net basis as revenues on the statements of income. However, purchases of power in excess of sales to PJM, on an hourly net basis, used to serve retail load are recorded gross as Operation Expenses on the statements of income.

Physical energy purchases arising from non-derivative contracts are accounted for on a gross basis in Operation Expenses on the statements of income. Energy purchases arising from non-trading derivative contracts are recorded based on the transaction’s facts and circumstances. Purchases under non-trading derivatives used to serve accrual based obligations are recorded in Operation Expenses on the statements of income. All other non-trading derivative purchases are recorded net in revenues.

In general, OPCo records expenses when purchased electricity is received and when expenses are incurred. OPCo, defers unrealized MTM amounts as regulatory assets (for losses) and regulatory liabilities (for gains).

Energy Marketing and Risk Management Activities

OPCo engages in power, capacity and, to a lesser extent, heating oil, gasoline and other commodity risk management activities focused on markets where the AEP System owns assets and on adjacent markets. These activities include the purchase-and-sale of energy under forward contracts at fixed and variable prices. These

contracts include physical transactions, exchange-traded futures, and to a lesser extent, OTC swaps and options. Certain energy marketing and risk management transactions are with RTOs.

OPCo recognizes revenues from marketing and risk management transactions that are not derivatives as the performance obligation of delivering the commodity is satisfied. OPCo uses MTM accounting for marketing and risk management transactions that are derivatives unless the derivative is designated in a qualifying cash flow hedge relationship or elected normal under the normal purchase normal sale election. Unrealized MTM gains and losses are included on the balance sheets as Derivative Instrument Assets or Liabilities, as appropriate, and on the statements of income in Operating Revenues. OPCo includes realized gains and losses on marketing and risk management transactions in revenue or expense based on the transaction’s facts and circumstances. The unrealized MTM amounts and some realized gains and losses are deferred as regulatory assets (for losses) and regulatory liabilities (for gains).

Certain qualifying marketing and risk management derivatives transactions are designated as hedges of variability in future cash flows as a result of forecasted transactions (cash flow hedge). In the event OPCo designates a cash flow hedge, the cash flow hedge’s gain or loss is initially recorded as a component of AOCI. When the forecasted transaction is realized and affects net income, OPCo subsequently reclassifies the gain or loss on the hedge from AOCI into revenues or expenses within the same financial statement line item as the forecasted transaction on their statements of income. See “Accounting for Cash Flow Hedging Strategies” section of Note 10 for additional information.

Maintenance

OPCo expenses maintenance costs as incurred. If it becomes probable that OPCo will recover specifically-incurred costs through future rates, a regulatory asset is established to match the expensing of those maintenance costs with its recovery in cost-based regulated revenues. OPCo defers costs above the level included in base rates and amortizes those deferrals commensurate with recovery through rate riders.

Income Taxes and Investment Tax Credits

OPCo uses the liability method of accounting for income taxes. Under the liability method, deferred income taxes are provided for all temporary differences between the book and tax basis of assets and liabilities which will result in a future tax consequence. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which the temporary differences are expected to be recovered or settled.

When the flow-through method of accounting for temporary differences is required by a regulator to be reflected in regulated revenues (that is, when deferred taxes are not included in the cost-of-service for determining regulated rates for electricity), deferred income taxes are recorded and related regulatory assets and liabilities are established to match the regulated revenues and tax expense.

OPCo applies the deferral methodology for the recognition of ITCs. Deferred ITCs are amortized to income tax expense over the life of the asset that generated the credit. Amortization of deferred ITCs begins when the asset is placed in-service, except where regulatory commissions reflect ITCs in the rate-making process, then amortization begins when the utility is able to utilize the ITC on a stand-alone basis.

OPCo accounts for uncertain tax positions in accordance with the accounting guidance for “Income Taxes.” OPCo classifies interest expense or income related to uncertain tax positions as interest expense or income as appropriate and classifies penalties as Penalties on the statements of income.

Excise Taxes

As an agent for some state and local governments, OPCo collects from customers certain excise taxes levied by those state or local governments on customers. OPCo does not record these taxes as revenue or expense.

Debt

Gains and losses from the reacquisition of debt used to finance regulated electric utility plants are deferred and amortized over the remaining term of the reacquired debt in accordance with their rate-making treatment unless the debt is refinanced. If the reacquired debt associated with the regulated business is refinanced, the reacquisition costs attributable to the portions of the business that are subject to cost-based regulatory accounting are generally deferred and amortized over the term of the replacement debt consistent with its recovery in rates.

Debt discount or premium and debt issuance expenses are deferred and amortized generally utilizing the straight-line method over the term of the related debt. The straight-line method approximates the effective interest method and is consistent with the treatment in rates for regulated operations.

Pension and OPEB Plans

OPCo participates in an AEP sponsored qualified pension plan and an unfunded nonqualified pension plan. Substantially all OPCo’s employees are covered by the qualified plan or both the qualified and a nonqualified pension plan. OPCo also participates in OPEB plans sponsored by AEP to provide health and life insurance benefits for retired employees. OPCo is allocated a proportionate share of benefit costs and account for their participation in these plans as multiple-employer plans. See Note 7 - Benefit Plans for additional information including significant accounting policies associated with the plans.

Investments Held in Trust for Future Liabilities

AEP has several trust funds with significant investments intended to provide for future payments of pension and OPEB benefits. All of the trust funds’ investments are diversified and managed in compliance with all laws and regulations. The investment strategy for the trust funds is to use a diversified portfolio of investments to achieve an acceptable rate of return while managing the investment risk of the assets relative to the associated liabilities. To minimize investment risk, the trust funds are broadly diversified among classes of assets, investment strategies and investment managers. Management regularly reviews the actual asset allocations and periodically rebalances the investments to targeted allocations when appropriate. Investment policies and guidelines allow investment managers in approved strategies to use financial derivatives to obtain or manage market exposures and to hedge assets and liabilities. The investments are reported at fair value under the “Fair Value Measurements and Disclosures” accounting guidance.

Benefit Plans

All benefit plan assets are invested in accordance with each plan’s investment policy. The investment policy outlines the investment objectives, strategies and target asset allocations by plan.

The investment philosophies for AEP’s benefit plans support the allocation of assets to minimize risks and optimize net returns. Strategies used include:

•Maintaining a long-term investment horizon.

•Diversifying assets to help control volatility of returns at acceptable levels.

•Managing fees, transaction costs and tax liabilities to maximize investment earnings.

•Using active management of investments where appropriate risk/return opportunities exist.

•Keeping portfolio structure style-neutral to limit volatility compared to applicable benchmarks.

•Using alternative asset classes such as real estate and private equity to maximize return and provide additional portfolio diversification.

The objective of the investment policy for the pension fund is to maintain the funded status of the plan while providing for growth in the plan assets to offset the growth in the plan liabilities. The current target asset allocations are as follows:


Pension Plan Assets	Target
Equity	30	%
Fixed Income	54	%
Other Investments	15	%
Cash and Cash Equivalents	1	%

OPEB Plans Assets	Target
Equity	59	%
Fixed Income	40	%
Cash and Cash Equivalents	1	%

The investment policy for each benefit plan contains various investment limitations. The investment policies establish concentration limits for securities and prohibit the purchase of securities issued by AEP (with the exception of proportionate and immaterial holdings of AEP securities in passive index strategies or certain commingled funds). However, the investment policies do not preclude the benefit trust funds from receiving contributions in the form of AEP securities, provided that the AEP securities acquired by each plan may not exceed the limitations imposed by law.

For equity investments, the concentration limits are generally as follows:

•No security in excess of 5% of all equities.

•Cash equivalents must be less than 10% of an investment manager’s equity portfolio.

•No individual stock may be more than 10% and 7% for pension and OPEB investments, respectively, of each manager’s equity portfolio.

•No securities may be bought or sold on margin or other use of leverage.

For fixed income investments, each investment manager’s portfolio is compared to investment grade, diversified long and intermediate benchmark indices.

A portion of the pension assets is invested in real estate funds to provide diversification, add return and hedge against inflation. Real estate properties are illiquid, difficult to value and not actively traded. The pension plan uses external real estate investment managers to invest in commingled funds that hold real estate properties. To mitigate investment risk in the real estate portfolio, commingled real estate funds are used to ensure that holdings are diversified by region, property type and risk classification. Real estate holdings include core, value-added and opportunistic classifications.

A portion of the pension assets is invested in private equity. Private equity investments add return and provide diversification and typically require a long-term time horizon to evaluate investment performance. Private equity is classified as an alternative investment because it is illiquid, difficult to value and not actively traded. The pension plan uses limited partnerships to invest across the private equity investment spectrum. The private equity holdings are with multiple general partners who help monitor the investments and provide investment selection expertise. The holdings are currently comprised of venture capital, buyout and hybrid debt and equity investments.

AEP participates in a securities lending program with BNY Mellon to provide incremental income on idle assets and to provide income to offset custody fees and other administrative expenses. AEP lends securities to borrowers approved by BNY Mellon in exchange for collateral. All loans are collateralized by at least 102% of the loaned asset’s market value and the collateral is invested. The difference between the rebate owed to the borrower and the collateral rate of return determines the earnings on the loaned security. The securities lending program’s objective is to provide modest incremental income with a limited increase in risk. As of December 31, 2022 and 2021, the fair value of securities on loan as part of the program was $83 million and $137 million, respectively. Cash and securities obtained as collateral exceeded the fair value of the securities loaned as of December 31, 2022 and 2021.

Trust owned life insurance (TOLI) underwritten by The Prudential Insurance Company is held in the OPEB plan trusts. The strategy for holding life insurance contracts in the taxable Voluntary Employees’ Beneficiary Association trust is to minimize taxes paid on the asset growth in the trust. Earnings on plan assets are tax-deferred within the TOLI contract and can be tax-free if held until claims are paid. Life insurance proceeds remain in the trust and are used to fund future retiree medical benefit liabilities. With consideration to other investments held in the trust, the cash value of the TOLI contracts is invested in two diversified funds. A portion is invested in a commingled fund with underlying investments in stocks that are actively traded on major international equity exchanges. The other portion of the TOLI cash value is invested in a diversified, commingled fixed income fund with underlying investments in government bonds, corporate bonds and asset-backed securities.

Cash and cash equivalents are held in each trust to provide liquidity and meet short-term cash needs. Cash equivalent funds are used to provide diversification and preserve principal. The underlying holdings in the cash funds are investment grade money market instruments including commercial paper, certificates of deposit, treasury bills and other types of investment grade short-term debt securities. The cash funds are valued each business day and provide daily liquidity.

Subsequent Events

Management has evaluated the impact of events occurring after December 31, 2022 through February 23, 2023, the date that AEP’s Form 10-K was issued, and has updated such evaluation for disclosure purposes through April 12, 2023. These financial statements include all necessary adjustments and disclosures resulting from these evaluations.

2. NEW ACCOUNTING STANDARDS

During the FASB’s standard-setting process and upon issuance of final standards, management reviews the new accounting literature to determine its relevance, if any, to OPCo’s business. There are no new standards expected to have a material impact on OPCo’s financial statements.

3. RATE MATTERS

OPCo is involved in rate and regulatory proceedings at the FERC and the PUCO. Rate matters can have a material impact on net income, cash flows and possibly financial condition. OPCo’s recent significant rate orders and pending rate filings are addressed in this note.

OVEC Cost Recovery Audits

In December 2021, as part of OVEC cost recovery audits pending before the PUCO, intervenors filed positions claiming that costs incurred by OPCo during the 2018-2019 audit period were imprudent and should be disallowed. In May 2022, intervenors filed for rehearing on the 2016-2017 OVEC cost recovery audit period claiming the PUCO’s April 2022 order to adopt the findings of the audit report were unjust, unlawful and unreasonable for multiple reasons, including the position that OPCo recovered imprudently incurred costs. In June 2022, the PUCO granted rehearing on the 2016-2017 audit period for purposes of further consideration. Management disagrees with these claims and is unable to predict the impact of these disputes; however, if any costs are disallowed or refunds are ordered it could reduce future net income and cash flows and impact financial condition. See "OVEC" section of Note 17 for additional information on AEP and OPCo’s investment in OVEC.

June 2022 Storm Costs

In June 2022, the service territory of OPCo was impacted by strong winds from multiple storms resulting in power outages and damage to the transmission and distribution infrastructures. As of December 31, 2022, OPCo had incurred approximately $20 million in incremental operation and maintenance costs related to service restoration efforts. The incremental storm restoration costs have been deferred as regulatory assets and OPCo is expected to seek recovery in a future filing. In July 2022, intervenors filed a motion requesting the PUCO open a formal investigation into the power outages that occurred as a result of the June storms and determine if OPCo was negligent and liable to consumers for damages incurred as a result of the power outages. Separately, in July 2022, the PUCO directed its staff to conduct an after-action review to examine the circumstances of the event and OPCo’s response to determine if OPCo adhered to the laws and rules in the state, followed its PUCO-approved emergency plan and responded appropriately to the event in an effort to mitigate the negative effects. In January 2023, the PUCO Staff issued a report which concluded OPCo was required to proactively shut down parts of its distribution system in order to avoid damages to the system and further outages and that OPCo adhered to its emergency plan. The report also directed OPCo to revise its vegetation programs around high voltage transmission lines and recommended that it make improvements to its emergency communications procedures. If any of the storm restoration costs are not recoverable, it could reduce future net income and cash flows and impact financial condition.

Ohio ESP Filings

In January 2023, OPCo filed an application with the PUCO to approve an ESP that included proposed rate adjustments, proposed new riders and the continuation and modification of certain existing riders, including the DIR, effective June 2024 through May 2030. The proposal includes a return on common equity of 10.65% on capital costs for certain riders. If OPCo is ultimately not permitted to fully collect its ESP rates it could reduce future net income and cash flows and impact financial condition.

FERC RTO Incentive

In February 2022, the Office of the Ohio Consumers’ Counsel (OCC) filed a complaint against AEPSC, American Transmission Systems, Inc. and Duke Energy Ohio, alleging the 50 basis point RTO incentive included in Ohio Transmission Owners’ respective transmission formula rates is not just and reasonable and therefore should be

eliminated on the basis that RTO participation is not voluntary, but rather is required by Ohio law. In March 2022, AEPSC filed a motion to dismiss the OCC’s February 2022 complaint with the FERC on the basis of certain deficiencies, including that the complaint fails to request relief that can be granted under FERC regulations because AEPSC is not a public utility nor does it have a transmission rate on file with the FERC. In December 2022, the FERC issued an order removing the 50 basis point RTO incentive from OPCo and OHTCo transmission formula rates effective the date of the February 2022 complaint filing and directed OPCo and OHTCo to provide refunds, with interest, within sixty days of the date of its order. In January 2023, both AEPSC and the OCC filed requests for rehearing with the FERC. A FERC order on rehearing is expected in 2023. Based on management’s preliminary estimates, the December 2022 FERC order is expected to reduce AEP’s pretax income by approximately $20 million on an annual basis.

4. EFFECTS OF REGULATION

Regulatory assets and liabilities are comprised of the following items:



	December 31,				Remaining Recovery Period
Regulatory Assets:	2022		2021
	(in millions)

Regulatory assets pending final regulatory approval:

Regulatory Assets Currently Not Earning a Return
Storm-Related Costs	$	33.8	$	3.8
Total Regulatory Assets Pending Final Regulatory Approval	33.8		3.8

Regulatory assets approved for recovery:

Regulatory Assets Currently Earning a Return
Ohio Distribution Decoupling	19.5		41.6		2 years
Ohio Basic Transmission Cost Rider	14.3		5.2		2 years
Ohio Economic Development Rider	1.1		10.1		2 years
Total Regulatory Assets Currently Earning a Return	34.9		56.9
Regulatory Assets Currently Not Earning a Return
Pension and OPEB Funded Status	142.7		83.3		12 years
Unrealized Loss on Forward Commitments	40.0		92.1		10 years
Income Tax Assets	60.7		62.0		(a)
Ohio Enhanced Service Reliability Plan	33.3		9.5		2 years
Smart Grid Costs	25.4		19.3		2 years
Postemployment Benefits	6.2		6.2		3 years
PJM Load Service Entity Formula Rate True-up	—		7.5
Other Regulatory Assets Approved for Recovery	13.0		11.5		various
Total Regulatory Assets Currently Not Earning a Return	321.3		291.4

Total Regulatory Assets Approved for Recovery	356.2		348.3

Total FERC Account 182.3 Regulatory Assets	$	390.0	$	352.1

a.Recovered over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets.



	December 31,				Remaining Refund Period
	2022		2021
Regulatory Liabilities:	(in millions)


Regulatory liabilities pending final regulatory determination:

Regulatory Liabilities Currently Not Paying a Return
Other Regulatory Liabilities Pending Final Regulatory Determination	$	0.2	$	0.2
Total Regulatory Liabilities Pending Final Regulatory Determination	0.2		0.2

Regulatory liabilities approved for payment:

Regulatory Liabilities Currently Paying a Return
Income Tax Liabilities (a)	512.6		542.6		(b)
Total Regulatory Liabilities Currently Paying a Return	512.6		542.6

Regulatory Liabilities Currently Not Paying a Return
OVEC Purchased Power	47.1		14.8		2 years
Over-recovered Fuel Costs	32.2		15.2		10 years
Peak Demand Reduction/Energy Efficiency	23.6		22.5		2 years
PJM Transmission Enhancement Refund	14.7		19.6		3 years
Other Regulatory Liabilities Approved for Payment	7.8		0.4		various
Total Regulatory Liabilities Currently Not Paying a Return	125.4		72.5

Total Regulatory Liabilities Approved for Payment	638.0		615.1

Total FERC 254 Account Regulatory Liabilities	$	638.2	$	615.3

(a)Predominately pays a return due to the inclusion of Excess ADIT in rate base.

(b)Recovered over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $162 million and $191 million for the years ended December 31, 2022 and 2021, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2022 is to be refunded over 6 years.

5. COMMITMENTS, GUARANTEES AND CONTINGENCIES

OPCo is subject to certain claims and legal actions arising in the ordinary course of business. In addition, OPCo’s business activities are subject to extensive governmental regulation related to public health and the environment. The ultimate outcome of such pending or potential litigation cannot be predicted. Management accrues contingent liabilities only when management concludes that it is both probable that a liability has been incurred at the date of the financial statements and the amount of loss can be reasonably estimated. When management determines that it is not probable, but rather reasonably possible that a liability has been incurred at the date of the financial statements, management discloses such contingencies and the possible loss or range of loss if such estimate can be made. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may not represent the maximum possible loss exposure. Circumstances change over time and actual results may vary significantly from estimates.

For current proceedings not specifically discussed below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on the financial statements.

COMMITMENTS

OPCo has substantial commitments for energy and capacity contracts as part of the normal course of business. Certain contracts contain penalty provisions for early termination.

In accordance with the accounting guidance for “Commitments”, the following table summarizes OPCo’s actual contractual commitments as of December 31, 2022:


Contractual Commitments	Less Than 1 Year		2-3 Years		4-5 Years		After 5 Years		Total
	(in millions)
Energy and Capacity Purchase Contracts	$	34.4	$	66.5	$	63.7	$	169.8	$	334.4

GUARANTEES

Liabilities for guarantees are recorded in accordance with the accounting guidance for “Guarantees.” There is no collateral held in relation to any guarantees. In the event any guarantee is drawn, there is no recourse to third-parties unless specified below.

Indemnifications and Other Guarantees

Contracts

OPCo enters into certain types of contracts which require indemnifications. Typically these contracts include, but are not limited to, sale agreements, lease agreements, purchase agreements and financing agreements. Generally, these agreements may include, but are not limited to, indemnifications around certain tax, contractual and environmental matters. With respect to sale agreements, exposure generally does not exceed the sale price. As of December 31, 2022, there were no material liabilities recorded for any indemnifications.

Lease Obligations

OPCo leases equipment under master lease agreements. See “Master Lease Agreements” section of Note 12 for additional information.

ENVIRONMENTAL CONTINGENCIES

The Comprehensive Environmental Response Compensation and Liability Act (Superfund) and State Remediation

By-products from the generation of electricity include materials such as ash, slag and sludge. Coal combustion by-products, which constitute the overwhelming percentage of these materials, are typically treated and deposited in captive disposal facilities or are beneficially utilized. In addition, the generation plants and transmission and distribution facilities have used asbestos, polychlorinated biphenyls and other hazardous and non-hazardous materials. OPCo currently incurs costs to dispose of these substances safely.

Superfund addresses clean-up of hazardous substances that are released to the environment. The Federal EPA administers the clean-up programs. Several states enacted similar laws. As of December 31, 2022, OPCo was named as a Potentially Responsible Party (PRP) for two sites by the Federal EPA for which alleged liability is unresolved. There are three additional sites for which OPCo received information requests which could lead to PRP designation. In those instances where a PRP or defendant has been named, disposal or recycling activities were in accordance with the then-applicable laws and regulations. Superfund does not recognize compliance as a defense, but imposes strict liability on parties who fall within its broad statutory categories. Liability has been resolved for a number of sites with no significant effect on net income.

Management evaluates the potential liability for each Superfund site separately, but several general statements can be made about potential future liability. Allegations that materials were disposed at a particular site are often unsubstantiated and the quantity of materials deposited at a site can be small and often non-hazardous. Although Superfund liability has been interpreted by the courts as joint and several, typically many parties are named as PRPs for each site and several of the parties are financially sound enterprises. As of December 31, 2022, management’s estimates do not anticipate material clean-up costs for identified Superfund sites.

OPERATIONAL CONTINGENCIES

Insurance and Potential Losses

OPCo maintains insurance coverage normal and customary for electric utilities, subject to various deductibles. OPCo also maintains property and casualty insurance that may cover certain physical damage or third-party injuries caused by cyber security incidents. Insurance coverage includes all risks of physical loss or damage to nonnuclear assets, subject to insurance policy conditions and exclusions. Covered property generally includes power plants, substations, facilities and inventories. Excluded property generally includes transmission and distribution lines, poles and towers. The insurance programs also generally provide coverage against loss arising from certain claims made by third-parties and are in excess of retentions absorbed by OPCo. Coverage is generally provided by a combination of the protected cell of EIS and/or various industry mutual and/or commercial insurance carriers.

Some potential losses or liabilities may not be insurable or the amount of insurance carried may not be sufficient to meet potential losses and liabilities, including, but not limited to, liabilities relating to a cyber security incident. Future losses or liabilities, if they occur, which are not completely insured, unless recovered from customers, could reduce future net income and cash flows and impact financial condition.

Claims Challenging Transition of American Electric Power System Retirement Plan to Cash Balance Formula

Four participants in The American Electric Power System Retirement Plan (the Plan) filed a class action complaint in December 2021 in the U.S. District Court for the Southern District of Ohio against AEPSC and the Plan. When the Plan’s benefit formula was changed in the year 2000, AEP provided a special provision for employees hired before January 1, 2001, allowing them to continue benefit accruals under the then benefit formula for a full 10 years alongside of the new cash balance benefit formula then being implemented. Employees who were hired on or after January 1, 2001 accrued benefits only under the new cash balance benefit formula. The plaintiffs assert a number of claims on behalf of themselves and the purported class, including that: (a) the Plan violates the requirements under the Employee Retirement Income Security Act (ERISA) intended to preclude back-loading the accrual of benefits to the end of a participant’s career, (b) the Plan violates the age discrimination prohibitions of ERISA and the Age Discrimination in Employment Act and (c) AEP failed to provide required notice regarding the changes to the Plan. Among other relief, the Complaint seeks reformation of the Plan to provide additional benefits and the recovery of plan benefits for former employees under such reformed plan. The plaintiffs previously had submitted claims for additional plan benefits to AEP, which were denied. On February 15, 2022, AEPSC and the Plan filed a motion to dismiss the complaint for failure to state a claim. On August 16, 2022, the district court granted the motion to dismiss the complaint without prejudice. The plaintiffs filed a motion for leave to file an amended complaint, which the Court denied on December 1, 2022. The plaintiffs did not file an appeal by the deadline of January 3, 2023.

Litigation Related to Ohio House Bill 6 (HB 6)

In 2019, Ohio adopted and implemented HB 6 which benefits OPCo by authorizing rate recovery for certain costs including renewable energy contracts and OVEC’s coal-fired generating units. OPCo engaged in lobbying efforts and provided testimony during the legislative process in connection with HB 6. In July 2020, an investigation led by the U.S. Attorney’s Office resulted in a federal grand jury indictment of an Ohio legislator and associates in connection with an alleged racketeering conspiracy involving the adoption of HB 6. After AEP learned of the criminal allegations against the Ohio legislator and others relating to HB 6, AEP, with assistance from outside advisors, conducted a review of the circumstances surrounding the passage of the bill. Management does not believe that AEP was involved in any wrongful conduct in connection with the passage of HB 6.

In August 2020, an AEP shareholder filed a putative class action lawsuit in the U.S. District Court for the Southern District of Ohio against AEP and certain of its officers for alleged violations of securities laws. The amended complaint alleged misrepresentations or omissions by AEP regarding: (a) its alleged participation in or connection to public corruption with respect to the passage of HB 6 and (b) its regulatory, legislative, political contribution, 501(c)(4) organization contribution and lobbying activities in Ohio. The complaint sought monetary damages, among other forms of relief. In December 2021, the district court issued an opinion and order dismissing the securities litigation complaint with prejudice, determining that the complaint failed to plead any actionable misrepresentations or omissions. The plaintiffs did not appeal the ruling.

In January 2021, an AEP shareholder filed a derivative action in the U.S. District Court for the Southern District of Ohio purporting to assert claims on behalf of AEP against certain AEP officers and directors. In February 2021, a second AEP shareholder filed a similar derivative action in the Court of Common Pleas of Franklin County, Ohio. In April 2021, a third AEP shareholder filed a similar derivative action in the U.S. District Court for the Southern District of Ohio and a fourth AEP shareholder filed a similar derivative action in the Supreme Court for the State of New York, Nassau County. These derivative complaints allege the officers and directors made misrepresentations and omissions similar to those alleged in the putative securities class action lawsuit filed against AEP. The derivative complaints together assert claims for: (a) breach of fiduciary duty, (b) waste of corporate assets, (c) unjust enrichment, (d) breach of duty for insider trading and (e) contribution for violations of sections 10(b) and 21D of the Securities Exchange Act of 1934; and seek monetary damages and changes to

AEP’s corporate governance and internal policies among other forms of relief. The court entered a scheduling order in the New York state court derivative action staying the case other than with respect to briefing the motion to dismiss. AEP filed substantive and forum-based motions to dismiss on April 29, 2022. On September 13, 2022, the New York state court granted the forum-based motion to dismiss with prejudice and the plaintiffs subsequently filed a notice of appeal with the New York appellate court. On January 20, 2023, the New York plaintiff filed a motion to intervene in the pending Ohio federal court action and withdrew his appeal in New York on January 24, 2023. AEP filed a brief in opposition to intervention on February 3, 2023. The two derivative actions pending in federal district court in Ohio have been consolidated and the plaintiffs in the consolidated action filed an amended complaint. AEP filed a motion to dismiss the amended complaint on May 3, 2022 and briefing on the motion to dismiss has been completed. Discovery remains stayed pending the district court’s ruling on the motion to dismiss. The plaintiff in the Ohio state court case advised that they no longer agreed to stay the proceedings, therefore, AEP filed a motion to continue the stays of proceedings on May 20, 2022 and the plaintiff filed an amended complaint on June 2, 2022. On June 15, 2022, the Ohio state court entered an order continuing the stays of that case until the resolution of the consolidated derivative actions pending in Ohio federal district court. The defendants will continue to defend against the claims. Management is unable to determine a range of potential losses that is reasonably possible of occurring.

In March 2021, AEP received a litigation demand letter from counsel representing a purported AEP shareholder. The litigation demand letter is directed to the Board of Directors of AEP and contains factual allegations involving HB 6 that are generally consistent with those in the derivative litigation filed in state and federal court. The letter demands, among other things, that the AEP Board undertake an independent investigation into alleged legal violations by directors and officers, and that, following such investigation, AEP commence a civil action for breaches of fiduciary duty and related claims and take appropriate disciplinary action against those individuals who allegedly harmed the company. The shareholder that sent the letter has since withdrawn the litigation demand, which is now terminated and of no further effect.

In May 2021, AEP received a subpoena from the SEC’s Division of Enforcement seeking various documents, including documents relating to the passage of HB 6 and documents relating to AEP’s policies and financial processes and controls. In August 2022, AEP received a second subpoena from the SEC seeking various additional documents relating to its ongoing investigation. AEP is cooperating fully with the SEC’s investigation, which has included taking testimony from certain individuals. Although the outcome of the SEC’s investigation cannot be predicted, management does not believe the results of this investigation will have a material impact on financial condition, results of operations or cash flows.

6. BENEFIT PLANS

For a discussion of investment strategy, investment limitations, target asset allocations and the classification of investments within the fair value hierarchy, see “Fair Value Measurements of Assets and Liabilities” and “Investments Held in Trust for Future Liabilities” sections of Note 1.

OPCo participates in an AEP sponsored qualified pension plan and an unfunded non-qualified pension plans. Substantially all employees are covered by the qualified plan or both the qualified and a non-qualified pension plan. OPCo also sponsors OPEB plans to provide health and life insurance benefits for retired employees.

OPCo recognizes the funded status associated with defined benefit pension and OPEB plans on the balance sheets. Disclosures about the plans are required by the “Compensation – Retirement Benefits” accounting guidance. OPCo recognizes an asset for a plan’s overfunded status or a liability for a plan’s underfunded status, and recognize, as a component of other comprehensive income, the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost. OPCo records a regulatory asset instead of other comprehensive income for qualifying benefit costs of regulated operations that for rate-making purposes are deferred for future recovery. The cumulative funded status adjustment is equal to the remaining unrecognized deferrals for unamortized actuarial losses or gains, prior service costs and transition obligations, such that remaining deferred costs result in an AOCI equity reduction or regulatory asset and deferred gains result in an AOCI equity addition or regulatory liability.

Actuarial Assumptions for Benefit Obligations

The weighted-average assumptions used in the measurement of the benefit obligations are shown in the following table:


	Pension Plans						OPEB
	December 31,
Assumption	2022			2021			2022		2021
Discount Rate	5.50	%		2.90	%		5.50	%	2.90	%
Interest Crediting Rate	4.25	%		4.00	%		NA		NA
Rate of Compensation Increase	5.35	%	(a)	5.30	%	(a)	NA		NA

(a)Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees.

NA Not applicable.

A duration-based method is used to determine the discount rate for the plans. A hypothetical portfolio of high quality corporate bonds is constructed with cash flows matching the benefit plan liability. The composite yield on the hypothetical bond portfolio is used as the discount rate for the plan.

For 2022, the rate of compensation increase assumed varies with the age of the employee, ranging from 3% per year to 11.5% per year, with the average increase shown in the table above.

Actuarial Assumptions for Net Periodic Benefit Costs

The weighted-average assumptions used in the measurement of benefit costs are shown in the following table:


	Pension Plans						OPEB
	Year Ended December 31,
Assumption	2022			2021			2022		2021
Discount Rate	2.90	%		2.50	%		2.90	%	2.55	%
Interest Crediting Rate	4.00	%		4.00	%		NA		NA
Expected Return on Plan Assets	5.25	%		4.75	%		5.50	%	4.75	%
Rate of Compensation Increase	5.35	%	(a)	5.30	%	(a)	NA		NA

(a)Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees.

NA Not applicable.

The expected return on plan assets was determined by evaluating historical returns, the current investment climate (yield on fixed income securities and other recent investment market indicators), rate of inflation, third-party forecasts and current prospects for economic growth.

The health care trend rate assumptions used for OPEB plans measurement purposes are shown below:


	December 31,
Health Care Trend Rates	2022		2021
Initial	7.50	%	6.25	%
Ultimate	4.50	%	4.50	%
Year Ultimate Reached	2029		2029

Significant Concentrations of Risk within Plan Assets

In addition to establishing the target asset allocation of plan assets, the investment policy also places restrictions on securities to limit significant concentrations within plan assets. The investment policy establishes guidelines that govern maximum market exposure, security restrictions, prohibited asset classes, prohibited types of transactions, minimum credit quality, average portfolio credit quality, portfolio duration and concentration limits. The guidelines were established to mitigate the risk of loss due to significant concentrations in any investment. Management monitors the plans to control security diversification and ensure compliance with the investment policy. As of December 31, 2022, the assets were invested in compliance with all investment limits. See “Investments Held in Trust for Future Liabilities” section of Note 1 for limit details.

Benefit Plan Obligations, Plan Assets, Funded Status and Amounts Recognized on the Balance Sheets

For the year ended December 31, 2022, the pension plans had an actuarial gain primarily due to an increase in the discount rate and was partially offset by increases in the assumed lump sum conversion rate and cash balance account interest crediting rate. For the year ended December 31, 2022, the OPEB plans had an actuarial gain primarily due to an increase in the discount rate and updated per capita cost assumptions. The OPEB plans gains were partially offset by a projected reduction in the Employer Group Waiver Program catastrophic reinsurance offset provided to AEP, resulting from the Inflation Reduction Act as well as an increase in the health care cost trend assumption. For the year ended December 31, 2021, the pension plans had an actuarial gain primarily due to an increase in the discount rate, partially offset by less favorable demographic experience than expected, resulting from the updated census information as of January 1, 2021. For the year ended December 31, 2021, the OPEB plans had an actuarial gain primarily due to an increase in the discount rate and an update of the projected reimbursements from the Employer Group Waiver Program under Medicare Part D. The following tables provide a reconciliation of the changes in the plans’ benefit obligations, fair value of plan assets, funded status and the presentation on the balance sheets. The benefit obligation for the defined benefit pension and OPEB plans are the projected benefit obligation and the accumulated benefit obligation, respectively.


	Pension Plans				OPEB
	2022		2021		2022		2021
Change in Benefit Obligation	(in millions)
Benefit Obligation as of January 1,	$	470.7	$	510.3	$	104.9	$	126.4
Service Cost	11.2		11.4		0.6		0.8
Interest Cost	13.3		12.5		3.0		3.0
Actuarial Gain	(97.9)		(24.1)		(8.9)		(15.6)
Plan Amendments	—		—		—		(0.6)
Benefit Payments	(33.7)		(39.4)		(15.5)		(13.6)
Participant Contributions	—		—		4.8		4.5
Benefit Obligation as of December 31,	$	363.6	$	470.7	$	88.9	$	104.9

Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	$	524.8	$	543.1	$	220.0	$	213.0
Actual Gain (Loss) on Plan Assets	(84.8)		21.1		(43.1)		16.1
Company Contributions	0.1		—		—		—
Participant Contributions	—		—		4.8		4.5
Benefit Payments	(33.7)		(39.4)		(15.5)		(13.6)
Fair Value of Plan Assets as of December 31,	$	406.4	$	524.8	$	166.2	$	220.0

Funded Status as of December 31,	$	42.8	$	54.1	$	77.3	$	115.1


	Pension Plans				OPEB
	December 31,
	2022		2021		2022		2021
	(in millions)
Special Funds – Prepaid Benefit Costs	$	43.1	$	54.8	$	77.3	$	115.1
Accumulated Provision for Pensions and Benefits – Long-term Benefit Liability	(0.3)		(0.7)		—		—
Funded Status	$	42.8	$	54.1	$	77.3	$	115.1

Amounts Included in Regulatory Assets, Deferred Income Taxes and AOCI

The following tables show the components of the plans included in regulatory assets, Accumulated Deferred Income Taxes, and income tax expense and the items attributable to the change in these components:


	Pension Plans				OPEB
	December 31,
	2022		2021		2022		2021
Components	(in millions)
Net Actuarial (Gain) Loss	$	124.3	$	118.1	$	27.6	$	(18.5)
Prior Service Credit	—		—		(9.2)		(16.3)

Recorded as
Regulatory Assets	$	124.3	$	118.1	$	18.4	$	(34.8)


	Pension Plans				OPEB
	2022		2021		2022		2021
Components	(in millions)
Actuarial (Gain) Loss During the Year	$	11.7	$	(22.8)	$	46.1	$	(22.1)
Amortization of Actuarial Loss	(5.5)		(9.1)		—		—
Prior Service Credit	—		—		—		(0.6)
Amortization of Prior Service Credit	—		—		7.1		7.2
Change for the Year Ended December 31,	$	6.2	$	(31.9)	$	53.2	$	(15.5)

Determination of Pension Expense

The determination of pension expense or income is based on a market-related valuation of assets which reduces year-to-year volatility. This market-related valuation recognizes investment gains or losses over a five-year period from the year in which they occur. Investment gains or losses for this purpose are the difference between the expected return calculated using the market-related value of assets and the actual return.

Pension and OPEB Assets

The fair value tables within Pension and OPEB Assets present the classification of assets for AEP within the fair value hierarchy. All Level 1, 2, 3 and Other amounts can be allocated to OPCo using the percentages in the table below:


Pension Plan				OPEB
December 31,
2022		2021		2022		2021
9.9	%	9.8	%	10.7	%	10.8	%

The following table presents the classification of pension plan assets for AEP within the fair value hierarchy as of December 31, 2022:


Asset Class	Level 1		Level 2		Level 3		Other		Total		Year End Allocation
	(in millions)
Equities (a):
Domestic	$	347.6	$	—	$	—	$	—	$	347.6	8.4	%
International	398.4		—		—		—		398.4		9.7	%
Common Collective Trusts (b)	—		—		—		379.9		379.9		9.2	%
Subtotal – Equities	746.0		—		—		379.9		1,125.9		27.3	%

Fixed Income (a):
United States Government and Agency Securities	(0.6)		1,071.4		—		—		1,070.8		26.0	%
Corporate Debt	—		891.7		—		—		891.7		21.6	%
Foreign Debt	—		140.2		—		—		140.2		3.4	%
State and Local Government	—		37.0		—		—		37.0		0.9	%
Other – Asset Backed	—		0.8		—		—		0.8		—	%
Subtotal – Fixed Income	(0.6)		2,141.1		—		—		2,140.5		51.9	%

Infrastructure (b)	—		—		—		109.2		109.2		2.6	%
Real Estate (b)	—		—		—		276.9		276.9		6.7	%
Alternative Investments (b)	—		—		—		319.7		319.7		7.8	%
Cash and Cash Equivalents (b)	—		64.9		—		58.3		123.2		3.0	%
Other – Pending Transactions and Accrued Income (c)	—		—		—		29.3		29.3		0.7	%

Total	$	745.4	$	2,206.0	$	—	$	1,173.3	$	4,124.7	100.0	%

(a)Includes investment securities loaned to borrowers under the securities lending program. See the “Investments Held in Trust for Future Liabilities” section of Note 1 for additional information.

(b)Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share.

(c)Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement.

The following table presents the classification of OPEB plan assets for AEP within the fair value hierarchy as of December 31, 2022:


Asset Class	Level 1		Level 2		Level 3		Other		Total		Year End Allocation
	(in millions)
Equities:
Domestic	$	414.1	$	—	$	—	$	—	$	414.1	26.7	%
International	265.0		—		—		—		265.0		17.1	%
Common Collective Trusts (a)	—		—		—		169.1		169.1		10.9	%
Subtotal – Equities	679.1		—		—		169.1		848.2		54.7	%

Fixed Income:
Common Collective Trust – Debt (a)	—		—		—		120.3		120.3		7.8	%
United States Government and Agency Securities	0.1		155.8		—		—		155.9		10.1	%
Corporate Debt	—		141.5		—		—		141.5		9.1	%
Foreign Debt	—		21.0		—		—		21.0		1.4	%
State and Local Government	62.9		7.8		—		—		70.7		4.6	%
Subtotal – Fixed Income	63.0		326.1		—		120.3		509.4		33.0	%

Trust Owned Life Insurance:
International Equities	—		46.7		—		—		46.7		3.0	%
United States Bonds	—		110.3		—		—		110.3		7.1	%
Subtotal – Trust Owned Life Insurance	—		157.0		—		—		157.0		10.1	%

Cash and Cash Equivalents (a)	23.2		—		—		6.7		29.9		1.9	%
Other – Pending Transactions and Accrued Income (b)	—		—		—		4.8		4.8		0.3	%

Total	$	765.3	$	483.1	$	—	$	300.9	$	1,549.3	100.0	%

(a)Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share.

(b)Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement.

The following table presents the classification of pension plan assets for AEP within the fair value hierarchy as of December 31, 2021:


Asset Class	Level 1		Level 2		Level 3		Other		Total		Year End Allocation
	(in millions)
Equities (a):
Domestic	$	388.9	$	—	$	—	$	—	$	388.9	7.2	%
International	465.7		—		—		—		465.7		8.7	%
Common Collective Trusts (b)	—		—		—		463.9		463.9		8.7	%
Subtotal – Equities	854.6		—		—		463.9		1,318.5		24.6	%

Fixed Income (a):
United States Government and Agency Securities	0.1		1,557.6		—		—		1,557.7		29.1	%
Corporate Debt	—		1,295.9		—		—		1,295.9		24.2	%
Foreign Debt	—		259.4		—		—		259.4		4.8	%
State and Local Government	—		57.1		—		—		57.1		1.1	%
Other – Asset Backed	—		1.3		—		—		1.3		—	%
Subtotal – Fixed Income	0.1		3,171.3		—		—		3,171.4		59.2	%

Infrastructure (b)	—		—		—		92.1		92.1		1.7	%
Real Estate (b)	—		—		—		232.6		232.6		4.4	%
Alternative Investments (b)	—		—		—		448.8		448.8		8.4	%
Cash and Cash Equivalents (b)	—		64.3		—		53.4		117.7		2.2	%
Other – Pending Transactions and Accrued Income (c)	—		—		—		(28.2)		(28.2)		(0.5)	%

Total	$	854.7	$	3,235.6	$	—	$	1,262.6	$	5,352.9	100.0	%

(b)Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share.

(c)Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement.

The following table presents the classification of OPEB plan assets for AEP within the fair value hierarchy as of December 31, 2021:


Asset Class	Level 1		Level 2		Level 3		Other		Total		Year End Allocation
	(in millions)
Equities:
Domestic	$	474.0	$	—	$	—	$	—	$	474.0	23.2	%
International	296.3		—		—		—		296.3		14.5	%
Common Collective Trusts (a)	—		—		—		265.0		265.0		13.0	%
Subtotal – Equities	770.3		—		—		265.0		1,035.3		50.7	%

Fixed Income:
Common Collective Trust – Debt (a)	—		—		—		167.7		167.7		8.2	%
United States Government and Agency Securities	—		222.4		—		—		222.4		10.9	%
Corporate Debt	—		233.2		—		—		233.2		11.4	%
Foreign Debt	—		39.8		—		—		39.8		2.0	%
State and Local Government	91.9		13.6		—		—		105.5		5.1	%
Subtotal – Fixed Income	91.9		509.0		—		167.7		768.6		37.6	%

Trust Owned Life Insurance:
International Equities	—		23.4		—		—		23.4		1.1	%
United States Bonds	—		171.3		—		—		171.3		8.4	%
Subtotal – Trust Owned Life Insurance	—		194.7		—		—		194.7		9.5	%

Cash and Cash Equivalents (a)	33.0		—		—		6.7		39.7		1.9	%
Other – Pending Transactions and Accrued Income (b)	—		—		—		6.0		6.0		0.3	%

Total	$	895.2	$	703.7	$	—	$	445.4	$	2,044.3	100.0	%

(a)Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share.

(b)Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement.

Accumulated Benefit Obligation

The accumulated benefit obligation for the pension plans is as follows:


	December 31,
Accumulated Benefit Obligation	2022		2021
	(in millions)
Qualified Pension Plan	$	344.1	$	440.0
Nonqualified Pension Plans	0.1		0.3
Total as of December 31, 2022	$	344.2	$	440.3

Obligations in Excess of Fair Values

The tables below show the underfunded pension plans that had obligations in excess of plan assets.

Projected Benefit Obligation


	December 31,
	2022		2021
	(in millions)
Projected Benefit Obligation	$	0.3	$	0.7
Fair Value of Plan Assets	—		—
Underfunded Projected Benefit Obligation	$	(0.3)	$	(0.7)

Accumulated Benefit Obligation


	December 31,
	2022		2021
	(in millions)
Accumulated Benefit Obligation	$	0.1	$	0.3
Fair Value of Plan Assets	—		—
Underfunded Accumulated Benefit Obligation	$	(0.1)	$	(0.3)

Estimated Future Benefit Payments and Contributions

The table below reflects the total benefits expected to be paid from the plan or from OPCo’s assets. The payments include the participants’ contributions to the plan for their share of the cost. Future benefit payments are dependent on the number of employees retiring, whether the retiring employees elect to receive pension benefits as annuities or as lump sum distributions, future integration of the benefit plans with changes to Medicare and other legislation, future levels of interest rates and variances in actuarial results. The estimated payments for the pension benefits and OPEB are as follows:


	Estimated Payments
	Pension Plans		OPEB
	(in millions)
2023	$	32.3	$	12.6
2024	31.9		12.6
2025	32.4		13.5
2026	32.0		13.4
2027	31.6		13.3
Years 2028 to 2032, in Total	146.0		62.3

Components of Net Periodic Benefit Cost

The following table provides the components of net periodic benefit cost (credit) for the plans:


	Pension Plans				OPEB
	Years Ended December 31,
	2022		2021		2022		2021
	(in millions)
Service Cost	$	11.2	$	11.4	$	0.6	$	0.8
Interest Cost	13.3		12.5		3.0		3.0
Expected Return on Plan Assets	(24.8)		(22.3)		(12.0)		(9.7)
Amortization of Prior Service Credit	—		—		(7.1)		(7.2)
Amortization of Net Actuarial Loss	5.5		9.1		—		—
Net Periodic Benefit Cost (Credit)	5.2		10.7		(15.5)		(13.1)
Capitalized Portion	(6.1)		(6.2)		(0.3)		(0.4)
Net Periodic Benefit Cost (Credit) Recognized in Expense	$	(0.9)	$	4.5	$	(15.8)	$	(13.5)

American Electric Power System Retirement Savings Plan

OPCo participates in an AEP sponsored defined contribution retirement savings plan, the American Electric Power System Retirement Savings Plan, for substantially all employees. This qualified plan offers participants an opportunity to contribute a portion of their pay, includes features under Section 401(k) of the Internal Revenue Code and provides for company matching contributions. The matching contributions to the plan are 100% of the first 1% of eligible employee contributions and 70% of the next 5% of contributions. The cost for matching contributions to the retirement savings plans for the years ended December 31, 2022 and 2021 were $8 million and $7 million, respectively.

7. BUSINESS SEGMENTS

OPCo has one reportable segment, an electricity transmission and distribution business. OPCo’s other activities are insignificant.

8. DERIVATIVES AND HEDGING

OBJECTIVES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS

AEPSC is agent for and transacts on behalf of OPCo.

OPCo is exposed to certain market risks as participant in the electricity markets. These risks include commodity price risks which may be subject to capacity risk, interest rate risk and credit risk. These risks represent the risk of loss that may impact OPCo due to changes in the underlying market prices or rates. Management utilizes derivative instruments to manage these risks.

STRATEGIES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS TO ACHIEVE OBJECTIVES

Risk Management Strategies

The strategy surrounding the use of derivative instruments primarily focuses on managing risk exposures, future cash flows and creating value utilizing both economic and formal hedging strategies. The risk management strategies also include the use of derivative instruments for trading purposes which focus on seizing market opportunities to create value driven by expected changes in the market prices of the commodities. To accomplish these objectives, OPCo primarily employs risk management contracts including physical and financial forward purchase-and-sale contracts and, to a lesser extent, OTC swaps and options. Not all risk management contracts meet the definition of a derivative under the accounting guidance for “Derivatives and Hedging.” Derivative risk management contracts elected normal under the normal purchases and normal sales scope exception are not subject to the requirements of this accounting guidance.

OPCo utilizes power, capacity, interest rate and, to a lesser extent, heating oil, gasoline and other commodity contracts to manage the risk associated with the energy business. OPCo utilizes interest rate derivative contracts in order to manage the interest rate exposure associated with the commodity portfolio. For disclosure purposes, such risks are grouped as “Commodity,” as these risks are related to energy risk management activities. OPCo also utilizes derivative contracts to manage interest rate risk associated with debt financing. For disclosure purposes, these risks are grouped as “Interest Rate.” The amount of risk taken is determined by the Commercial Operations, Energy Supply and Finance groups in accordance with established risk management policies as approved by the Finance Committee of the Board of Directors.

The following table represents the gross notional volume of outstanding derivative contracts:


Notional Volume of Derivative Instruments

Primary Risk Exposure	2022	2021	Unit of Measure
	(in millions)
Commodity:
Power	2.5	2.7	MWhs
Heating Oil and Gasoline	1.4	1.5	Gallons

Cash Flow Hedging Strategies

OPCo utilizes cash flow hedges on certain derivative transactions for the purchase-and-sale of power (“Commodity”) in order to manage the variable price risk related to forecasted purchases and sales. Management monitors the potential impacts of commodity price changes and, where appropriate, enters into derivative

transactions to protect profit margins for a portion of future electricity sales and purchases. OPCo does not hedge all commodity price risk.

OPCo utilizes a variety of interest rate derivative transactions in order to manage interest rate risk exposure. OPCo also utilizes interest rate derivative contracts to manage interest rate exposure related to future borrowings of fixed-rate debt. OPCo does not hedge all interest rate exposure.

ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND THE IMPACT ON THE FINANCIAL STATEMENTS

The accounting guidance for “Derivatives and Hedging” requires recognition of all qualifying derivative instruments as either assets or liabilities on the balance sheets at fair value. The fair values of derivative instruments accounted for using MTM accounting or hedge accounting are based on exchange prices and broker quotes. If a quoted market price is not available, the estimate of fair value is based on the best information available including valuation models that estimate future energy prices based on existing market and broker quotes and other assumptions. In order to determine the relevant fair values of the derivative instruments, OPCo applies valuation adjustments for discounting, liquidity and credit quality.

Credit risk is the risk that a counterparty will fail to perform on the contract or fail to pay amounts due. Liquidity risk represents the risk that imperfections in the market will cause the price to vary from estimated fair value based upon prevailing market supply and demand conditions. Since energy markets are imperfect and volatile, there are inherent risks related to the underlying assumptions in models used to fair value risk management contracts. Unforeseen events may cause reasonable price curves to differ from actual price curves throughout a contract’s term and at the time a contract settles. Consequently, there could be significant adverse or favorable effects on future net income and cash flows if market prices are not consistent with management’s estimates of current market consensus for forward prices in the current period. This is particularly true for longer term contracts. Cash flows may vary based on market conditions, margin requirements and the timing of settlement of risk management contracts.

According to the accounting guidance for “Derivatives and Hedging,” OPCo reflects the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, OPCo is required to post or receive cash collateral based on third-party contractual agreements and risk profiles. The netted cash collateral from third-parties against short-term and long-term risk management assets and netted cash collateral paid to third-parties against short-term and long-term risk management liabilities were immaterial as of December 31, 2022 and 2021.

The following tables represent the gross fair value of OPCo’s derivative activity on the balance sheets:


	December 31, 2022
	Risk Management	Gross Amounts Offset	Net Amounts of Assets/Liabilities
	Contracts -	in the Statement of	Presented in the Statement of
Balance Sheet Location	Commodity (a)	Financial Position (b)	Financial Position (c)
	(in millions)
Derivative Instrument Assets	$ —	$ —	$ —
Long-Term Portion of Derivative Instrument Assets	—	—	—

Derivative Instrument Liabilities	40.0	(0.3)	39.7
Long-Term Portion of Derivative Instrument Liabilities	37.9	—	37.9


	December 31, 2021
	Risk Management	Gross Amounts Offset	Net Amounts of Assets/Liabilities
	Contracts -	in the Statement of	Presented in the Statement of
Balance Sheet Location	Commodity (a)	Financial Position (b)	Financial Position (c)
	(in millions)
Derivative Instrument Assets	$ 0.5	$ (0.5)	$ —
Long-Term Portion of Derivative Instrument Assets	—	—	—

Derivative Instrument Liabilities	92.6	—	92.6
Long-Term Portion of Derivative Instrument Liabilities	85.8	—	85.8

(a)Derivative instruments within these categories are disclosed as gross. These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.”

(b)Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.”

(c)All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position.

The table below presents the activity of derivative risk management contracts:


Amount of Gain (Loss) Recognized on Risk Management Contracts

	Years Ended December 31,
Location of Gain (Loss)	2022		2021
	(in millions)
Operation Expenses	$	0.8	$	0.5
Maintenance Expenses	1.2		0.6
Other Regulatory Assets (a)	52.1		10.0
Other Regulatory Liabilities (a)	3.7		—
Total Gain (Loss) on Risk Management Contracts	$	57.8	$	11.1

(a)Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets.

Certain qualifying derivative instruments have been designated as normal purchase or normal sale contracts, as provided in the accounting guidance for “Derivatives and Hedging.” Derivative contracts that have been designated as normal purchases or normal sales under that accounting guidance are not subject to MTM accounting treatment and are recognized on the statements of income on an accrual basis.

The accounting for the changes in the fair value of a derivative instrument depends on whether it qualifies for and has been designated as part of a hedging relationship and further, on the type of hedging relationship. Depending on the exposure, management designates a hedging instrument as a fair value hedge or a cash flow hedge.

For contracts that have not been designated as part of a hedging relationship, the accounting for changes in fair value depends on whether the derivative instrument is held for trading purposes. Unrealized and realized gains

and losses on derivative instruments held for trading purposes are included in revenues on a net basis on the statements of income. Unrealized and realized gains and losses on derivative instruments not held for trading purposes are included in revenues or expenses on the statements of income depending on the relevant facts and circumstances. Certain derivatives that economically hedge future commodity risk are recorded in the same line item on the statements of income as that of the associated risk being hedged. However, unrealized and some realized gains and losses for both trading and non-trading derivative instruments are recorded as regulatory assets (for losses) or regulatory liabilities (for gains) in accordance with the accounting guidance for “Regulated Operations.”

Credit Risk

Management mitigates credit risk in wholesale marketing and trading activities by assessing the creditworthiness of potential counterparties before entering into transactions with them and continuing to evaluate their creditworthiness on an ongoing basis. Management uses credit agency ratings and current market-based qualitative and quantitative data as well as financial statements to assess the financial health of counterparties on an ongoing basis.

Master agreements are typically used to facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Collateral requirements in the form of cash, letters of credit and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. Some master agreements include margining, which requires a counterparty to post cash or letters of credit in the event exposure exceeds the established threshold. The threshold represents an unsecured credit limit which may be supported by a parental/affiliate guaranty, as determined in accordance with AEP’s credit policy. In addition, master agreements allow for termination and liquidation of all positions in the event of a default including a failure or inability to post collateral when required.

Credit-Risk-Related Contingent Features

Cross-Acceleration Triggers

Certain interest rate derivative contracts contain cross-acceleration provisions that, if triggered, would permit the counterparty to declare a default and require settlement of the outstanding payable. These cross-acceleration provisions could be triggered if there was a non-performance event by OPCo under any of their outstanding debt of at least $50 million and the lender on that debt has accelerated the entire repayment obligation. On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these cross-acceleration provisions in contracts. OPCo had no derivative contracts with cross-acceleration provisions outstanding as of December 31, 2022 and 2021.

9. FAIR VALUE MEASUREMENTS

Fair Value Measurements of Long-term Debt

The fair values of Long-term Debt are based on quoted market prices, without credit enhancements, for the same or similar issues and the current interest rates offered for instruments with similar maturities classified as Level 2 measurement inputs. These instruments are not marked-to-market. The estimates presented are not necessarily indicative of the amounts that could be realized in a current market exchange.

The book values and fair values of Long-term Debt are summarized in the following table:


December 31,
2022				2021
Book Value		Fair Value		Book Value		Fair Value
(in millions)
$	2,991.6	$	2,516.6	$	2,991.2	$	3,437.5

Fair Value Measurements of Financial Assets and Liabilities

For a discussion of fair value accounting and the classification of assets and liabilities within the fair value hierarchy, see the “Fair Value Measurements of Assets and Liabilities” section of Note 1.

The following tables set forth, by level within the fair value hierarchy, OPCo’s financial assets and liabilities that were accounted for at fair value on a recurring basis. As required by the accounting guidance for “Fair Value Measurements and Disclosures,” financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Management’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. There have not been any significant changes in management’s valuation techniques.


	December 31, 2022
	Level 1		Level 2		Level 3		Other		Total
Assets:	(in millions)

Derivative Instrument Assets
Risk Management Commodity Contracts (a) (b)	$	—	$	—	$	—	$	—	$	—

Liabilities:

Derivative Instrument Liabilities
Risk Management Commodity Contracts (a) (b)	$	—	$	—	$	40.0	$	(0.3)	$	39.7


	December 31, 2021
	Level 1		Level 2		Level 3		Other		Total
Assets:	(in millions)

Derivative Instrument Assets
Risk Management Commodity Contracts (a) (b)	$	—	$	0.5	$	—	$	(0.5)	$	—

Liabilities:

Derivative Instrument Liabilities
Risk Management Commodity Contracts (a) (b)	$	—	$	—	$	92.5	$	—	$	92.5

(a)Amounts in “Other” column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.”

(b)Substantially comprised of power contracts.

The following tables set forth a reconciliation of changes in the fair value of net trading derivatives classified as Level 3 in the fair value hierarchy:


	Derivative Instrument
Year Ended December 31, 2022	Assets (Liabilities)
	(in millions)
Balance as of December 31, 2021	$	(92.5)
Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b)	6.5
Settlements	0.3
Changes in Fair Value Allocated to Regulated Jurisdictions (c)	45.7
Balance as of December 31, 2022	$	(40.0)


	Derivative Instrument
Year Ended December 31, 2021	Assets (Liabilities)
	(in millions)
Balance as of December 31, 2020	$	(110.3)
Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b)	2.4
Settlements	6.3
Changes in Fair Value Allocated to Regulated Jurisdictions (c)	9.1
Balance as of December 31, 2021	$	(92.5)

(a)Included in revenues on the statements of income.

(b)Represents the change in fair value between the beginning of the reporting period and the settlement of the risk management commodity contract.

(c)Relates to the net gains (losses) of those contracts that are not reflected on the statements of income. These changes in fair value are recorded as regulatory liabilities for net gains and as regulatory assets for net losses or accounts payable.

The following tables quantify the significant unobservable inputs used in developing the fair value of Level 3 positions:

December 31, 2022

Significant

Input/Range

Fair Value

Valuation

Unobservable

Weighted

Assets

Liabilities

Technique

Input (a)

Low

High

Average (b)

(in millions)

Energy Contracts

—

40.0

Discounted Cash Flow

Forward Market Price

2.91

187.34

48.76

December 31, 2021

Significant

Input/Range

Fair Value

Valuation

Unobservable

Weighted

Assets

Liabilities

Technique

Input (a)

Low

High

Average (b)

(in millions)

Energy Contracts

—

92.5

Discounted Cash Flow

Forward Market Price

14.26

52.98

30.68

(a)Represents market prices in dollars per MWh.

(b)The weighted-average is the product of the forward market price of the underlying commodity and volume weighted by term.

The following table provides the measurement uncertainty of fair value measurements to increases (decreases) in significant unobservable inputs related to Energy Contracts, Natural Gas Contracts and FTRs as of December 31, 2022 and 2021:

Uncertainty of Fair Value Measurements

Significant Unobservable Input

Position

Change in Input

Impact on Fair Value

Measurement

Forward Market Price

Buy

Increase (Decrease)

Higher (Lower)

Forward Market Price

Sell

Increase (Decrease)

Lower (Higher)

10. INCOME TAXES

Income Tax Expense (Benefit)

The details of OPCo’s income taxes as reported are as follows:


	Years Ended December 31,
	2022		2021
	(in millions)
Charged (Credited) to Operating Expenses, Net:
Current	$	(24.5)	$	8.0
Deferred	77.7		31.3
Total	53.2		39.3

Charged (Credited) to Non-Operating Income, Net:
Current	(2.7)		(4.3)
Deferred	(6.3)		(0.6)
Total	(9.0)		(4.9)
Total Income Taxes	$	44.2	$	34.4

The following is a reconciliation for OPCo between the federal income taxes computed by multiplying pretax income by the federal statutory tax rate and the income taxes reported:


	Years Ended December 31,
	2022			2021
	(in millions)
Net Income	$	287.8		$	253.6
Equity Earnings of Unconsolidated Subsidiaries	(0.6)			—
Income Tax Expense	44.2			34.4
Pretax Income	$	331.4		$	288.0

Income Taxes on Pretax Income at Statutory Rate (21%)	$	69.6		$	60.5
Increase (Decrease) in Income Taxes Resulting from the Following Items:
Reversal of Origination Flow-Through	3.0			2.2
State and Local Income Taxes, Net	(1.6)			—
AFUDC	(2.9)			(2.3)
Tax Adjustments (a)	—			8.9
Tax Reform Excess ADIT Reversal	(27.5)			(32.6)
Federal Return to Provision	3.5			(1.2)
Other	0.1			(1.1)
Income Tax Expense	$	44.2		$	34.4

Effective Income Tax Rate	13.3		%	11.9		%

(a)2021 amount represents an out of period adjustment related to Deferred Income Taxes and Income Tax Expense (Benefit). Management concluded the misstatement and subsequent correction was not material to the 2021 or prior period financial statements.

Net Deferred Tax Liability

The following tables show elements of the net deferred tax liability and significant temporary differences for OPCo:


	December 31,
	2022		2021
	(in millions)
Deferred Tax Assets	$	218.8	$	204.4
Deferred Tax Liabilities	(1,319.9)		(1,205.3)
Net Deferred Tax Liabilities	$ (1,101.1)		$ (1,000.9)

Property Related Temporary Differences	$ (1,133.8)		$ (1,042.0)
Amounts Due to Customers for Future Income Taxes	112.6		117.7
Deferred State Income Taxes	(59.6)		(58.8)
Regulatory Assets	(57.6)		(39.8)
Operating Lease Liability	15.5		17.2
All Other, Net	21.8		4.8
Net Deferred Tax Liabilities	$	(1,101.1)	$	(1,000.9)

Tax Credit Carryforward

As of December 31, 2022, OPCO has federal tax credit carryforwards in the amount of $1 million. If these credits are not utilized, federal general business tax credits will expire in the years 2036 through 2041. OPCO anticipates future federal taxable income will be sufficient to realize the tax benefits of the federal tax credits before they expire unused.

Net Income Tax Operating Loss Carryforward

As of December 31, 2022, OPCO has Ohio Municipal net income tax operating loss carryforward of $190.1 million. As a result, OPCO recognized deferred state income tax benefits. Management anticipates future taxable income will be sufficient to realize the state net income tax operating loss tax benefits before the state carryforward expires.

Federal and State Income Tax Audit Status

The statute of limitations for the IRS to examine OPCo and other AEP subsidiaries originally filed federal return has expired for tax years 2016 and earlier. OPCo has agreed to extend the statute of limitations on the 2017 and 2018 tax returns to December 31, 2023, to allow time for the current IRS audit to be completed including a refund claim approval by the Congressional Joint Committee on Taxation. The statute of limitations for the 2019 return is set to naturally expire in 2023 as well.

The current IRS audit and associated refund claim evolved from a net operating loss carryback to 2015 that originated in the 2017 return. OPCo and other AEP subsidiaries have received and agreed to two IRS proposed adjustments on the 2017 tax return, which were immaterial. The exam is nearly complete, and OPCo and other AEP subsidiaries are currently working with the IRS to submit the refund claim to the Congressional Joint Committee on Taxation for resolution and final approval.

OPCo and AEP subsidiaries file income tax returns in various state and local jurisdictions. These taxing authorities routinely examine the tax returns, and OPCo and other AEP subsidiaries are currently under examination in several state and local jurisdictions. Generally, the statutes of limitations have expired for tax

years prior to 2017. In addition, management is monitoring and continues to evaluate the potential impact of federal legislation and corresponding state conformity.

Uncertain Tax Positions

The reconciliations of the beginning and ending amounts of unrecognized tax benefits is as follows:


	OPCo
	2022		2021
	(in millions)
Balance as of January 1,	$	—	$	3.3
Increase – Tax Positions Taken During a Prior Period	5.1		—
Decrease – Tax Positions Taken During a Prior Period	—		(3.3)
Increase – Tax Positions Taken During the Current Year	—		—
Decrease – Tax Positions Taken During the Current Year	—		—
Decrease – Settlements with Taxing Authorities	—		—
Decrease – Lapse of the Applicable Statute of Limitations	—		—
Balance as of December 31,	$	5.1	$	—

The total amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate is $4 million and $0 for 2022 and 2021 respectively. Management believes that there will be no significant net increase or decrease in unrecognized benefits within 12 months of the reporting date.

Federal Tax Legislation

Inflation Reduction Act

In August 2022, President Biden signed H.R. 5376 into law, commonly known as the Inflation Reduction Act of 2022 or IRA. Most notably this budget reconciliation legislation creates a 15% minimum tax on adjusted financial statement income (Corporate Alternative Minimum Tax or CAMT), extends and increases the value of PTCs and ITCs, adds a nuclear and clean hydrogen PTC, an energy storage ITC and allows the sale or transfer of tax credits to third parties for cash. This legislation has no material impact on the current period financial statements. As further significant guidance from Treasury and the IRS is expected on the tax provisions in the IRA, OPCo will continue to monitor any issued guidance and evaluate the impact on future net income, cash flows and financial condition.

In November 2022, the IRS released Notice 2022-61 addressing the Prevailing Wage and Apprenticeship Requirements (PWAR) tied to full value PTCs and ITCs for projects that begin construction on or after January 29, 2023. OPCo’s future renewable energy projects that begin construction after this date will be required to, and expect to, satisfy the PWAR to receive full value ITCs and PTCs.

In December 2022, the IRS released Notice 2023-7 addressing time sensitive issues related to the CAMT. The notice provided initial guidance that OPCo can begin to rely on in 2023 and also stated that additional guidance is expected, of which OPCo will continue to monitor and assess. Notably, the interim guidance in Notice 2023-7 confirmed the CAMT depreciation adjustment includes tax depreciation that is capitalized to inventory under §263A and recovered as part of cost of goods sold, providing significant relief to OPCo’s potential CAMT exposure.

The enactment of the IRA will have future cash flow and income tax reporting considerations. OPCo and other AEP subsidiaries expect to be applicable corporations beginning in 2023 and expect to have CAMT cash tax payments beginning in 2024. CAMT cash taxes are expected to be offset by regulatory recovery, the utilization of tax credits and additionally the cash inflow generated by the sale of tax credits. The sale of tax credits will be presented in the operating section of the statements of cash flows consistent with the presentation of cash taxes paid. OPCo will present the gain or loss on sale of tax credits through income tax expense. Management believes this presentation provides consistency in financial statement reporting as it matches the originating income tax benefit of the tax credits.

State Tax Legislation

In April 2021, West Virginia enacted House Bill (HB) 2026. HB 2026 changes the state income tax apportionment formula from a ratio that includes property, payroll and sales to a single sales factor apportionment regime effective for tax years beginning on or after January 1, 2022. HB 2026 also eliminates the “throw out” rule related to sales of tangible personal property for sales factor apportionment calculation purposes and introduces a market-based sourcing for sales of services and intangible property.

11. LEASES

OPCo leases property, plant and equipment including, but not limited to, fleet, information technology and real estate leases. These leases require payments of non-lease components, including related property taxes, operating and maintenance costs. OPCo does not separate non-lease components from associated lease components. Many of these leases have purchase or renewal options. Leases not renewed are often replaced by other leases. Options to renew or purchase a lease are included in the measurement of lease assets and liabilities if it is reasonably certain OPCo will exercise the option.

Lease obligations are measured using the discount rate implicit in the lease when that rate is readily determinable. AEP has visibility into the rate implicit in the lease when assets are leased from selected financial institutions under master leasing agreements. When the implicit rate is not readily determinable, OPCo measures its lease obligation using its estimated secured incremental borrowing rate. Incremental borrowing rates are comprised of an underlying risk-free rate and a secured credit spread relative to the lessee on a matched maturity basis.

Operating and Finance lease rental costs are generally charged to Operation Expense and Maintenance Expense in accordance with rate-making treatment for regulated operations. Lease costs associated with capital projects are included in Utility Plant on the balance sheets. For regulated operations with finance leases, a finance lease asset and offsetting liability are recorded at the present value of the remaining lease payments for each reporting period.

The components of rental costs were as follows:


	Years Ended December 31,
	2022		2021
	(in millions)
Operating Lease Cost	$	16.9	$	19.0
Finance Lease Cost:
Amortization of Right-of-Use Assets	4.9		4.9
Interest on Lease Liabilities	0.8		0.8
Total Lease Rental Costs (a)	$	22.6	$	24.7

a.Excludes variable and short-term lease costs, which were immaterial.

Supplemental information related to leases are shown in the tables below:


	December 31,
	2022		2021
	(in millions)
Weighted-Average Remaining Lease Term (years):
Operating Leases	5.98		6.69
Finance Leases	5.27		5.54
Weighted-Average Discount Rate:
Operating Leases	3.73	%	3.56	%
Finance Leases	4.53	%	4.19	%


	Years Ended December 31,
	2022		2021
	(in millions)
Cash paid for amounts included in the measurement of lease liabilities:
Operating Cash Flows from Operating Leases	$	17.5	$	19.0
Operating Cash Flows from Finance Leases	5.7		5.7

Non-cash Acquisitions Under Operating Leases	$	8.4	$	4.2

The following tables show property, plant and equipment under finance leases, operating leases and related obligations recorded on OPCo’s balance sheets:


	December 31,
	2022		2021
	(in millions)
Property, Plant and Equipment Under Finance Leases:
Utility Plant (a)	$	18.9	$	19.3
Net Property, Plant and Equipment Under Finance Leases	$	18.9	$	19.3

Obligations Under Finance Leases:
Noncurrent	$	14.3	$	14.9
Current	4.6		4.4
Total Obligations Under Finance Leases	$	18.9	$	19.3

(a) Includes $14 million and $13 million of accumulated provision for depreciation and amortization for the years ended December 31, 2022 and 2021, respectively.


	December 31,
	2022		2021
	(in millions)
Property, Plant and Equipment Under Operating Leases:
Utility Plant (a)	$	66.0	$	71.9
Nonutility Plant	12.4		12.4
Accumulated Provision for Depreciation and Amortization - Nonutility Plant	(4.4)		(3.2)
Net Property, Plant and Equipment Under Operating Lease	$	74.0	$	81.1

Obligations Under Operating Leases:
Noncurrent	$	60.3	$	68.6
Current	13.5		13.1
Total Obligations Under Operating Leases	$	73.8	$	81.7

(a) Includes $38 million and $28 million of accumulated provision for depreciation and amortization for the years ended December 31, 2022 and 2021, respectively.

Future minimum lease payments consisted of the following as of December 31, 2022:


	Finance Leases		Operating Leases
	(in millions)
2023	$	5.4	$	16.4
2024	4.6		14.9
2025	3.2		13.2
2026	2.6		12.0
2027	2.1		10.7
After 2027	3.4		15.7
Total Future Minimum Lease Payments	21.3		82.9
Less: Imputed Interest	2.4		9.1
Estimated Present Value of Future Minimum Lease Payments	$	18.9	$	73.8

Master Lease Agreements

OPCo leases certain equipment under master lease agreements. Under the lease agreements, the lessor is guaranteed a residual value up to a stated percentage of the equipment cost at the end of the lease term. If the actual fair value of the leased equipment is below the guaranteed residual value at the end of the lease term, OPCo is committed to pay the difference between the actual fair value and the residual value guarantee. Historically, at the end of the lease term the fair value has been in excess of the amount guaranteed. As of December 31, 2022, the maximum potential loss by OPCo for these lease agreements assuming the fair value of the equipment is zero at the end of the lease term was $8 million.

Lessor Activity

OPCo’s lessor activity was immaterial as of and for the twelve months ended December 31, 2022 and December 31, 2021, respectively.

12. FINANCING ACTIVITIES

Long-term Debt

The following table details long-term debt outstanding:


		Weighted-Average	Interest Rate Ranges as of		Outstanding as of
		Interest Rate as of	December 31,		December 31,
	Maturity	December 31, 2022	2022	2021	2022		2021


Senior Unsecured Notes	2030-2051	3.87%	1.63%-6.60%	1.63%-6.60%	$	3,000.0	$	3,000.0
Other Long-term Debt	2028	1.15%	1.15%	1.15%	0.6		0.7
Unamortized Discount, Net					(9.0)		(9.5)
Total Long-term Debt Outstanding					$	2,991.6	$	2,991.2

As of December 31, 2022, outstanding long-term debt was payable as follows:


	(in millions)
2023	$	0.1
2024	0.1
2025	0.1
2026	0.1
2027	0.1
After 2027	3,000.1
Principal Amount	3,000.6
Unamortized Discount, Net	(9.0)
Total Long-term Debt	$	2,991.6

Dividend Restrictions

OPCo pays dividends to Parent provided funds are legally available. Various financing arrangements and regulatory requirements may impose certain restrictions on the ability of OPCo to transfer funds to Parent in the form of dividends.

All of the dividends declared by OPCo are subject to a Federal Power Act requirement that prohibits the payment of dividends out of capital accounts in certain circumstances; payment of dividends is generally allowed out of retained earnings.

The most restrictive dividend limitation for OPCo is through the Federal Power Act restriction. As of December 31, 2021, the maximum amount of restricted net assets of OPCo that may not be distributed to the Parent in the form of a loan, advance or dividend was $1.2 billion.

Corporate Borrowing Program – AEP System

The AEP System uses a corporate borrowing program to meet the short-term borrowing needs of AEP’s subsidiaries. The corporate borrowing program includes a Utility Money Pool, which funds AEP’s utility subsidiaries. The AEP System Utility Money Pool operates in accordance with the terms and conditions of its agreement filed with the FERC. The amounts of outstanding loans to (borrowings from) the Utility Money Pool as of December 31, 2022 and 2021 are included in Notes Receivable from Associated Companies and Notes Payable to Associated Companies, respectively, on the balance sheets. OPCo’s money pool activity and corresponding authorized borrowing limits are described in the following table:


	Maximum				Average				Net Loans to
	Borrowings		Maximum		Borrowings		Average		(Borrowings from)		Authorized
	from the		Loans to the		from the		Loans to the		the Utility Money		Short-term
Years ended	Utility		Utility		Utility		Utility		Pool as of		Borrowing
December 31,	Money Pool		Money Pool		Money Pool		Money Pool		December 31,		Limit
	(in millions)
2022	$	262.5	$	246.1	$	101.3	$	86.9	$	(172.9)	$	500.0
2021	259.2		622.9		61.6		127.2		42.0		500.0

The maximum, minimum and average interest rates for funds either borrowed from or loaned to the Utility Money Pool are summarized in the following table:


	Maximum		Minimum		Maximum		Minimum		Average		Average
	Interest Rates		Interest Rates		Interest Rates		Interest Rates		Interest Rates		Interest Rates
	for Funds		for Funds		for Funds		for Funds		for Funds		for Funds
	Borrowed from		Borrowed from		Loaned to		Loaned to		Borrowed from		Loaned to
Years ended	the Utility		the Utility		the Utility		the Utility		the Utility		the Utility
December 31,	Money Pool		Money Pool		Money Pool		Money Pool		Money Pool		Money Pool
	(in millions)
2022	5.28	%	0.10	%	2.30	%	0.46	%	3.51	%	1.22	%
2021	0.48	%	0.03	%	0.48	%	0.02	%	0.27	%	0.14	%

Interest expense and interest income related to the Utility Money Pool financing relationship are included in Interest on Debt to Associated Companies and Interest and Dividend Income, respectively, on the statements of income. The interest expense and interest income related to the corporate borrowing programs were immaterial for the years ended December 31, 2022 and 2021.

Securitized Accounts Receivables – AEP Credit

Under this sale of receivables arrangement, OPCo sells, without recourse, certain of its customer accounts receivable and accrued utility revenue balances to AEP Credit and is charged a fee based on AEP Credit’s financing costs, administrative costs and uncollectible accounts experience for OPCo’s receivables. The costs of customer accounts receivable sold are reported in Other Deductions on OPCo’s statements of income. OPCo manages and services its customer accounts receivable, which are sold to AEP Credit. AEP Credit securitizes the eligible receivables for OPCo and retains the remainder.

The amount of accounts receivable and accrued utility revenues under the sale of receivables agreement as of December 31, 2022 and 2021 were $479 million and $393 million, respectively.

The fees paid to AEP Credit for customer accounts receivable sold were $30 million and $8 million for the years ended December 31, 2022 and 2021, respectively. In 2021, due to the successful collection of accounts receivable balances during the COVID-19 pandemic, the allowance for doubtful accounts was reduced, resulting in the issuance of credits to offset the higher fees previously paid by OPCo and to lower subsequent fees paid.

The proceeds on the sale of receivables to AEP Credit were $3.1 billion and $2.5 billion for the years ended December 31, 2022 and 2021, respectively.

13. RELATED PARTY TRANSACTIONS

For other related party transactions, also see “AEP System Tax Allocation” section of Note 1 in addition to “Corporate Borrowing Program – AEP System” and “Securitized Accounts Receivables – AEP Credit” sections of Note 13.

Power Coordination Agreement

AEPSC conducts only gasoline, diesel fuel, energy procurement and risk management activities on OPCo’s behalf.

Affiliated Revenues and Purchases

The following table shows the revenues derived from direct sales to affiliates, auction sales to affiliates, net transmission agreement sales and other revenues for the years ended December 31, 2022 and 2021:


	Years Ended December 31,
Related Party Revenues	2022		2021
	(in millions)
Transmission Agreement and Transmission Coordination Agreement Sales	$	(3.6)	$	(1.1)
Other Revenues	22.4		25.9

The following table shows the purchased power expenses incurred for purchases from affiliates for the years December 31, 2022 and 2021:


	Years Ended December 31,
Related Party Purchases	2022		2021
	(in millions)
Auction Purchases from AEPEP (a)	$	9.8	$	26.6
Auction Purchases from AEP Energy (a)	—		25.3

(a) Refer to the Ohio Auctions section below for further information regarding these amounts.

PJM Service Charges

The AEP East Companies are parties to the TA, which defines how transmission costs through the PJM OATT are allocated among the AEP East Companies on a 12-month average coincident peak basis. Additional costs for transmission services provided by AEPTCo and other transmission affiliates are billed to AEP East Companies through the PJM OATT. OPCo’s net charges for the years ended December 31, 2022 and 2021 related to the TA were $608 million and $509 million, respectively. The charges were recorded in Operation Expenses on the statements of income.

Joint License Agreement

AEPTCo entered into a 50-year joint license agreement with OPCo allowing either party to occupy the granting party’s facilities or real property. After the expiration of the agreement, the term shall automatically renew for successive one-year terms unless either party provides notice. The joint license billing provides compensation to the granting party for the cost of carrying assets, including depreciation expense, property taxes, interest expense, return on equity and income taxes. For the years ended December 31, 2022 and 2021, OPCo billed AEPTCo $5 million and $5 million, respectively.

OVEC

AEP and several nonaffiliated utility companies jointly own OVEC. As of December 31, 2022, the ownership and investment in OVEC were as follows:


	December 31, 2022
Company	Ownership		Investment
			(in millions)
Parent	39.17	%	$	4.0
OPCo	4.30	%	0.4
Total	43.47	%	4.4

OVEC’s owners, along with APCo and I&M, are members to an intercompany power agreement. Participants of this agreement are entitled to receive and obligated to pay for all OVEC generating capacity, approximately 2,400 MWs, in proportion to their respective power participation ratios. The aggregate power participation ratio of certain AEP utility subsidiaries, including APCo, I&M and OPCo, is 43.47%. The proceeds from the sale of power by OVEC are designed to be sufficient for OVEC to meet its operating expenses and fixed costs, including outstanding indebtedness, and provide a return on capital. The intercompany power agreement ends in June 2040.

AEP and other nonaffiliated owners authorized environmental investments related to their ownership interests. OVEC financed capital expenditures in connection with the engineering and construction of FGD projects and the associated waste disposal landfills at its two generation plants. These environmental projects were funded through debt issuances. As of December 31, 2022 and 2021, OVEC’s outstanding indebtedness was approximately $1.1 billion and $1.1 billion, respectively. Although they are not an obligor or guarantor, AEP utility subsidiaries are responsible for their respective ratio of OVEC’s outstanding debt through the intercompany power agreement. Principal and interest payments related to OVEC’s outstanding indebtedness are disclosed in accordance with the accounting guidance for “Commitments.” See the “Commitments” section of Note 5 for additional information.

Purchased Power from OVEC

OPCo paid $152 million and $133 million for power purchased from OVEC for the years ended December 31, 2022 and 2021, respectively. The amounts shown above are recoverable from customers and are included in Operating Revenues and Operation Expenses on the statement of income.

Ohio Auctions

In connection with OPCo’s June 2012 - May 2015 ESP, the PUCO ordered OPCo to conduct energy and capacity auctions for its entire SSO load for delivery beginning in June 2015. AEP Energy, AEPEP, APCo, KPCo, I&M and WPCo participate in the auction process and have been awarded tranches of OPCo’s SSO load. Refer to the Affiliated Revenues and Purchases section above for amounts related to these transactions.

Sales and Purchases of Property

OPCo had affiliated sales and purchases of electric property amounting to $100 thousand or more, sales and purchases of meters and transformers, and sales and purchases of transmission property. There were no gains or

losses recorded on the transactions. The following table shows the sales and purchases, recorded at net book value:


	Years Ended December 31,
	2022	2021
	(in millions)
Sales	$ 7.6	$ 9.2
Purchases	2.0	1.4

The amounts above are recorded in Utility Plant on the balance sheets.

AEP Wind Holdings LLC PPAs

Prior to its acquisition, two of the 50% owned joint venture wind farms in the AEP Wind Holdings, LLC portfolio had existing PPAs with OPCo. Fowler Ridge 2 has PPAs with OPCo for a portion of its energy production. The OPCo portion totaled $24 million and $20 million, respectively, for the years ended December 31, 2022 and 2021, respectively.

Intercompany Billings

OPCo performs certain utility services for each other when necessary or practical. The costs of these services are billed on a direct-charge basis, whenever possible, or on reasonable basis of proration for services that benefit multiple companies. The billings for services are made at cost and include no compensation for the use of equity capital.

AEPSC

AEPSC provides certain managerial and professional services to OPCo. The costs of the services are based on a direct charge or on a prorated basis and billed to OPCo at AEPSC’s cost. AEPSC and its billings are subject to regulation by the FERC. OPCo’s total billings from AEPSC were $273 million and $235 million for the years ended December 31, 2022 and 2021, respectively.

Charitable Contributions to AEP Foundation

The American Electric Power Foundation is funded by American Electric Power and its utility operating units. The Foundation provides a permanent, ongoing resource for charitable initiatives and multi-year commitments in the communities served by AEP and initiatives outside of AEP’s 11-state service area. In 2022, OPCo made an $8 million charitable contribution to the AEP Foundation recorded in Donations on the statements of income. In 2021, there were no charitable contributions made to the AEP Foundation..

14. PROPERTY, PLANT AND EQUIPMENT

Depreciation

OPCo provides for depreciation of Utility Plant, on a straight-line basis over the estimated useful lives of property, generally using composite rates by functional class. The following table provides total regulated annual composite depreciation rates by functional class:


Year		Transmission	Distribution	General
	(in percentages)
2022		2.3	2.7	6.1
2021		2.3	2.9	6.1

The composite depreciation rate generally includes a component for non-ARO removal costs, which is credited to accumulated depreciation on the balance sheets. Actual removal costs incurred are charged to accumulated depreciation.

Asset Retirement Obligations

The following is a reconciliation of the 2022 and 2021 aggregate carrying amounts of ARO:


Year	ARO at January 1,		Accretion Expense		Liabilities Incurred		Liabilities Settled		ARO at December 31,
	(in millions)
2022	$	1.9	$	0.2	$	3.0	$	(0.1)	$	5.0
2021	1.9		0.1		—		(0.1)		1.9

15. REVENUE FROM CONTRACTS WITH CUSTOMERS

Disaggregated Revenues from Contracts with Customers

The table below represents revenues from contracts with customers, net of respective provisions for refund, by type of revenue:


	Years Ended December 31,
	2022		2021
	(in millions)
Retail Revenues:
Residential Revenues	$	1,830.2	$	1,587.9
Commercial Revenues	947.7		722.7
Industrial Revenues (a)	571.7		286.3
Other Retail Revenues	13.9		12.6
Total Retail Revenues	3,363.5		2,609.5

Wholesale Revenues:
Transmission Revenues	86.2		74.9
Total Wholesale Revenues	86.2		74.9

Other Revenues from Contracts with Customers (a)	218.1		148.3

Total Revenues from Contracts with Customers	3,667.8		2,832.7

Other Revenues:
Alternative Revenues	(25.6)		42.6
Other Revenues (a)	35.9		27.1
Total Other Revenues	10.3		69.7

Total Operating Revenues	$	3,678.1	$	2,902.4

(a)Amounts include affiliated and nonaffiliated revenues.

Performance Obligations

OPCo has performance obligations as part of its normal course of business. A performance obligation is a promise to transfer a distinct good or service, or a series of distinct goods or services that are substantially the same and have the same pattern of transfer to a customer. The invoice practical expedient within the accounting guidance for “Revenue from Contracts with Customers” allows for the recognition of revenue from performance obligations in the amount of consideration to which there is a right to invoice the customer and when the amount for which there is a right to invoice corresponds directly to the value transferred to the customer.

The purpose of the invoice practical expedient is to depict an entity’s measure of progress toward completion of the performance obligation within a contract and can only be applied to performance obligations that are satisfied over time and when the invoice is representative of services provided to date. OPCo elected to apply the invoice practical expedient to recognize revenue for performance obligations satisfied over time as the invoices from the respective revenue streams are representative of services or goods provided to date to the customer. Performance obligations for OPCo are summarized as follows:

Retail Revenues

OPCo has performance obligations to transmit and distribute electricity for sale to rate-regulated retail customers. The performance obligation to deliver electricity is satisfied over time as the customer simultaneously receives and consumes the benefits provided. Revenues are variable as they are subject to the customer’s usage requirements.

Rate-regulated retail customers typically have the right to discontinue receiving service at will, therefore these contracts between OPCo and their customers for rate-regulated services are generally limited to the services requested and received to date for such arrangements. Retail customers are generally billed on a monthly basis, and payment is typically due within 15 to 20 days after the issuance of the invoice

Wholesale Revenues - Transmission

OPCo has performance obligations to transmit electricity to wholesale customers through assets owned and operated. The performance obligation to provide transmission services in PJM is partially fixed for a period of one year or less. Payments from PJM for transmission services are typically received within one week from the issuance of the invoice, which is issued weekly for PJM.

OPCo within the PJM region collects revenues through transmission formula rates. The FERC-approved rates establish the annual transmission revenue requirement (ATRR) and transmission service rates for transmission owners. The formula rates establish rates for a one year period and also include a true-up calculation for the prior year’s billings, allowing for over/under-recovery of the transmission owner’s ATRR. The annual true-ups meet the definition of alternative revenues in accordance with the accounting guidance for “Regulated Operations,” and are therefore presented as such in the disaggregated revenues tables above.

The AEP East Companies are parties to the TA, which defines how transmission costs are allocated among the AEP East Companies on a 12-month average coincident peak basis Affiliate revenues as a result of the respective TA are reflected as Transmission Revenues in the disaggregated revenues tables above.

Contract Assets and Liabilities

Contract assets are recognized when OPCo has a right to consideration that is conditional upon the occurrence of an event other than the passage of time, such as future performance under a contract. OPCo did not have any material contract assets as of December 31, 2022 and 2021.

When OPCo receives consideration, or such consideration is unconditionally due from a customer prior to transferring goods or services to the customer under the terms of a sales contract, they recognize a contract liability on the balance sheets in the amount of that consideration. Revenue for such consideration is subsequently recognized in the period or periods in which the remaining performance obligations in the contract are satisfied. OPCo’s contract liabilities typically arise from services provided under joint use agreements for utility poles. OPCo did not have any material contract liabilities as of December 31, 2022 and 2021.

Accounts Receivable from Contracts with Customers

Accounts receivable from contracts with customers are presented on OPCo’s balance sheets within the Customer Accounts Receivable line item. OPCo’s balances for receivables from contracts that are not recognized in accordance with the accounting guidance for “Revenue from Contracts with Customers” included in Customer Accounts Receivable were not material as of December 31, 2022 and 2021. See “Securitized Accounts Receivable - AEP Credit” section of Note 13 for additional information.

The amount of affiliated accounts receivable from contracts with customers included in Accounts Receivable from Associated Companies on OPCo’s balance sheets were $50 million and $52 million, as of December 31, 2022 and 2021.

Contract Costs

Contract costs to obtain or fulfill a contract for OPCo are accounted for under the guidance for “Other Assets and Deferred Costs” and presented as a single asset and are neither bifurcated nor reclassified between current assets and deferred debits on the balance sheets. Contract costs to acquire a contract are amortized in a manner consistent with the transfer of goods or services to the customer in Operation Expenses on the income statements. OPCo did not have material contract costs as of December 31, 2022 and 2021.

16. FERC ORDER No. 784-A

On July 18, 2013, the FERC issued Order No. 784 that revised certain aspects of the accounting and reporting requirements under the Uniform System of Accounts related to energy storage accounts. Due to software limitations, the newly adopted and revised schedules in the FERC Forms that would contain the energy storage accounts are not available to filers of the forms for use as of the effective date. Utilities with energy storage assets must use the existing schedules in the FERC Forms to report energy storage assets pending availability of the new and revised schedules. FERC directed filers to submit the requested energy storage information as part of pages 122-123.

The following table presents OPCo’s energy storage operations for small plants for the years ended December 31, 2022 and 2021, as required by FERC Order No. 784:


						Operation			Maintenance
Project	Functional	Project	Project Costs			Expenses			Expenses
Name	Classification	Location	Account	Amount		Account	Amount		Account	Amount (a)
			(dollars in millions)
Year Ended December 31, 2022
Citizens Station	Distribution	Bluffton, OH	363	$	5.1		$	—		$	—
Reno Station	Distribution	Marietta, OH	363	$	—		$	—		$	—

Year Ended December 31, 2021
Citizens Station	Distribution	Bluffton, OH	363	$	5.1		$	—		$	—

a.This amount would have been recorded in Account 592.2 in accordance with FERC Order No. 784.

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote. Report data on a year-to-date basis.
Line No.	Item (a)	Unrealized Gains and Losses on Available-For-Sale Securities (b)	Minimum Pension Liability Adjustment (net amount) (c)	Foreign Currency Hedges (d)	Other Adjustments (e)	Other Cash Flow Hedges Interest Rate Swaps (f)	Other Cash Flow Hedges [Specify] (g)	Totals for each category of items recorded in Account 219 (h)	Net Income (Carried Forward from Page 116, Line 78) (i)	Total Comprehensive Income (j)
1	Balance of Account 219 at Beginning of Preceding Year			30,183				30,183
2	Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income			10,653				10,653
3	Preceding Quarter/Year to Date Changes in Fair Value
4	Total (lines 2 and 3)			10,653				10,653	253,646,877	253,636,224
5	Balance of Account 219 at End of Preceding Quarter/Year			19,530				19,530
6	Balance of Account 219 at Beginning of Current Year			19,530				19,530
7	Current Quarter/Year to Date Reclassifications from Account 219 to Net Income			10,652				10,652
8	Current Quarter/Year to Date Changes in Fair Value
9	Total (lines 7 and 8)			10,652				10,652	287,797,165	287,786,513
10	Balance of Account 219 at End of Current Quarter/Year			8,878				8,878

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION
Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.
Line No.	Classification (a)	Total Company For the Current Year/Quarter Ended (b)	Electric (c)	Gas (d)	Other (Specify) (e)	Other (Specify) (f)	Other (Specify) (g)	Common (h)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlantInServiceAbstract In Service
3	UtilityPlantInServiceClassified Plant in Service (Classified)	9,978,181,757	9,978,181,757
4	UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases	84,597,564	84,597,564
5	UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold
6	UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified	679,236,759.00	679,236,759.00
7	UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified
8	UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7)	10,742,016,080	10,742,016,080
9	UtilityPlantLeasedToOthers Leased to Others
10	UtilityPlantHeldForFutureUse Held for Future Use	5,074,377	5,074,377
11	ConstructionWorkInProgress Construction Work in Progress	483,318,237	483,318,237
12	UtilityPlantAcquisitionAdjustment Acquisition Adjustments	636,578.00	636,578.00
13	UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12)	11,231,045,272	11,231,045,272
14	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion	3,019,297,768	3,019,297,768
15	UtilityPlantNet Net Utility Plant (13 less 14)	8,211,747,504	8,211,747,504
16	DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17	AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service:
18	DepreciationUtilityPlantInService Depreciation	2,881,454,265	2,881,454,265
19	AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService Amortization and Depletion of Producing Natural Gas Land and Land Rights
20	AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService Amortization of Underground Storage Land and Land Rights
21	AmortizationOfOtherUtilityPlantUtilityPlantInService Amortization of Other Utility Plant	137,190,258	137,190,258
22	DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21)	3,018,644,523	3,018,644,523
23	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract Leased to Others
24	DepreciationUtilityPlantLeasedToOthers Depreciation
25	AmortizationAndDepletionUtilityPlantLeasedToOthers Amortization and Depletion
26	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers Total Leased to Others (24 & 25)
27	DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract Held for Future Use
28	DepreciationUtilityPlantHeldForFutureUse Depreciation	16,667	16,667
29	AmortizationUtilityPlantHeldForFutureUse Amortization
30	DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29)	16,667	16,667
31	AbandonmentOfLeases Abandonment of Leases (Natural Gas)
32	AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment	636,578.00	636,578.00
33	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32)	3,019,297,768	3,019,297,768

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No.	Description of item (a)	Balance Beginning of Year (b)	Changes during Year Additions (c)	Changes during Year Amortization (d)	Changes during Year Other Reductions (Explain in a footnote) (e)	Balance End of Year (f)
1	Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1)
2	Fabrication
3	Nuclear Materials
4	Allowance for Funds Used during Construction
5	(Other Overhead Construction Costs, provide details in footnote)
6	SUBTOTAL (Total 2 thru 5)
7	Nuclear Fuel Materials and Assemblies
8	In Stock (120.2)
9	In Reactor (120.3)
10	SUBTOTAL (Total 8 & 9)
11	Spent Nuclear Fuel (120.4)
12	Nuclear Fuel Under Capital Leases (120.6)
13	(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)
14	TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)
15	Estimated Net Salvage Value of Nuclear Materials in Line 9
16	Estimated Net Salvage Value of Nuclear Materials in Line 11
17	Est Net Salvage Value of Nuclear Materials in Chemical Processing
18	Nuclear Materials held for Sale (157)
19	Uranium
20	Plutonium
21	Other (Provide details in footnote)
22	TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21)

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
Report below the original cost of electric plant in service according to the prescribed accounts. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of the prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No.	Account (a)	Balance Beginning of Year (b)	Additions (c)	Retirements (d)	Adjustments (e)	Transfers (f)	Balance at End of Year (g)
1	1. INTANGIBLE PLANT
2	(301) Organization	4,744					4,744
3	(302) Franchise and Consents	4,700					4,700
4	(303) Miscellaneous Intangible Plant	243,411,426	53,322,917	28,107,070			268,627,273
5	TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)	243,420,870	53,322,917	28,107,070			268,636,717
6	2. PRODUCTION PLANT
7	A. Steam Production Plant
8	(310) Land and Land Rights
9	(311) Structures and Improvements
10	(312) Boiler Plant Equipment
11	(313) Engines and Engine-Driven Generators
12	(314) Turbogenerator Units
13	(315) Accessory Electric Equipment
14	(316) Misc. Power Plant Equipment
15	(317) Asset Retirement Costs for Steam Production
16	TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)
17	B. Nuclear Production Plant
18	(320) Land and Land Rights
19	(321) Structures and Improvements
20	(322) Reactor Plant Equipment
21	(323) Turbogenerator Units
22	(324) Accessory Electric Equipment
23	(325) Misc. Power Plant Equipment
24	(326) Asset Retirement Costs for Nuclear Production
25	TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)
26	C. Hydraulic Production Plant
27	(330) Land and Land Rights
28	(331) Structures and Improvements
29	(332) Reservoirs, Dams, and Waterways
30	(333) Water Wheels, Turbines, and Generators
31	(334) Accessory Electric Equipment
32	(335) Misc. Power Plant Equipment
33	(336) Roads, Railroads, and Bridges
34	(337) Asset Retirement Costs for Hydraulic Production
35	TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)
36	D. Other Production Plant
37	(340) Land and Land Rights
38	(341) Structures and Improvements
39	(342) Fuel Holders, Products, and Accessories
40	(343) Prime Movers
41	(344) Generators
42	(345) Accessory Electric Equipment
43	(346) Misc. Power Plant Equipment
44	(347) Asset Retirement Costs for Other Production
44.1	(348) Energy Storage Equipment - Production
45	TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)
46	TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)
47	3. Transmission Plant
48	(350) Land and Land Rights	126,494,931	3,304,527	186,646		207,869	129,404,943
48.1	(351) Energy Storage Equipment - Transmission
49	(352) Structures and Improvements	122,559,948	43,701,173	6,641,756		2,364,834	157,254,531
50	(353) Station Equipment	1,523,657,515	54,831,335	9,467,947			1,569,020,903
51	(354) Towers and Fixtures	195,388,929	1,020,161	718,442			195,690,648
52	(355) Poles and Fixtures	472,428,060	59,007,625	4,018,249			527,417,436
53	(356) Overhead Conductors and Devices	499,172,475	26,011,968	3,540,855			521,643,588
54	(357) Underground Conduit	15,736,476	27,959,581				43,696,057
55	(358) Underground Conductors and Devices	34,802,338	17,368,220	165,784			52,004,774
56	(359) Roads and Trails
57	(359.1) Asset Retirement Costs for Transmission Plant	3,120					3,120
58	TOTAL Transmission Plant (Enter Total of lines 48 thru 57)	2,990,243,792	233,204,590	24,739,679		2,572,703	3,196,136,000
59	4. Distribution Plant
60	(360) Land and Land Rights	85,029,283	1,953,718	558,184			86,424,817
61	(361) Structures and Improvements	56,031,590	11,746,935	409,051			67,369,474
62	(362) Station Equipment	1,036,305,171	55,634,858	9,602,811			1,082,337,218
63	(363) Energy Storage Equipment – Distribution	5,117,366	45,255				5,162,621
64	(364) Poles, Towers, and Fixtures	900,061,600	78,611,123	14,184,886		60	964,487,897
65	(365) Overhead Conductors and Devices	1,104,685,950	101,455,429	21,191,764		1,539	1,184,948,076
66	(366) Underground Conduit	426,705,846	60,162,403	211,617		1,129	486,657,761
67	(367) Underground Conductors and Devices	798,198,789	43,776,522	6,433,430		305	835,542,186
68	(368) Line Transformers	913,988,500	50,297,285	15,450,569		44	948,835,260
69	(369) Services	366,720,593	19,794,848	2,552,137			383,963,304
70	(370) Meters	271,540,584	6,911,196	3,358,671			275,093,109
71	(371) Installations on Customer Premises	60,104,028	9,089,257	1,575,037			67,618,248
72	(372) Leased Property on Customer Premises	103,067					103,067
73	(373) Street Lighting and Signal Systems	43,714,594	13,290,680	778,830			56,226,444
74	(374) Asset Retirement Costs for Distribution Plant		2,991,770				2,991,770
75	TOTAL Distribution Plant (Enter Total of lines 60 thru 74)	6,068,306,961	455,761,279	76,306,987		1	6,447,761,252
76	5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77	(380) Land and Land Rights
78	(381) Structures and Improvements
79	(382) Computer Hardware
80	(383) Computer Software
81	(384) Communication Equipment
82	(385) Miscellaneous Regional Transmission and Market Operation Plant
83	(386) Asset Retirement Costs for Regional Transmission and Market Oper
84	TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85	6. General Plant
86	(389) Land and Land Rights	28,396,950		17,146		172,955	28,206,849
87	(390) Structures and Improvements	371,148,578	11,789,804	837,661		172,955	382,273,676
88	(391) Office Furniture and Equipment	25,299,177	792,550	61,784			26,029,943
89	(392) Transportation Equipment	489,630					489,630
90	(393) Stores Equipment	1,201,468	396,673	739			1,597,402
91	(394) Tools, Shop and Garage Equipment	55,615,846	2,785,957	143,373			58,258,430
92	(395) Laboratory Equipment	470,346					470,346
93	(396) Power Operated Equipment	2,894					2,894
94	(397) Communication Equipment	222,073,189	16,693,132	408,415			238,357,906
95	(398) Miscellaneous Equipment	5,735,259	410,105	130,471		2,572,704	8,587,597
96	SUBTOTAL (Enter Total of lines 86 thru 95)	710,433,337	32,868,221	1,599,589		2,572,704	744,274,673
97	(399) Other Tangible Property
98	(399.1) Asset Retirement Costs for General Plant	622,869		12,995			609,874
99	TOTAL General Plant (Enter Total of lines 96, 97, and 98)	711,056,206	32,868,221	1,612,584		2,572,704	744,884,547
100	TOTAL (Accounts 101 and 106)	10,013,027,829	775,157,007	130,766,320			10,657,418,516
101	(102) Electric Plant Purchased (See Instr. 8)
102	(Less) (102) Electric Plant Sold (See Instr. 8)
103	(103) Experimental Plant Unclassified
104	TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)	10,013,027,829	775,157,007	130,766,320			10,657,418,516

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No.	LesseeName Name of Lessee (a)	IndicationOfAssociatedCompany * (Designation of Associated Company) (b)	LeaseDescription Description of Property Leased (c)	CommissionAuthorization Commission Authorization (d)	ExpirationDateOfLease Expiration Date of Lease (e)	ElectricPlantLeasedToOthers Balance at End of Year (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47	TOTAL

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No.	ElectricPlantHeldForFutureUseDescription Description and Location of Property (a)	ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate Date Originally Included in This Account (b)	ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate Date Expected to be used in Utility Service (c)	ElectricPlantHeldForFutureUse Balance at End of Year (d)
1	Land and Rights:
2	North Corridor Marysville Substation 765 KV Right-of-Way (9520)	02/01/1996		418,481.00
3	Ridgely Substation (3607)	03/01/2010	12/31/2027	469,403.00
4	North Galloway - West Jefferson 69KV Right-of-Way (5684)	05/01/1998		254,004.00
5	Delaware County Site (Berrywood Substation) (0276)	03/01/2006	12/31/2023	252,572.00
6	Giles 138/13.2 KV Substation (0383)	08/01/2009	12/31/2023	699,997.00
7	Shanahan Substation (0277)	11/01/2010	12/31/2027	251,640.00
8	Salerno 138KV Substation (3372)	12/01/2022	12/31/2023	266,070
9	Items under $250,000			2,439,203.00
21	Other Property:
22	Items under $250,000			23,007.00
47	TOTAL			5,074,377

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
Report below descriptions and balances at end of year of projects in process of construction (107). Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts). Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No.	ConstructionWorkInProgressProjectDescription Description of Project (a)	ConstructionWorkInProgress Construction work in progress - Electric (Account 107) (b)
1	ADMS Imp DSN DNEX-OP D	4,776,335
2	AMI IT Work	3,381,359
3	AMI Master - Phase 3	1,901,106
4	Astor - Replace UG TFXR Cables	3,830,691
5	Astor Duct & MH Renewal	1,296,245
6	Bixby - New Feeder F-7109	2,514,995
7	Brice Sta - Construct UG Lines	2,198,887
8	Cambridge Service Center (New)	23,680,270
9	Chillicothe District CB Repl	1,281,835
10	CIS-Common Deployment-OP D	7,398,650
11	CIS-Net Meter/Spc Bill-OP D	1,285,869
12	Columbus Southeast SC	1,124,690
13	Columbus Southwest SC Constr	18,777,931
14	Corp Prgrm Billing - OPCO Tran	2,433,014
15	D/OP/Capital Blanket - OHPCo	5,474,936
16	DACR Control	1,504,559
17	DACR Telecomm	1,917,250
18	Dolan Lab Purchase	4,812,385
19	Ds-Op-Ai Recloser Replacement	1,083,590
20	Ed-Ci-Opco-D Ast Imp	27,156,468
21	Ed-Ci-Opco-D Cust Serv	10,346,882
22	Ed-Ci-Opco-D Ppr	2,582,016
23	EV Chargers for GL BU 250	1,456,632
24	Fiber to Ohio Power Service Ce	1,200,678
25	Fifth Av D-Sta Retire & Instal	5,110,402
26	Gahanna T1 and T2 D-Station	6,382,556
27	Green Chapel Land Transfer	4,800,189
28	Green Chapel Station (250)	4,467,205
29	Hayden Sta - Dist Station	3,286,726
30	Lick Rebuild - Opco-D CI	1,543,703
31	Lick Rebuild - Opco-T CI	2,390,931
32	Lick Sta. Distr Funded Work	2,684,338
33	Marion North Duct & MH Renewal	6,470,516
34	Marion South Duct & MH Renewal	4,346,722
35	Mifflin D&MH Inside Station	1,772,713
36	MillbrookP-SPoint Opco-T CI	1,430,213
37	Minford Battery Installation	4,667,498
38	Mound Sta- Cnstr Dist Feeder	4,258,976
39	New Albany Data Ctr Retrofit	1,157,924
40	North Market PPR Phase 1 Civil	1,979,126
41	Novec 1230 Retrofit-Groveport	1,145,960
42	Ohio Cap Bank Replacements CI	2,590,514
43	Ohio Power Co - Transmission	2,557,931
44	Ohio Power Dist Work	3,138,300
45	Ohio Power Distribution work 1	3,183,445
46	Ohio Power Distribution work 2	3,430,019
47	Ohio Power Transmission work 1	1,496,601
48	Ohio Power Transmission work 2	1,278,211
49	Ohio Power Transmission work 3	2,465,381
50	Ohio PowerCo -Transmission CI	5,911,049
51	OHPCo T-BlnktProj Under $3M	3,071,233
52	OPCo Dist Pre Eng Parent	30,950,724
53	OPCo Major Eq/Spares-Distr	3,483,785
54	OPCo Trans Pre Eng Parent	12,328,676
55	OPCo Transmission Work	1,998,703
56	OPCo-D Service Restoration Blk	1,485,273
57	OPCo-D Small Cap Adds Blkt	6,295,051
58	OPCo-D Spare/Major Equipmen CI	5,931,309
59	OPCO-D Telecom	5,677,803
60	OPCo-D Third Party Work Blkt	1,245,345
61	OPCO-D work	1,708,379
62	OPCO-T CI 1	1,027,577
63	OPCO-T CI 2	1,053,076
64	OPCO-T for Robyville	1,246,157
65	OPCo-T Ohio Canton TTMP CI	4,343,876
66	OPCo-T Ohio South TTMP CI	3,567,603
67	OPCo-T Spare/Major Equipmen CI	1,933,559
68	OPCO-T Work	1,534,231
69	OPCO-T Work CI	1,827,088
70	OPSectionalizing Program	1,447,412
71	OP-T	1,156,556
72	OP-T Baseline	1,961,104
73	OP-T Supplemental	1,180,660
74	Poth - UG Feeder Exits	6,530,875
75	SS-CI-OPCo-D GEN PLT	12,931,175
76	SS-CI-OPCo-T GEN PLT	21,450,669
77	St Clair Ave D-Line UG	2,657,390
78	Supplemental Ohio Power T Work	1,364,920
79	T/OH/North Central OH Area Tel	2,373,624
80	T/OH/Ohio Power Trans work	2,436,168
81	T/OP/Capital Blanket - OHPCo	3,181,741
82	T/OP/NERC Physical Security	34,125,091
83	T/OP/Ohio Power Trans Work	1,472,386
84	Trans station Renew-Refurb OH	1,306,721
85	VVO D-Line Comp - Phase 3	1,263,155
86	X530 retire to Marquis OpcoT	2,681,967
87	Zuber Station - 07 and 08 ckts	1,073,434
88	Other Minor Projects under $1,000,000	74,649,319
43	Total	483,318,237

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
Explain in a footnote any important adjustments during year. Explain in a footnote any difference between the amount for book cost of plant retired, Line 12, column (c), and that reported for electric plant in service, page 204, column (d), excluding retirements of non-depreciable property. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No.	Item (a)	Total (c + d + e) (b)	Electric Plant in Service (c)	Electric Plant Held for Future Use (d)	Electric Plant Leased To Others (e)
Section A. Balances and Changes During Year
1	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance Beginning of Year	2,793,354,070	2,793,337,717	16,353
2	Depreciation Provisions for Year, Charged to
3	DepreciationExpenseExcludingAdjustments (403) Depreciation Expense	254,527,987	254,527,987
4	DepreciationExpenseForAssetRetirementCosts (403.1) Depreciation Expense for Asset Retirement Costs
5	ExpensesOfElectricPlantLeasedToOthers (413) Exp. of Elec. Plt. Leas. to Others
6	TransportationExpensesClearing Transportation Expenses-Clearing
7	OtherClearingAccounts Other Clearing Accounts
8	OtherAccounts Other Accounts (Specify, details in footnote):
9.1	Other Accounts (Specify, details in footnote):	3,016,614	(a) 3,016,614
10	DepreciationProvision TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)	257,544,601	257,544,601
11	Net Charges for Plant Retired:
12	BookCostOfRetiredPlant Book Cost of Plant Retired	102,616,625	102,616,625
13	CostOfRemovalOfPlant Cost of Removal	77,589,099	(b) 77,589,094	5
14	SalvageValueOfRetiredPlant Salvage (Credit)	14,002,108	(c) 14,001,789	319
15	NetChargesForRetiredPlant TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)	166,203,616	166,203,930	314
16	OtherAdjustmentsToAccumulatedDepreciation Other Debit or Cr. Items (Describe, details in footnote):
17.1	Other Debit or Cr. Items (Describe, details in footnote):	3,224,123	(d) 3,224,123
18	BookCostOfAssetRetirementCosts Book Cost or Asset Retirement Costs Retired
19	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)	2,881,470,932	2,881,454,265	16,667
Section B. Balances at End of Year According to Functional Classification
20	AccumulatedDepreciationSteamProduction Steam Production
21	AccumulatedDepreciationNuclearProduction Nuclear Production
22	AccumulatedDepreciationHydraulicProductionConventional Hydraulic Production-Conventional
23	AccumulatedDepreciationHydraulicProductionPumpedStorage Hydraulic Production-Pumped Storage
24	AccumulatedDepreciationOtherProduction Other Production
25	AccumulatedDepreciationTransmission Transmission	916,678,904	916,656,610	22,294
26	AccumulatedDepreciationDistribution Distribution	1,833,253,170	1,833,258,797	5,627
27	AccumulatedDepreciationRegionalTransmissionAndMarketOperation Regional Transmission and Market Operation
28	AccumulatedDepreciationGeneral General	131,538,858	131,538,858
29	AccumulatedProvisionForDepreciationOfElectricUtilityPlant TOTAL (Enter Total of lines 20 thru 28)	2,881,470,932	2,881,454,265	16,667

FOOTNOTE DATA

(a) Concept: OtherAccounts

(b) Concept: CostOfRemovalOfPlant

Includes $9,698,762 of removal cost in retirement work in progress (RWIP).

Includes ($7,011,129)of salvage in retirement work in progress (RWIP).

(d) Concept: OtherAdjustmentsToAccumulatedDepreciation


Defer ARO Deprec&Accretion Exp			$3,224,123

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
Report below investments in Account 123.1, Investments in Subsidiary Companies. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f). Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No.	DescriptionOfInvestmentsInSubsidiaryCompanies Description of Investment (a)	DateOfAcquisitionInvestmentsInSubsidiaryCompanies Date Acquired (b)	DateOfMaturityInvestmentsInSubsidiaryCompanies Date of Maturity (c)	InvestmentInSubsidiaryCompanies Amount of Investment at Beginning of Year (d)	EquityInEarningsOfSubsidiaryCompanies Equity in Subsidiary Earnings of Year (e)	InterestAndDividendRevenueFromInvestments Revenues for Year (f)	InvestmentInSubsidiaryCompanies Amount of Investment at End of Year (g)	InvestmentGainLossOnDisplosal Gain or Loss from Investment Disposed of (h)
1	NCT JOINT VENTURES FUND II:	11/22/2013		1,438,892	606,759		2,045,651
2	Limited Partnership Interest
3	REV1 FUND I, LLC	09/30/2016		561,885	39,506		388,622
4	REV1 Fund II	07/15/2021		28,776	10,726		113,050
42	Total Cost of Account 123.1 $		Total	2,029,553	556,527		2,547,323

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

MATERIALS AND SUPPLIES
For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No.	Account (a)	Balance Beginning of Year (b)	Balance End of Year (c)	Department or Departments which Use Material (d)
1	Fuel Stock (Account 151)
2	Fuel Stock Expenses Undistributed (Account 152)
3	Residuals and Extracted Products (Account 153)
4	Plant Materials and Operating Supplies (Account 154)
5	Assigned to - Construction (Estimated)	70,251,610	102,528,219	Electric
6	Assigned to - Operations and Maintenance
7	Production Plant (Estimated)
8	Transmission Plant (Estimated)	1,017,815	3,227,275	Electric
9	Distribution Plant (Estimated)	2,723,345	3,323,673	Electric
10	Regional Transmission and Market Operation Plant (Estimated)
11	Assigned to - Other (provide details in footnote)	(a) 142,085	(b) 457,491	Electric
12	TOTAL Account 154 (Enter Total of lines 5 thru 11)	74,134,855	109,536,658
13	Merchandise (Account 155)
14	Other Materials and Supplies (Account 156)
15	Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)
16	Stores Expense Undistributed (Account 163)
17
18
19
20	TOTAL Materials and Supplies	74,134,855	109,536,658

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesOther

Assigned to - Other includes Customer Account, Administrative, and General Expenses.

(b) Concept: PlantMaterialsAndOperatingSuppliesOther

Assigned to - Other includes Customer Account, Administrative, and General Expenses.

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	SO2 Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)
5	Returned by EPA
6
7
8	Purchases/Transfers:
9
10
11
12
13
14
15	Total
16
17	Relinquished During Year:
18	Charges to Account 509
19	Other:
20	Allowances Used
20.1	Allowances Used
21	Cost of Sales/Transfers:
22
23
24
25
26
27
28	Total
29	Balance-End of Year
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)
33	Net Sales Proceeds (Other)
34	Gains
35	Losses
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year
37	Add: Withheld by EPA
38	Deduct: Returned by EPA
39	Cost of Sales
40	Balance-End of Year
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)
44	Net Sales Proceeds (Other)
45	Gains
46	Losses

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	NOx Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)
5	Returned by EPA
6
7
8	Purchases/Transfers:
9
10
11
12
13
14
15	Total
16
17	Relinquished During Year:
18	Charges to Account 509
19	Other:
20	Allowances Used
20.1	Allowances Used
21	Cost of Sales/Transfers:
22
23
24
25
26
27
28	Total
29	Balance-End of Year
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)
33	Net Sales Proceeds (Other)
34	Gains
35	Losses
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year
37	Add: Withheld by EPA
38	Deduct: Returned by EPA
39	Cost of Sales
40	Balance-End of Year
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)
44	Net Sales Proceeds (Other)
45	Gains
46	Losses

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfExtraordinaryPropertyLoss Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).] (a)	ExtraordinaryPropertyLossesNotYetRecognized Total Amount of Loss (b)	ExtraordinaryPropertyLossesRecognized Losses Recognized During Year (c)	ExtraordinaryPropertyLossesWrittenOffAccountCharged Account Charged (d)	ExtraordinaryPropertyLossesWrittenOff Amount (e)	ExtraordinaryPropertyLosses Balance at End of Year (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
20	TOTAL

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)] (a)	UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized Total Amount of Charges (b)	UnrecoveredPlantAndRegulatoryStudyCostsRecognized Costs Recognized During Year (c)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged Account Charged (d)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff Amount (e)	UnrecoveredPlantAndRegulatoryStudyCosts Balance at End of Year (f)
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49	TOTAL

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

Transmission Service and Generation Interconnection Study Costs
Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies. List each study separately. In column (a) provide the name of the study. In column (b) report the cost incurred to perform the study at the end of period. In column (c) report the account charged with the cost of the study. In column (d) report the amounts received for reimbursement of the study costs at end of period. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.	DescriptionOfStudyPerformed Description (a)	StudyCostsIncurred Costs Incurred During Period (b)	StudyCostsAccountCharged Account Charged (c)	StudyCostsReimbursements Reimbursements Received During the Period (d)	StudyCostsAccountReimbursed Account Credited With Reimbursement (e)
1	Transmission Studies
2	AD2-031	2,150	186	2,571	186
3	AE1-093	2,096	186	2,305	186
4	AE2-136	320	186
5	AF1-029	7,177	186	4,959	186
6	AF1-047	2,320	186
7	AF1-062	3,746	186	4,041	186
8	AF1-076	19,236	186	19,472	186
9	AF1-077	2,324	186	2,489	186
10	AF1-085	8,963	186	11,525	186
11	AF1-113	5,579	186	5,726	186
12	AF1-117	28,767	186	26,896	186
13	AF1-144	6,131	186	6,891	186
14	AF1-164	9,072	186	9,475	186
15	AF1-227	50,140	186	57,023	186
16	AF1-275	2,956	186	2,814	186
17	AF1-283	46,313	186	46,568	186
18	AF2-014	6,389	186	8,084	186
19	AF2-059	236	186	236	186
20	AF2-124	6,381	186	1,426	186
21	AF2-137	29,386	186	31,459	186
22	AF2-149	31,322	186	31,322	186
23	AF2-198	23,858	186	22,830	186
24	AF2-209	5,416	186	5,658	186
25	AF2-376	2,720	186	2,813	186
26	AF2-440	41,058	186	33,265	186
27	AG1-003	61	186
28	AG1-004	54	186
29	AG1-042	203	186
30	AG1-076	80	186
31	AG1-163	3,189	186	3,778	186
32	AG1-218	67	186
33	AG1-358	8	186
34	AG1-369	56	186
35	AG1-380	39	186
36	AG1-456	106	186
37	AG1-554	66	186
38	AG2-006	9	186	17	186
39	AG2-031	7	186	13	186
40	AG2-082	9	186	17	186
41	AG2-104	17	186	31	186
42	AG2-105		186	18	186
43	AG2-106	9	186	14	186
44	AG2-107	7	186	14	186
45	AG2-148	8	186	15	186
46	AG2-175	52	186	105	186
47	AG2-194	43	186	86	186
48	AG2-218	46	186	91	186
49	AG2-383	679	186	1,363	186
50	AG2-470	7	186	14	186
51	AG2-503	5	186	11	186
52	AG2-547	36	186	72	186
53	AG2-548	22	186	39	186
54	AH1-015	20	186	36	186
55	AH1-032	7	186	14	186
56	PJM - #AC2-060	2,949	186	24,170	186
57	PJM - #AD1-015	43	186	129	186
58	PJM - #AD1-070	6,986	186	5,882	186
59	PJM - #AD1-106	4,073	186	4,073	186
60	PJM - #AD1-130	718	186	3,241	186
61	PJM - #AD2-067	3,574	186	3,292	186
62	PJM - #AD2-162	16,256	186	23,722	186
63	PJM - #AE1-021	93	186
64	PJM - #AE1-090	1,191	186	1,191	186
65	PJM - #AE1-091	6,112	186	7,459	186
66	PJM - #AE1-146	3,437	186	5,143	186
67	PJM - #AE2-174	360	186	427	186
68	PJM - #AF1-228	6,796	186	6,827	186
69	PJM - #AF1-229	3,524	186	4,177	186
70	PJM - #AF2-377	4,574	186	5,163	186
71	PJM - #AF2-395	219	186
72	PJM - #AG1-239	54	186
73	PJM - #AG1-351	5	186
74	PJM - AD1-073	1,058	186	1,414	186
75	PJM - AD1-101	8,286	186
76	PJM - AD1-119	1,844	186
77	PJM - AD2-086	1,158	186	619	186
78	PJM - AD2-091	1,306	186	1,306	186
79	PJM - AD2-092	384	186	134	186
80	PJM - AD2-093	932	186	398	186
81	PJM - AD2-096	443	186	578	186
82	PJM - AE1-102	155	186
20	Total
21	Generation Studies
22	None
39	Total
40	Grand Total

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

OTHER REGULATORY ASSETS (Account 182.3)
Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Assets being amortized, show period of amortization.
				CREDITS
Line No.	DescriptionAndPurposeOfOtherRegulatoryAssets Description and Purpose of Other Regulatory Assets (a)	OtherRegulatoryAssets Balance at Beginning of Current Quarter/Year (b)	IncreaseDecreaseInOtherRegulatoryAssets Debits (c)	OtherRegulatoryAssetsWrittenOffAccountCharged Written off During Quarter/Year Account Charged (d)	OtherRegulatoryAssetsWrittenOffRecovered Written off During the Period Amount (e)	OtherRegulatoryAssets Balance at end of Current Quarter/Year (f)
1	Under-Recovery of Integrated Gasification Combined Cycle (IGCC) Deferral- Case No. 05-376-EL-UNC	59,540				59,540
2	Under-Recovered Ohio BTCR - Ohio ESP - Case No. 13-2385-EL-SSO - Ohio ESP - Case No. 13-2386-EL-AAM	5,208,880	32,569,645	566	23,515,838	14,262,687
3	COVID-19 Deferred Expense
4	PJM 2020 Transmission DeferralAmortization period: Jan 2022-Dec 2022	7,532,766	627,731	565	8,160,497
5	FERC Formula Rates Under Recvr	4,200,178		456	4,200,178
6	Smart City Rider (SCR) Case No. 16-1852-EL-SSO Case No. 16-1853-EL-AAM	975,730	2,347,302	908	3,297,641	25,391
7	SFAS 112 Post-Employment Benefits- Case No. 08-917-EL-SSO	6,161,633	61,231	228	38,670	6,184,194
8	EDR Deferral	10,083,380	7,432,838	440/442/444/445/447	16,392,648	1,123,570
9	Deferred Storm Expense	3,787,916	33,983,730	593	3,978,297	33,793,349
10	Under-Recovery of Excess Deferred Federal Income Tx- Case No. 18-1007-EL-UNC- Case No. 18-1451-EL-ATA	249,585				249,585
11	Rate Case Expenses - Ohio 2020	73,803		928	15,991	57,812
12	Under Recovered ESRP Cost - OH	9,537,789	25,965,942	593	2,149,460	33,354,271
13	SFAS 106 Medicare Subsidy - Amortization Period: 01/2013 to 12/2024	3,096,610		926	1,032,204	2,064,406
14	SFAS 109 Flow-through Deferred Federal Inc Tx (FIT)	59,237,485	35,202,391	190/254/236/282/283/409/41	36,856,710	57,583,166
15	SFAS 109 Flow-through Deferred State Inc Tx (SIT)	2,752,311	399,187	283	31,555	3,119,943
16	Pilot Throughput Balancing Adjust Rider (PTBAR) Carrying Charges (Distribution	841,309	611,054	407	1,146,836	305,527
17	Unrealized Loss on Forward Commitments	92,102,172	23,240,805	244/254	75,794,030	39,548,947
18	Pilot Throughput Balancing Adjustment Rider (PTBAR) Under-Recovery	24,302,463	16,200,149	440/442	21,435,852	19,066,760
19	Unrealized Loss on Forward Commitments - Netting of Trading Activities between		1,605,223	244/254	1,161,278	443,945
20	GridSMART Phase 2 Under-Recovery - Case No. 13-1939-EL-RDR	19,294,913	6,996,818	403	889,017	25,402,714
21	Under-Recovery Ohio Valley Electric Corporation (OVEC) Purchased Power
22	Distribution Deferred Assets - Partnership With Ohio (PWO) - Case No. 16-1852-EL-
23	SFAS 158 Employers' Accounting for Defined Benefit	83,287,088	178,688,977	182	119,294,745	142,681,320
24	GreenHat Settlement Regulatory Deferral
25	PJM Deferral
26	ACRR Costs - OH		32,604,407	254/555	28,785,587	3,818,820
27	Under-Recovery Distribution Investment Rider (DIR)	2,126,008	4,500,178	403	4,369,304	2,256,882
28	Under-Recovery Distribution Decoupling Revenue Program (Pilot Throughput	16,051,426	148,723	182	16,200,149
29	Bad Debt Rider Under-Recovery Case No. 20-585	704,835		426	704,835
30	PJM Transmission True-up		4,540,573			4,540,573
31	Distribution Decoupling Revenue Program Carrying Charges	436,637	272,432	182	611,055	98,014
44	TOTAL	352,104,457	407,999,336		370,062,377	390,041,416

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

MISCELLANEOUS DEFFERED DEBITS (Account 186)
Report below the particulars (details) called for concerning miscellaneous deferred debits. For any deferred debit being amortized, show period of amortization in column (a) Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
				CREDITS
Line No.	Description of Miscellaneous Deferred Debits (a)	Balance at Beginning of Year (b)	Debits (c)	Credits Account Charged (d)	Credits Amount (e)	Balance at End of Year (f)
1	Deferred Property Taxes	351,202,520	374,398,946	107/236/408	354,428,751	371,172,715
2	Agency Fees - Factored A/R	7,680,120	64,809,080	184	62,917,938	9,571,262
3	Unamortized Credit Line Fees	1,093,372	219,396	431	432,673	880,095
4	Deferred Expenses - Misc.	6,723	82,807	152/183/560/580	80,359	9,171
5	Def Lease Assets - Non Taxable	275,062	1,074,970	142/143/184	1,067,011	283,021
6	Transource PJM LSE Over/Under Deferral	416,778	499,111	565	678,541	237,348
7	Long Term Assoc AR - Annual Transmission True-up		34,951,009	253	13,308,164	21,642,845
47	Miscellaneous Work in Progress	2,490,433				1,500,958
48	Deferred Regulatroy Comm. Expenses (See pages 350 - 351)
49	TOTAL	363,165,008				405,297,415

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

ACCUMULATED DEFERRED INCOME TAXES (Account 190)
Report the information called for below concerning the respondent’s accounting for deferred income taxes. At Other (Specify), include deferrals relating to other income and deductions.
Line No.	DescriptionOfAccumulatedDeferredIncomeTax Description and Location (a)	AccumulatedDeferredIncomeTaxes Balance at Beginning of Year (b)	AccumulatedDeferredIncomeTaxes Balance at End of Year (c)
1	Electric
2	CIAC - BOOK RECEIPTS	23,336,485	29,571,082
3	EXCESS ADFIT	111,844,494	106,702,059
4	BOOK OPERATING LEASE - LIAB	17,163,477	15,486,741
5	INT EXP CAPITALIZED FOR TAX	37,143,358	39,700,001
6	ACCRD SFAS 106 PST RETIRE EXP	12,124,667	14,158,754
7	Other	92,956,299	73,029,511
8	TOTAL Electric (Enter Total of lines 2 thru 7)	84,406,848	104,271,618
9	Gas
15	Other
16	TOTAL Gas (Enter Total of lines 10 thru 15)
17.1	Other (Specify) Nonutility, SFAS 109, 87 & 133	119,950,603	(a) 114,549,320
17	Other (Specify)
18	TOTAL (Acct 190) (Total of lines 8, 16 and 17)	204,357,451	218,820,938

Notes

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxes

Line 17 Other - Detail                Balance at     Balance at
                     Beginning of Year      End of Year
Acc Def Income Taxes - Federal - Hdg-CF-Int Rate            –        –
Non Utility Items - 190.2                 1,466,296     1,157,628
SFAS 109-Regulatory Assets - 190.3 & 190.4         118,484,307     113,391,692
SFAS 133                            –        –
Accu Def Income Taxes Pension-OCI                –        –
Total                        $119,950,603     $114,549,320
Line 18
Reconciliation of details applicable to Account 190, Line 18, Columns (b) and (c) :
Balance at Beginning of Year                $204,357,451
(Less) Amounts Debited to:
(a) Account 410.1                 (34,542,494)
(b) Account 410.2                 (2,598,210)
(c) 1823/254/219/129/427             (11,857,866)
(Plus) Amounts Credited to:
(a) Account 411.1                 54,498,650
(b) Account 411.2         2,198,156 (c) 1823/254/219/129/427             6,765,251
Balance at End of Year              $218,820,938

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

CAPITAL STOCKS (Account 201 and 204)
Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No.	Class and Series of Stock and Name of Stock Series (a)	Number of Shares Authorized by Charter (b)	Par or Stated Value per Share (c)	Call Price at End of Year (d)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares (e)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount (f)	Held by Respondent As Reacquired Stock (Acct 217) Shares (g)	Held by Respondent As Reacquired Stock (Acct 217) Cost (h)	Held by Respondent In Sinking and Other Funds Shares (i)	Held by Respondent In Sinking and Other Funds Amount (j)
1	Common Stock (Account 201)
2	Common Stock (Account 201)	40,000,000			27,952,473	321,201,454
6	Total	40,000,000			27,952,473	321,201,454
7	Preferred Stock (Account 204)
8
9
10
11	Total
1	Capital Stock (Accounts 201 and 204) - Data Conversion
2
3
4
5	Total

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2023-04-12

Year/Period of Report

End of:

2022

Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No.	Item (a)	Amount (b)
1	DonationsReceivedFromStockholdersAbstract Donations Received from Stockholders (Account 208)
2	DonationsReceivedFromStockholders Beginning Balance Amount	840,695,320
3.1	IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders Increases (Decreases) from Sales of Donations Received from Stockholders
4	DonationsReceivedFromStockholders Ending Balance Amount	840,695,320
5	ReductionInParOrStatedValueOfCapitalStockAbstract Reduction in Par or Stated Value of Capital Stock (Account 209)
6	ReductionInParOrStatedValueOfCapitalStock Beginning Balance Amount
7.1	IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8	ReductionInParOrStatedValueOfCapitalStock Ending Balance Amount
9	GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10	GainOnResaleOrCancellationOfReacquiredCapitalStock Beginning Balance Amount	3,057,087
11.1	IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock
12	GainOnResaleOrCancellationOfReacquiredCapitalStock Ending Balance Amount	3,057,087
13	MiscellaneousPaidInCapitalAbstract Miscellaneous Paid-In Capital (Account 211)
14	MiscellaneousPaidInCapital Beginning Balance Amount	4,971,195
15.1	IncreasesDecreasesDueToMiscellaneousPaidInCapital Increases (Decreases) Due to Miscellaneous Paid-In Capital	979,000
16	MiscellaneousPaidInCapital Ending Balance Amount	5,950,195
17	OtherPaidInCapitalAbstract Historical Data - Other Paid in Capital
18	OtherPaidInCapitalDetail Beginning Balance Amount
19.1	IncreasesDecreasesInOtherPaidInCapital Increases (Decreases) in Other Paid-In Capital
20	OtherPaidInCapitalDetail Ending Balance Amount
40	OtherPaidInCapital Total	837,802,212

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

CAPITAL STOCK EXPENSE (Account 214)
Report the balance at end of the year of discount on capital stock for each class and series of capital stock. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No.	NameOfClassAndSeriesOfStock Class and Series of Stock (a)	CapitalStockExpense Balance at End of Year (b)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22	TOTAL

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

LONG-TERM DEBT (Account 221, 222, 223 and 224)
Report by Balance Sheet Account the details concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds, and in column (b) include the related account number. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received, and in column (b) include the related account number. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued, and in column (b) include the related account number. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (m). Explain in a footnote any difference between the total of column (m) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No.	ClassAndSeriesOfObligationCouponRateDescription Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates) (a)	RelatedAccountNumber Related Account Number (b)	Principal Amount of Debt Issued (c)	LongTermDebtIssuanceExpensePremiumOrDiscount Total Expense, Premium or Discount (d)	LongTermDebtIssuanceExpenses Total Expense (e)	LongTermDebtPremium Total Premium (f)	LongTermDebtDiscount Total Discount (g)	NominalDateOfIssue Nominal Date of Issue (h)	DateOfMaturity Date of Maturity (i)	AmortizationPeriodStartDate AMORTIZATION PERIOD Date From (j)	AmortizationPeriodEndDate AMORTIZATION PERIOD Date To (k)	Outstanding (Total amount outstanding without reduction for amounts held by respondent) (l)	Interest for Year Amount (m)
1	Bonds (Account 221)
2	None
3	Subtotal
4	Reacquired Bonds (Account 222)
5
6
7
8	Subtotal
9	Advances from Associated Companies (Account 223)
10	None
11	Subtotal
12	Other Long Term Debt (Account 224)
13	Installment Purchase Contracts:
14	None
15	Senior Unsecured Notes:
16	6.60% Unsecured Medium Term Notes Series D Due 03/2033		250,000,000		2,187,500		1,180,000	02/14/2003	03/01/2033	02/14/2003	03/01/2033	250,000,000	16,500,000
17	5.85% Unsecured Medium Term Notes Series F Due 10/2035		250,000,000		2,187,500		2,815,000	10/14/2005	10/01/2035	10/14/2005	10/01/2035	250,000,000	14,625,000
18	4% Unsecured Medium Term Notes Series O Due 06/2049		450,000,000		4,665,098		1,098,000	05/22/2019	06/01/2049	05/22/2019	06/01/2049	450,000,000	18,000,000
19	2.6% Unsecured Medium Term Notes Series P Due 04/2030		350,000,000		2,812,802		371,000	03/17/2020	04/01/2030	03/17/2020	04/01/2030	350,000,000	9,100,000
20	6.60% Unsecured Medium Term Notes Series G Due 02/2033		250,000,000		2,368,087		1,165,000	02/14/2003	02/15/2033	02/14/2003	02/15/2033	250,000,000	16,500,000
21	4.15% Unsecured Notes Series N Due 04/2048		400,000,000		4,165,966		2,928,000	03/22/2018	04/01/2048	03/22/2018	04/01/2048	400,000,000	16,600,000
22	(a) 1.625% Unsecured Notes Series Q Due 01/2031		450,000,000		3,749,956		706,500	01/07/2021	01/15/2031	01/07/2021	01/15/2031	450,000,000	7,312,500
23	(b) 2.9% Unsecured Notes Series R Due 10/2051		600,000,000		6,333,271		2,874,000	09/13/2021	10/01/2051	09/13/2021	10/01/2051	600,000,000	17,400,000
24	Groveport Service Center Facility Lease:
25	Groveport Facilty Lease		1,138,364					05/01/2013	04/30/2028	05/01/2013	04/30/2028	641,808
26	Subtotal		3,001,138,364		28,470,180		13,137,500					3,000,641,808	116,037,500
33	TOTAL		3,001,138,364									3,000,641,808	116,037,500

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: ClassAndSeriesOfObligationCouponRateDescription

The $450M 1.625% fixed rate Series Q Senior Unsecured Note was issued 1/07/2021 with a maturity date of 1/15/2031. Issuance expense and discount expense will be amortized through January 2031.

(b) Concept: ClassAndSeriesOfObligationCouponRateDescription

The $600M 2.900% fixed rate Series R Senior Unsecured Note was issued 9/13/2021 with a maturity date of 10/01/2051. Issuance expense and discount expense will be amortized through October 2051.

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No.	Particulars (Details) (a)	Amount (b)
1	Net Income for the Year (Page 117)	287,797,165
2	Reconciling Items for the Year
3
4	Taxable Income Not Reported on Books
5
6
7
8
9	Deductions Recorded on Books Not Deducted for Return
10
11
12
13
14	Income Recorded on Books Not Included in Return
15
16
17
18
19	Deductions on Return Not Charged Against Book Income
20
21
22
23
24
25
26
27	Federal Tax Net Income	104,406,686
28	Show Computation of Tax:
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (d). Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (l) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
					BALANCE AT BEGINNING OF YEAR					BALANCE AT END OF YEAR		DISTRIBUTION OF TAXES CHARGED
Line No.	DescriptionOfTaxesAccruedPrepaidAndCharged Kind of Tax (See Instruction 5) (a)	TypeOfTax Type of Tax (b)	TaxJurisdiction State (c)	TaxYear Tax Year (d)	TaxesAccrued Taxes Accrued (Account 236) (e)	PrepaidTaxes Prepaid Taxes (Include in Account 165) (f)	TaxesCharged Taxes Charged During Year (g)	TaxesPaid Taxes Paid During Year (h)	TaxAdjustments Adjustments (i)	TaxesAccrued Taxes Accrued (Account 236) (j)	PrepaidTaxes Prepaid Taxes (Included in Account 165) (k)	TaxesAccruedPrepaidAndCharged Electric (Account 408.1, 409.1) (l)	IncomeTaxesExtraordinaryItems Extraordinary Items (Account 409.3) (m)	AdjustmentsToRetainedEarnings Adjustment to Ret. Earnings (Account 439) (n)	TaxesIncurredOther Other (o)
1	Federal Tax	Federal Tax			7,836,048		33,077,671	22,623,800		2,617,823	0	24,174,182			8,903,489
2	Subtotal Federal Tax				7,836,048	0	33,077,671	22,623,800		2,617,823	0	24,174,182			8,903,489
3	State Tax 2014	State Tax	IL	2014	8,731					8,731	0
4	State Tax 2016	State Tax	IL	2016	1					1	0
5	State Tax 2017	State Tax	IL	2017	1,337					1,337	0
6	State Tax 2018	State Tax	IL	2018	210,013					210,013	0
7	State Tax 2019	State Tax	IL	2019	197,109					197,109	0
8	State Tax 2020	State Tax	IL	2020	47,029					47,029	0
9	State Tax 2021	State Tax	IL	2021	54,706			404,731		350,025	0
10	State Tax 2022	State Tax	IL	2022	0		89			89		2,694			2,783
11	State Tax 2017	State Tax	KY	2017	57,645					57,645	0
12	State Tax 2018	State Tax	KY	2018	13,750					13,750	0
13	State Tax 2019	State Tax	KY	2019	6,814					6,814	0
14	State Tax 2020	State Tax	KY	2020	7,863					7,863	0
15	State Tax 2021	State Tax	KY	2021	7,785			39,283		47,068	0
16	State Tax 2017	State Tax	MI	2017	6,008					6,008	0
17	State Tax 2018	State Tax	MI	2018	8,148					8,148	0
18	State Tax 2019	State Tax	MI	2019	623					623	0
19	State Tax 2020	State Tax	MI	2020	344					344	0
20	State Tax 2021	State Tax	MI	2021	0			1,860		1,860
21	State Tax 2022	State Tax	MI	2022	0					0	0
22	State Tax 2017	State Tax	WV	2017	23,273					23,273	0	334,715			334,715
23	State Tax 2018	State Tax	WV	2018	28,658					28,658	0
24	State Tax 2019	State Tax	WV	2019	54,946					54,946	0
25	State Tax 2020	State Tax	WV	2020	32,471					32,471	0
26	State Tax 2021	State Tax	WV	2021	22,634			12,852		35,486
27	State Tax 2019	State Tax	MULTI	2019	1,904,877					1,904,877	0
28	State Tax 2021	State Tax	UT	2021	0			100		100
29	State Tax 2022	State Tax	OH	2022	0							3,651			3,651
30	State Tax 2022	State Tax	KY	2022	0					0		409			409
31	Subtotal State Tax				2,247,831	0	89	354,356		1,893,564	0	341,469			341,558
32	City Tax 2017	Local Tax	OH	2017	2,900,289	0				2,900,289	0
33	City Tax 2018	Local Tax	OH	2018	2,888,066	0				2,888,066	0
34	City Tax 2019	Local Tax	OH	2019	4,253,111	0				4,253,111	0
35	City Tax 2020	Local Tax	OH	2020	319,464	0				319,464	0
36	City Tax 2021	Local Tax	OH	2021	127,255			1,047		126,208	0
37	City Tax 2022	Local Tax	OH	2022			239,246	4,160		243,406					239,246
38	Subtotal Local Tax				4,457,543	0	239,246	5,207		4,701,996	0				239,246
39	Subtotal Other Tax				0	0				0	0
40	Personal Property Leased	Property Tax	OH	2018			436	436		0	0	436
41	Personal Property Leased	Property Tax	OH	2021	788,941		78,492	867,433		0	0	78,492
42	Personal Property Leased	Property Tax	OH	2022			902,866	3,048		899,818	0	902,866
43	Real & Pers Prop	Property Tax	OH	2018			35,836	35,836		0	0	35,836
44	Real & Pers Prop	Property Tax	OH	2019			24,087	24,087		0		24,086			1
45	Real & Pers Prop	Property Tax	OH	2020	320,936,583		2,524,930	318,411,653		0		2,522,132			2,798
46	Real & Pers Prop	Property Tax	OH	2021	350,198,487		7,224,328	163,899		342,810,260		342,664,424			349,888,752
47	Real & Pers Prop	Property Tax	OH	2022			370,167,453	2,160		370,169,613		199,820			369,967,633
48	Real & Pers Prop	Property Tax	WV	2020	413,936			413,936		0		407,580			407,580
49	Real & Pers Prop	Property Tax	WV	2021	806,263		11,410	408,837		408,836		413,678			402,268
50	Real Prop Leased	Property Tax	WV	2022			817,700			817,700					817,700
51	Subtotal Property Tax				673,144,210	0	362,288,150	320,326,133		715,106,227	0	342,204,214			20,083,936
52	UNEMPLOYMENT 2022	Unemployment Tax			16,719	0	65,961	79,908		2,772	0	18,884			47,077
53	STATE UNEMPLOYMENT 2022	Unemployment Tax	IL		0					0
54	STATE UNEMPLOYMENT 2022	Unemployment Tax	OH		22,453	0	237,055	241,361		18,147	0	99,741			137,314
55	STATE UNEMPLOYMENT 2022	Unemployment Tax	WV		0	0				0	0
56	Subtotal Unemployment Tax				39,172	0	303,016	321,269		20,919	0	118,625			184,391
57	KWH State Excise Tax	Excise Tax	OH	2021	12,416,670			12,416,670
58	KWH State Excise Tax	Excise Tax	OH	2022			145,642,383	133,095,654		12,546,729	0	145,641,284			1,099
59	Subtotal Excise Tax				12,416,670	0	145,642,383	145,512,324		12,546,729	0	145,641,284			1,099
60	Subtotal Federal Insurance Tax				0	0				0	0
61	Franchise Tax	Franchise Tax	KY	2017	1,376	0				1,376	0
62	Franchise Tax	Franchise Tax	KY	2018	3,030	0				3,030	0
63	Franchise Tax	Franchise Tax	KY	2019	2,302	0				2,302	0
64	Franchise Tax	Franchise Tax	UT	2017	100	0				100	0
65	Franchise Tax	Franchise Tax	KY	2020	1,741	0				1,741	0
66	Subtotal Franchise Tax				8,349	0				8,349	0
67					0	0				0
68	Ohio CAT Tax	Miscellaneous Other Tax	OH	2021	1,659,300		39,966	1,699,266		0		39,966
69	Ohio CAT Tax	Miscellaneous Other Tax	OH	2022	0		8,122,197	6,363,897		1,758,300	0	8,122,197
70	Subtotal Other State Tax				1,659,300	0	8,162,163	8,063,163		1,758,300	0	8,162,163
71	Use Tax	Other Use Tax	OH	2021	417,645	100,000	59,173	258,472		0		1			59,172
72	Use Tax	Other Use Tax	OH	2022			1,974,457	1,773,640		400,817	200,000	8,227			1,982,684
73	Use Tax	Other Use Tax	WV	2021	5,590		3,734	1,856		0					3,734
74	Use Tax	Other Use Tax	WV	2022			79,168	35,587		43,581					79,168
75	Subtotal Other Use Tax				423,235	100,000	1,990,718	2,069,555		444,398	200,000	8,228			1,998,946
76	Occ & PUCO Fees	Other License And Fees Tax	OH	2022			5,867,924	5,867,924		0	0				5,867,924
77	State License Registration	Other License And Fees Tax	WV	2019	26					26	0
78	Subtotal Other License And Fees Tax				26	0	5,867,924	5,867,924		26	0				5,867,924
79	FICA 2022	Payroll Tax			1,561,665	0	13,330,408	16,658,448	3,096,246	1,329,871	0	6,169,760			7,160,648
80	2360104 FICA	Payroll Tax			0	0				0	0
81	2360105 FICA CARES ACT	Payroll Tax			3,096,246	0			3,096,246	0	0
82	Subtotal Payroll Tax				4,657,911	0	13,330,408	16,658,448		1,329,871	0	6,169,760			7,160,648
83	Federal Income Tax Fin 48	Other Federal Tax			0	0	5,090,980			5,090,980					5,090,980
40	TOTAL				697,975,157	100,000	509,358,914	476,554,579		730,879,492	200,000	477,772,167			31,586,747

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)
Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.
			Deferred for Year		Allocations to Current Year's Income
Line No.	Account Subdivisions (a)	Balance at Beginning of Year (b)	Account No. (c)	Amount (d)	Account No. (e)	Amount (f)	Adjustments (g)	Balance at End of Year (h)	Average Period of Allocation to Income (i)	ADJUSTMENT EXPLANATION (j)
1	Electric Utility
2	3%				411.4
3	4%				411.4
4	7%				411.4
5	10%	512	411.1		411.4	501		11	1 Year
6	State DITC		411.1		411.4
7	30				411.4
8	TOTAL Electric (Enter Total of lines 2 thru 7)	512				501		11
9	Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10										`
47	OTHER TOTAL
48	GRAND TOTAL	512						11

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

OTHER DEFERRED CREDITS (Account 253)
Report below the particulars (details) called for concerning other deferred credits. For any deferred credit being amortized, show the period of amortization. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
			DEBITS
Line No.	Description and Other Deferred Credits (a)	Balance at Beginning of Year (b)	Contra Account (c)	Amount (d)	Credits (e)	Balance at End of Year (f)
1	Customer Advance Receipts	20,614,654	142	20,614,654	24,682,997	24,682,997
2	Deferred Rev - Pole Attachments	2,172,897	172/454	9,358,434	9,265,341	2,079,804
3	Deferred Rev- Bonus Lease Curr	25,290	456	25,290
4	Deferred Rev- Bonus Lease NC
5	SFAS 106 - OPEB
6	Other Deferred Credits	2,091,495	142/143/184/186	2,091,495	1,746,980	1,746,980
7	Customer Choice Collateral Deposit	6,005,529	232/561	60,936,585	70,106,585	15,175,529
8	Contr In Aid of Constr Advance	5,443,337	107/108	5,443,337	11,787,068	11,787,068
9	Fiber Opt Lines Sold Deferred Rev- Amortization period - 1/2005 to 12/2024	139,166	451	111,966		27,200
10	Security Deposit				27,339,438	27,339,438
11	ABD - Sharyland Deferred Revenue	543,171	142/454	543,171	559,466	559,466
12	Long Term Assoc AP				4,824,134	4,824,134
13	Def Revenue GPDC2 Lease-Affil	773,873			231,385	1,005,258
14	QUAL OF SVC PENALTIES - LT	412,670				412,670
47	TOTAL	38,222,082		99,124,932	150,543,394	89,640,544

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)

Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property.
For other (Specify),include deferrals relating to other income and deductions.
Use footnotes as required.

CHANGES DURING YEAR

ADJUSTMENTS

Debits

Credits

Line No.

Account

(a)

Balance at Beginning of Year

(b)

Amounts Debited to Account 410.1

(c)

Amounts Credited to Account 411.1

(d)

Amounts Debited to Account 410.2

(e)

Amounts Credited to Account 411.2

(f)

Account Credited

(g)

Amount

(h)

Account Debited

(i)

Amount

(j)

Balance at End of Year

(k)

Accelerated Amortization (Account 281)

Electric

Defense Facilities

Pollution Control Facilities

Other

5.1

Other (provide details in footnote):

TOTAL Electric (Enter Total of lines 3 thru 7)

Gas

Defense Facilities

Pollution Control Facilities

Other

12.1

Other (provide details in footnote):

TOTAL Gas (Enter Total of lines 10 thru 14)

Other

16.1

Other - SFAS 109

254

TOTAL (Acct 281) (Total of 8, 15 and 16)

Classification of TOTAL

Federal Income Tax

State Income Tax

Local Income Tax

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization. For other (Specify),include deferrals relating to other income and deductions. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 282
2	Electric	1,414,578,209	168,556,312	81,989,819					190		1,501,144,702
3	Gas
4	Other (Specify)
5	Total (Total of lines 2 thru 4)	1,414,578,209	168,556,312	81,989,819							1,501,144,702
6	Non Utility	455,539									455,539
7	SFAS 109/FIN 48	354,999,439					1823/254	32,808,354	1823/254	52,710,273	335,097,520
9	TOTAL Account 282 (Total of Lines 5 thru 8)	1,060,034,309	168,556,312	81,989,819				32,808,354		52,710,273	1,166,502,721
10	Classification of TOTAL
11	Federal Income Tax	1,060,034,309	168,556,312	81,989,819			—	32,808,354	—	52,710,273	1,166,502,721
12	State Income Tax
13	Local Income Tax

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283. For other (Specify),include deferrals relating to other income and deductions. Provide in the space below explanations for Page 276. Include amounts relating to insignificant items listed under Other. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 283
2	Electric
3	ACCRUED BK PENSION EXPENSE	30,856,622	227,453	730,356							30,353,719
4	CAPITALIZED SOFTWARE COST-BOOK	32,154,041	427,809	2,424,016							30,157,834
5	REG ASSET-UND/REC DIST RECOUP REV PROG	3,370,800	31,232	3,402,031							1
6	DEFD TAX GAIN - SEC I REG ASSET	5,090,980									5,090,980
7	REG ASSET-SFAS 158 - PENSIONS	24,704,407	253,882	1,517,126							23,441,163
8	Other	55,507,461	64,885,831	46,684,141	130,892	6,786,719					67,053,324
9	TOTAL Electric (Total of lines 3 thru 8)	151,684,311	65,826,207	54,757,670	130,892	6,786,719					156,097,021
10	Gas
11
12
13
14
15
16
17	TOTAL Gas (Total of lines 11 thru 16)
18	TOTAL Other	6,426,290	55,581				1823/254	7,958,872	1823/254	11,677,319	2,652,262
19	TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)	145,258,021	65,881,788	54,757,670	130,892	6,786,719		7,958,872		11,677,319	153,444,759
20	Classification of TOTAL
21	Federal Income Tax	86,680,801	59,081,705	48,330,987	130,892	6,786,719		7,927,317		11,278,133	94,126,508
22	State Income Tax	58,577,220	6,800,083	6,426,692				31,555		399,186	59,318,242
23	Local Income Tax
NOTES

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

OTHER REGULATORY LIABILITIES (Account 254)
Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Liabilities being amortized, show period of amortization.
			DEBITS
Line No.	Description and Purpose of Other Regulatory Liabilities (a)	Balance at Beginning of Current Quarter/Year (b)	Account Credited (c)	Amount (d)	Credits (e)	Balance at End of Current Quarter/Year (f)
1	Unrealized Gain on Forward Commitments		175/224	1,605,233	1,161,278	443,955
2	Unrealized Gain on Forward Commitments - Nettingof Trading Activities between Regulated Assets / Liabilities		175/224	1,161,278	1,605,233	443,955
3	Over Rec Dist Invest Rider
4	Over-Recovery Alternative Energy Rider (AER) Costs - Ohio - Case No. 16-1852-EL-SSO - Case No. 16-1853-EL-AAM
5	Ohio Rate Stabilization Plan (RSP) - Low Income Customer / Economic Recovery- Docket No. 04-169-EL-UNC	304,207	232	10,000		294,207
6	Bad Debt Rider Over-Recovery		426	245,493	7,742,755	7,497,262
7	DAPIR Over Recovery
8	Over Rcvrd Fuel Cost - LT - OH	15,220,828	254	15,220,828	32,226,739	32,226,739
9	PJM Transmission Enhancement Regulatory Liability	19,626,606	142/565	4,933,034		14,693,572
10	SFAS 109 Flow-Through Deferred Fed Inc Tax (FIT) Excess Deferred FIT - OCI	544,888,475	190/236/282/283/409/411	40,643,386	10,640,582	514,885,671
11	Over-Recovery Monongahela Power Litigation Termination - Case No. 05-765-EL-UNC	215,649				215,649
12	Over-Recovery Energy Efficiency / Peak Demand Reduction Rider (EE / PDR) - Case No. 16-1852-EL-SSO - Case No. 16-1853-EL-AAM	20,561,390	908	71,976	1,797,468	22,286,882
13	Deferred SIT	2,307,075			303	2,306,772
14	EE-PDR CHP Program Liability	1,971,055	232	629,065		1,341,990
15	Over Recovery OVEC PPA	14,807,910	555	8,827,820	41,095,787	47,075,877
16	Over-Recovery Enhanced Service Reliability Plan (ESRP) Costs - Ohio - Case No. 16-1852-EL-SSO, Case No. 16-1853-EL-AAM
17	Over-Recovery Fuel Costs - Ohio- Case No. 16-1852-EL-SSO- Case No. 16-1853-EL-AAM
18	Over-Recovery Fixed Costs Rider (FCR) - Ohio - Case No. 12-3254-EL-UNC
41	TOTAL	615,289,045		73,348,113	96,270,145	638,211,077

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

Electric Operating Revenues
The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages. Report below operating revenues for each prescribed account, and manufactured gas revenues in total. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.) See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.	Title of Account (a)	Operating Revenues Year to Date Quarterly/Annual (b)	Operating Revenues Previous year (no Quarterly) (c)	MEGAWATT HOURS SOLD Year to Date Quarterly/Annual (d)	MEGAWATT HOURS SOLD Amount Previous year (no Quarterly) (e)	AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly) (f)	AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly) (g)
1	SalesOfElectricityHeadingAbstract Sales of Electricity
2	ResidentialSalesAbstract (440) Residential Sales	1,806,582,854	1,586,465,519	14,430,135	14,546,502	1,320,046	1,314,084
3	CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales
4	CommercialSalesAbstract Small (or Comm.) (See Instr. 4)	944,917,101	724,889,271	16,013,323	15,036,325	187,209	185,446
5	IndustrialSalesAbstract Large (or Ind.) (See Instr. 4)	567,873,107	289,668,862	14,088,721	14,321,447	9,255	9,333
6	PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting	13,784,784	12,581,570	109,753	111,154	2,523	2,556
7	OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities	57,966	55,569	561	581	24	25
8	SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways
9	InterdepartmentalSalesAbstract (448) Interdepartmental Sales
10	SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers	(a) 3,333,215,811	2,613,660,791	44,642,493	44,016,009	1,519,057	1,511,444
11	SalesForResaleAbstract (447) Sales for Resale	195,797,396	108,891,211	2,749,396	2,521,794	3	3
12	SalesOfElectricityAbstract TOTAL Sales of Electricity	3,529,013,207	2,722,552,002	47,391,888	46,537,803	1,519,060	1,511,447
13	ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds	4,887,141
14	RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds	3,524,126,066	2,722,552,002	47,391,888	46,537,803	1,519,060	1,511,447
15	OtherOperatingRevenuesAbstract Other Operating Revenues
16	ForfeitedDiscounts (450) Forfeited Discounts	4,645,253	2,104,608
17	MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues	(b) 1,886,898	8,927,879
18	SalesOfWaterAndWaterPower (453) Sales of Water and Water Power
19	RentFromElectricProperty (454) Rent from Electric Property	45,946,255	49,621,575
20	InterdepartmentalRents (455) Interdepartmental Rents
21	OtherElectricRevenue (456) Other Electric Revenues	(c) 14,385,482	43,183,430
22	RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others	87,157,072	75,997,493
23	RegionalTransmissionServiceRevenues (457.1) Regional Control Service Revenues
24	MiscellaneousRevenue (457.2) Miscellaneous Revenues
25	OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues
26	OtherOperatingRevenues TOTAL Other Operating Revenues	154,020,960	179,834,983
27	ElectricOperatingRevenues TOTAL Electric Operating Revenues	3,678,147,026	2,902,386,985
Line12, column (b) includes $ 35,286,953 of unbilled revenues.
Line12, column (d) includes 142,268 MWH relating to unbilled revenues

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: SalesToUltimateConsumers


Details of Unmetered Sales
	Revenue	MWH	Average Customer
Residential	5,188,735.00	17,919.00	27,305.00
Commercial	11,325,252.00	48,638.00	16,720.00
Industrial	852,591.00	4,847.00	853.00
Public Street Lighting	15,166.00	70.00	25.00
Total	17,381,744.00	71,474.00	44,903.00

Total Sales to Ultimate Consumers include $1,309,550,775 of operating revenues for distribution service provided to Open Access Customers. Megawatt hours delivered to Open Access Customers were $28,190,076 and are included in the reported Megawatt hours sold on pg. 301 (d).

(b) Concept: MiscellaneousServiceRevenues

Customer Service Revenue including connects, reconnects, disconnects, temporary services and other charges billed to customers.


Description	YTD 2022	YTD 2021
Associated Business Development Revenues	5,771,383.00	(4,936,579.00)
Oth Elect Rev - Nonaffiliated	471,033.00	(767,563.00)
Oth Elect Rev - Affiliated	—	—
All Other (under $250,000 each)	(143,464.00)	(101,330.00)
Oth Elect Rev - DSM Program	83,510.00	(86,985.00)
LGR Rider Revenue	8,203,020.00	(37,290,973.00)
Amort of Defer Equity Inc	0.00	—
	14,385,482.00	(43,183,430.00)

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.	Description of Service (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46	TOTAL

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	GS	7	977	1	7,000	0.1396
2	OAD-AL Area Lighting	4,175	948,387			0.2272
3	OAD-GS-1
4	OAD-RR Residential Regular					0.0000
5	OAD-RR-1 Residential Low Usage	3,349,061	287,174,333	339,080	9,877	0.0857
6	OAD-RS Residential Service	2,657,056	223,111,468	242,538	10,955	0.0840
7	OAD-RSDM	204	19,414	22	9,273	0.0952
8	OL Outdoor Lighting	17,919	5,188,735			0.2896
9	RLM Res Opt Demand Rate	2,224	305,603	48	46,333	0.1374
10	RR Residential Regular	625	98,696	99	6,313	0.1579
11	RR-1 Residential Low Usage	11	2,326	4	2,750	0.2115
12	RS Residential Service	8,351,672	1,294,033,510	737,916	11,318	0.1549
13	RS-CPP Res Exp Critical Peak Pric					0.0000
14	RS-ES Res Energy Storage	3,585	510,672	223	16,076	0.1424
15	RS-TOD Gen Svc-Time of Day	862	124,430	63	13,683	0.1444
16	RS-TOD2 Res Exper-Time of Day					0.0000
17	RS-TOU	368	54,901	41	8,976	0.1492
18	Ohio Riders		23,581,144
19	Misc Adjustment		58,365
20	PEV	178	13,804	11	16,182	0.0776
41	TOTAL Billed Residential Sales	14,387,925	1,788,059,825	1,320,046	10,900	0.1243
42	TOTAL Unbilled Rev. (See Instr. 6)	42,210	18,523,029			0.4388
43	TOTAL	14,430,135	1,806,582,854	1,320,046	10,900	0.1252

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	EHG Electric Heating General	5,166	594,203	137	37,708	0.1150
2	Net Estimated Billings	2,113	8,730,133			4.1316
3	GS	4,586,919	386,850,406	46,395	98,867	0.0843
4	GS1	167,578	28,630,757	33,920	4,940	0.1709
5	GS-1 Gen Svc Fixed	218,566	23,513,122	31,235	6,997	0.1076
6	GS-2 Gen Svc Low	7,626	609,806	79	96,532	0.0800
7	GS-TOD2 Gen Exper Low-Time of					0.0000
8	GS-3 Gen Svc Medium	121	10,716			0.0886
9	GS-4 Gen Svc Large	1	600,231			600.2310
10	GS-TOD Gen Svc-Time of Day	20,710	2,481,109	425	48,729	0.1198
11	GS-FAIR County and Independent Fairs	3,800	299,005	127	29,921	0.0787
12	GS-TOU	24	3,954	2	12,000	0.1648
13	OAD-AL Area Lighting	31,960	5,043,115			0.1578
14	OAD-EHG Electric Heating General	6,230	420,364	187	33,316	0.0675
15	OAD-EHS	410	17,252	1	410,000	0.0421
16	OAD-GS	7,357,317	275,259,939	20,809	353,564	0.0374
17	OAD-GS-1 Gen Svc Fixed	210,911	19,982,194	33,246	6,344	0.0947
18	OAD-GS-2 Gen Svc Low	3,219,421	172,412,610	20,533	156,793	0.0536
19	OAD-GS-3 Gen Svc Medium	58	53,376
20	OAD-GS-4 Gen Svc Large					0.0000
21	OAD-RR-1	2	120			0.0000
22	OAD-RS		4			0.0000
23	OAD-SL	1,021	21,371	1	1,021,000	0.0209
24	OAD-SS School Service	23,361	1,250,415	92	253,924	0.0535
25	OL Outdoor Lighting	48,638	11,325,253			0.2328
26	RS Residential Service					0.0000
27	SL Street Lighting	17	1,829	2	8,500	0.1076
28	SS School Service	1,666	198,962	15	111,067	0.1194
29	PEV	29	4,756	3	9,667	0.1640
30	Ohio Riders		2,785,486
31	Misc Adjustment		21,166
41	TOTAL Billed Small or Commercial	15,913,305	934,222,036	187,209	85,003	0.0587
42	TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)	100,018	10,695,065			0.1069
43	TOTAL Small or Commercial	16,013,323	944,917,101	187,209	85,003	0.0590

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	EHG Electric Heating General	59	6,554	2	29,500	0.1111
2	Net Estimated Billings	151,911	10,160,194			0.0669
3	GS	7,148,111	333,231,188	1,913	3,736,597	0.0466
4	GS1	6,073	1,257,525	1,915	3,171	0.2071
5	GS-1 Gen Svc Fixed	14,725	1,212,662	643	22,900	0.0824
6	GS-2 Gen Svc Low	5,121	37,991	1	5,121,000	0.0074
7	GS-3 Gen Svc Medium	1	68			0.0680
8	GS-4 Gen Svc Large	36,103	1,205,875			0.0334
9	GS-TOD Gen Svc-Time of Day	657	79,082	9	73,000	0.1204
10	OAD-AL Area Lighting	2,965	354,676			0.1196
11	OAD-EHG Electric Heating General	523	47,900	10	52,300	0.0916
12	OAD-GS	6,132,746	171,184,162	1,434	4,276,671	0.0279
13	OAD-GS-1 Gen Svc Fixed	6,905	806,468	1,558	4,432	0.1168
14	OAD-GS-2 Gen Svc Low	882,208	47,618,790	1,770	498,423	0.0540
15	OAD-GS-3 Gen Svc Medium	122	22,391			0.1835
16	OAD-GS-4 Gen Svc Large					0.0000
17	OL Outdoor Lighting	4,847	852,591			0.1759
18	Ohio Riders		4,230,951
19	Misc Adjustment		1,976,983
41	TOTAL Billed Large (or Ind.) Sales	14,089,011	561,825,401	9,255	1,522,313	0.0399
42	TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)	290	6,047,706			20.8542
43	TOTAL Large (or Ind.)	14,088,721	567,873,107	9,255	1,522,313	0.0403

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41	TOTAL Billed Commercial and Industrial Sales
42	TOTAL Unbilled Rev. (See Instr. 6)
43	TOTAL

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	GS	1,071	132,705	30	35,700	0.1239
2	GS1	230	52,986	89	2,584	0.2304
3	GS-1 Gen Svc Fixed	6,706	410,911	156	42,987	0.0613
4	OAD-AL Area Lighting	149	23,358			0.1568
5	OAD-GS	2,229	113,235	14	159,214	0.0508
6	OAD-GS-1 Gen Svc Fixed	1,909	401,519	1,029	1,855	0.2103
7	OAD-GS-2 Gen Svc Low	2,487	128,005	23	108,130	0.0515
8	OAD-GS-3 Gen Svc Medium					0.0000
9	OAD-SL Street Lighting	78,874	9,377,852	725	108,792	0.1189
10	OL Outdoor Lighting	70	15,166			0.2167
11	SL Street Lighting	15,694	3,129,081	457	34,341	0.1994
12	Ohio Riders		21,301
13	Misc Adjustment		70
41	TOTAL Billed Public Street and Highway Lighting	109,419	13,763,587	2,523	43,369	0.1258
42	TOTAL Unbilled Rev. (See Instr. 6)	334	21,197			0.0635
43	TOTAL	109,753	13,784,784	2,523	43,369	0.1256

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	GS-1 Gen Svc Fixed	382	46,031	14	27,286	0.1205
2	SPECIAL - Street Lighting	182	12,029	10	18,200	0.0661
3	Ohio Riders		55
4	Misc Adjustment		5
41	TOTAL Billed Other Sales to Public Authorities	564	58,010	24	23,500	0.1029
42	TOTAL Unbilled Rev. (See Instr. 6)	3	44			0.0147
43	TOTAL	561	57,966	24	23,500	0.1033

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41	TOTAL Billed Provision For Rate Refunds
42	TOTAL Unbilled Rev. (See Instr. 6)
43	TOTAL		4,887,141

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
41	TOTAL Billed - All Accounts	44,500,224	3,297,928,859	1,519,057	29,295	0.0741
42	TOTAL Unbilled Rev. (See Instr. 6) - All Accounts	142,269	35,286,953			0.2480
43	TOTAL - All Accounts	44,642,493	3,333,215,812	1,519,057	29,295	0.0747

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

SALES FOR RESALE (Account 447)
Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326). Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k). In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24. Footnote entries as required and provide explanations following all required data.
					ACTUAL DEMAND (MW)			REVENUE
Line No.	Name of Company or Public Authority (Footnote Affiliations) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Average Monthly Billing Demand (MW) (d)	Average Monthly NCP Demand (e)	Average Monthly CP Demand (f)	Megawatt Hours Sold (g)	Demand Charges ($) (h)	Energy Charges ($) (i)	Other Charges ($) (j)	Total ($) (h+i+j) (k)
1	MUNICIPAL RESALE SALES	RQ	NOTE 1				0	372,098	372,050		49
2	(a) OHIO ECONOMIC DEVELOPMENT RIDER	OS	(b) NOTE 1				0			1,824	1,824
3	PJM INTERCONNECTION	OS	NOTE 1				2,741,237	2,260,092	199,959,047	7,236,061	194,983,078
4	OHIO EDISON - 217	RQ	OPCO-99				8,159	419,611	396,483		816,094
15	Subtotal - RQ						8,159	791,709	24,433		816,143
16	Subtotal-Non-RQ						2,741,237	2,260,092	199,959,047	7,237,885	194,981,254
17	Total						2,749,396	3,051,801	199,983,481	7,237,885	195,797,396

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityReceivingElectricityPurchasedForResale

The PUCO authorized OPCO to defer any over/under recovery of special billing arrangements equal to the difference between the ESP tariff rate and the rate paid by certain customers under the Economic Development Rider (EDR). Charges/Credits to the (EDR) regulatory asset are offset to retail revenues.

(b) Concept: RateScheduleTariffNumber

FERC Electric Tariff, First Revised Volume No. 5.

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

ELECTRIC OPERATION AND MAINTENANCE EXPENSES
If the amount for previous year is not derived from previously reported figures, explain in footnote.
Line No.	Account (a)	Amount for Current Year (b)	Amount for Previous Year (c) (c)
1	PowerProductionExpensesAbstract 1. POWER PRODUCTION EXPENSES
2	SteamPowerGenerationAbstract A. Steam Power Generation
3	SteamPowerGenerationOperationAbstract Operation
4	OperationSupervisionAndEngineeringSteamPowerGeneration (500) Operation Supervision and Engineering
5	FuelSteamPowerGeneration (501) Fuel
6	SteamExpensesSteamPowerGeneration (502) Steam Expenses
7	SteamFromOtherSources (503) Steam from Other Sources
8	SteamTransferredCredit (Less) (504) Steam Transferred-Cr.
9	ElectricExpensesSteamPowerGeneration (505) Electric Expenses
10	MiscellaneousSteamPowerExpenses (506) Miscellaneous Steam Power Expenses
11	RentsSteamPowerGeneration (507) Rents
12	Allowances (509) Allowances
13	SteamPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 4 thru 12)
14	SteamPowerGenerationMaintenanceAbstract Maintenance
15	MaintenanceSupervisionAndEngineeringSteamPowerGeneration (510) Maintenance Supervision and Engineering
16	MaintenanceOfStructuresSteamPowerGeneration (511) Maintenance of Structures
17	MaintenanceOfBoilerPlantSteamPowerGeneration (512) Maintenance of Boiler Plant
18	MaintenanceOfElectricPlantSteamPowerGeneration (513) Maintenance of Electric Plant
19	MaintenanceOfMiscellaneousSteamPlant (514) Maintenance of Miscellaneous Steam Plant
20	SteamPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 15 thru 19)
21	PowerProductionExpensesSteamPower TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)
22	NuclearPowerGenerationAbstract B. Nuclear Power Generation
23	NuclearPowerGenerationOperationAbstract Operation
24	OperationSupervisionAndEngineeringNuclearPowerGeneration (517) Operation Supervision and Engineering
25	NuclearFuelExpense (518) Fuel
26	CoolantsAndWater (519) Coolants and Water
27	SteamExpensesNuclearPowerGeneration (520) Steam Expenses
28	SteamFromOtherSourcesNuclearPowerGeneration (521) Steam from Other Sources
29	SteamTransferredCreditNuclearPowerGeneration (Less) (522) Steam Transferred-Cr.
30	ElectricExpensesNuclearPowerGeneration (523) Electric Expenses
31	MiscellaneousNuclearPowerExpenses (524) Miscellaneous Nuclear Power Expenses
32	RentsNuclearPowerGeneration (525) Rents
33	NuclearPowerGenerationOperationsExpense TOTAL Operation (Enter Total of lines 24 thru 32)
34	NuclearPowerGenerationMaintenanceAbstract Maintenance
35	MaintenanceSupervisionAndEngineeringNuclearPowerGeneration (528) Maintenance Supervision and Engineering
36	MaintenanceOfStructuresNuclearPowerGeneration (529) Maintenance of Structures
37	MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration (530) Maintenance of Reactor Plant Equipment
38	MaintenanceOfElectricPlantNuclearPowerGeneration (531) Maintenance of Electric Plant
39	MaintenanceOfMiscellaneousNuclearPlant (532) Maintenance of Miscellaneous Nuclear Plant
40	NuclearPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 35 thru 39)
41	PowerProductionExpensesNuclearPower TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)
42	HydraulicPowerGenerationAbstract C. Hydraulic Power Generation
43	HydraulicPowerGenerationOperationAbstract Operation
44	OperationSupervisionAndEngineeringHydraulicPowerGeneration (535) Operation Supervision and Engineering
45	WaterForPower (536) Water for Power
46	HydraulicExpenses (537) Hydraulic Expenses
47	ElectricExpensesHydraulicPowerGeneration (538) Electric Expenses
48	MiscellaneousHydraulicPowerGenerationExpenses (539) Miscellaneous Hydraulic Power Generation Expenses
49	RentsHydraulicPowerGeneration (540) Rents
50	HydraulicPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 44 thru 49)
51	HydraulicPowerGenerationContinuedAbstract C. Hydraulic Power Generation (Continued)
52	HydraulicPowerGenerationMaintenanceAbstract Maintenance
53	MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration (541) Mainentance Supervision and Engineering
54	MaintenanceOfStructuresHydraulicPowerGeneration (542) Maintenance of Structures
55	MaintenanceOfReservoirsDamsAndWaterways (543) Maintenance of Reservoirs, Dams, and Waterways
56	MaintenanceOfElectricPlantHydraulicPowerGeneration (544) Maintenance of Electric Plant
57	MaintenanceOfMiscellaneousHydraulicPlant (545) Maintenance of Miscellaneous Hydraulic Plant
58	HydraulicPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 53 thru 57)
59	PowerProductionExpensesHydraulicPower TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
60	OtherPowerGenerationAbstract D. Other Power Generation
61	OtherPowerGenerationOperationAbstract Operation
62	OperationSupervisionAndEngineeringOtherPowerGeneration (546) Operation Supervision and Engineering
63	Fuel (547) Fuel
64	GenerationExpenses (548) Generation Expenses
64.1	OperationOfEnergyStorageEquipment (548.1) Operation of Energy Storage Equipment
65	MiscellaneousOtherPowerGenerationExpenses (549) Miscellaneous Other Power Generation Expenses
66	RentsOtherPowerGeneration (550) Rents	267	23
67	OtherPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 62 thru 67)	267	23
68	OtherPowerGenerationMaintenanceAbstract Maintenance
69	MaintenanceSupervisionAndEngineeringOtherPowerGeneration (551) Maintenance Supervision and Engineering
70	MaintenanceOfStructures (552) Maintenance of Structures
71	MaintenanceOfGeneratingAndElectricPlant (553) Maintenance of Generating and Electric Plant
71.1	MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration (553.1) Maintenance of Energy Storage Equipment
72	MaintenanceOfMiscellaneousOtherPowerGenerationPlant (554) Maintenance of Miscellaneous Other Power Generation Plant
73	OtherPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 69 thru 72)
74	PowerProductionExpensesOtherPower TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)	267	23
75	OtherPowerSuplyExpensesAbstract E. Other Power Supply Expenses
76	PurchasedPower (555) Purchased Power	1,254,476,855	697,709,821
76.1	PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations	0
77	SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching
78	OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses	50,078,832	40,290,714
79	OtherPowerSupplyExpense TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)	1,304,555,687	738,000,535
80	PowerProductionExpenses TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)	1,304,555,420	738,000,558
81	TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES
82	TransmissionExpensesOperationAbstract Operation
83	OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering	14,438,302	11,004,767
85	LoadDispatchReliability (561.1) Load Dispatch-Reliability
86	LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System	333,527	350,630
87	LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling
88	SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services	165,310	109,603
89	ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development	283,745	498,427
90	TransmissionServiceStudies (561.6) Transmission Service Studies
91	GenerationInterconnectionStudies (561.7) Generation Interconnection Studies
92	ReliabilityPlanningAndStandardsDevelopmentServices (561.8) Reliability, Planning and Standards Development Services
93	StationExpensesTransmissionExpense (562) Station Expenses	1,269,134	1,367,156
93.1	OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment
94	OverheadLineExpense (563) Overhead Lines Expenses	77,463	75,697
95	UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses	267	125
96	TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others	630,945,490	532,406,631
97	MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses	4,522,443	12,824,524
98	RentsTransmissionElectricExpense (567) Rents	316,623	190,109
99	TransmissionOperationExpense TOTAL Operation (Enter Total of Lines 83 thru 98)	643,307,419	558,827,669
100	TransmissionMaintenanceAbstract Maintenance
101	MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering	57,509	65,921
102	MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures	116,325	54,523
103	MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware	(a) 20,848	25,207
104	MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software	539,810	423,077
105	MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment	211,492	148,379
106	MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant
107	MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment	5,353,524	5,858,529
107.1	MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment
108	MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines	22,485,572	19,442,375
109	MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines	154,163	197,501
110	MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant	71,725	99,413
111	TransmissionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 101 thru 110)	29,010,969	26,314,925
112	TransmissionExpenses TOTAL Transmission Expenses (Total of Lines 99 and 111)	672,318,388	585,142,594
113	RegionalMarketExpensesAbstract 3. REGIONAL MARKET EXPENSES
114	RegionalMarketExpensesOperationAbstract Operation
115	OperationSupervision (575.1) Operation Supervision
116	DayAheadAndRealTimeMarketAdministration (575.2) Day-Ahead and Real-Time Market Facilitation
117	TransmissionRightsMarketAdministration (575.3) Transmission Rights Market Facilitation
118	CapacityMarketAdministration (575.4) Capacity Market Facilitation
119	AncillaryServicesMarketAdministration (575.5) Ancillary Services Market Facilitation
120	MarketMonitoringAndCompliance (575.6) Market Monitoring and Compliance
121	MarketFacilitationMonitoringAndComplianceServices (575.7) Market Facilitation, Monitoring and Compliance Services	15,615	2,378
122	RentsRegionalMarketExpenses (575.8) Rents
123	RegionalMarketOperationExpense Total Operation (Lines 115 thru 122)	15,615	2,378
124	RegionalMarketExpensesMaintenanceAbstract Maintenance
125	MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses (576.1) Maintenance of Structures and Improvements
126	MaintenanceOfComputerHardware (576.2) Maintenance of Computer Hardware
127	MaintenanceOfComputerSoftware (576.3) Maintenance of Computer Software
128	MaintenanceOfCommunicationEquipmentRegionalMarketExpenses (576.4) Maintenance of Communication Equipment
129	MaintenanceOfMiscellaneousMarketOperationPlant (576.5) Maintenance of Miscellaneous Market Operation Plant
130	RegionalMarketMaintenanceExpense Total Maintenance (Lines 125 thru 129)
131	RegionalMarketExpenses TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)	15,615	2,378
132	DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES
133	DistributionExpensesOperationAbstract Operation
134	OperationSupervisionAndEngineeringDistributionExpense (580) Operation Supervision and Engineering	6,937,963	9,050,350
135	LoadDispatching (581) Load Dispatching	205	12
136	StationExpensesDistribution (582) Station Expenses	4,573,871	3,096,339
137	OverheadLineExpenses (583) Overhead Line Expenses	4,053,596	3,611,180
138	UndergroundLineExpenses (584) Underground Line Expenses	9,871,535	9,229,481
138.1	OperationOfEnergyStorageEquipmentDistribution (584.1) Operation of Energy Storage Equipment
139	StreetLightingAndSignalSystemExpenses (585) Street Lighting and Signal System Expenses	236,216	235,014
140	MeterExpenses (586) Meter Expenses	4,983,027	4,235,740
141	CustomerInstallationsExpenses (587) Customer Installations Expenses	118,830	103,421
142	MiscellaneousDistributionExpenses (588) Miscellaneous Expenses	39,355,079	35,031,349
143	RentsDistributionExpense (589) Rents	6,701,550	6,793,933
144	DistributionOperationExpensesElectric TOTAL Operation (Enter Total of Lines 134 thru 143)	76,831,873	71,179,977
145	DistributionExpensesMaintenanceAbstract Maintenance
146	MaintenanceSupervisionAndEngineering (590) Maintenance Supervision and Engineering	320,301	255,920
147	MaintenanceOfStructuresDistributionExpense (591) Maintenance of Structures	53,126	49,364
148	MaintenanceOfStationEquipment (592) Maintenance of Station Equipment	5,943,961	5,027,807
148.1	MaintenanceOfEnergyStorageEquipment (592.2) Maintenance of Energy Storage Equipment
149	MaintenanceOfOverheadLines (593) Maintenance of Overhead Lines	115,739,850	95,807,118
150	MaintenanceOfUndergroundLines (594) Maintenance of Underground Lines	7,297,361	8,131,446
151	MaintenanceOfLineTransformers (595) Maintenance of Line Transformers	2,001,789	1,923,940
152	MaintenanceOfStreetLightingAndSignalSystems (596) Maintenance of Street Lighting and Signal Systems	577,718	601,015
153	MaintenanceOfMeters (597) Maintenance of Meters	667,167	648,095
154	MaintenanceOfMiscellaneousDistributionPlant (598) Maintenance of Miscellaneous Distribution Plant	5,225,905	4,224,301
155	DistributionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 146 thru 154)	137,827,178	116,669,006
156	DistributionExpenses TOTAL Distribution Expenses (Total of Lines 144 and 155)	214,659,050	187,848,983
157	CustomerAccountsExpensesAbstract 5. CUSTOMER ACCOUNTS EXPENSES
158	CustomerAccountsExpensesOperationsAbstract Operation
159	SupervisionCustomerAccountExpenses (901) Supervision	1,358,059	1,464,289
160	MeterReadingExpenses (902) Meter Reading Expenses	2,882,181	2,867,976
161	CustomerRecordsAndCollectionExpenses (903) Customer Records and Collection Expenses	37,032,122	37,201,919
162	UncollectibleAccounts (904) Uncollectible Accounts	78,893,151	60,887,781
163	MiscellaneousCustomerAccountsExpenses (905) Miscellaneous Customer Accounts Expenses	134,568	225,126
164	CustomerAccountExpenses TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)	120,300,081	102,647,090
165	CustomerServiceAndInformationalExpensesAbstract 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166	CustomerServiceAndInformationalExpensesOperationAbstract Operation
167	SupervisionCustomerServiceAndInformationExpenses (907) Supervision	2,548,115	2,989,542
168	CustomerAssistanceExpenses (908) Customer Assistance Expenses	6,927,337	11,041,804
169	InformationalAndInstructionalAdvertisingExpenses (909) Informational and Instructional Expenses
170	MiscellaneousCustomerServiceAndInformationalExpenses (910) Miscellaneous Customer Service and Informational Expenses	147,363	166,546
171	CustomerServiceAndInformationExpenses TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)	9,622,815	14,197,893
172	SalesExpenseAbstract 7. SALES EXPENSES
173	SalesExpenseOperationAbstract Operation
174	SupervisionSalesExpense (911) Supervision	11,547	13,484
175	DemonstratingAndSellingExpenses (912) Demonstrating and Selling Expenses	227,767	262,626
176	AdvertisingExpenses (913) Advertising Expenses
177	MiscellaneousSalesExpenses (916) Miscellaneous Sales Expenses
178	SalesExpenses TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)	239,314	276,110
179	AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
180	AdministrativeAndGeneralExpensesOperationAbstract Operation
181	AdministrativeAndGeneralSalaries (920) Administrative and General Salaries	37,399,039	38,571,139
182	OfficeSuppliesAndExpenses (921) Office Supplies and Expenses	4,392,184	3,904,455
183	AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit	7,666,154	8,065,432
184	OutsideServicesEmployed (923) Outside Services Employed	13,442,167	7,931,184
185	PropertyInsurance (924) Property Insurance	2,540,023	2,538,539
186	InjuriesAndDamages (925) Injuries and Damages	6,773,118	5,596,546
187	EmployeePensionsAndBenefits (926) Employee Pensions and Benefits	4,687,512	3,559,093
188	FranchiseRequirements (927) Franchise Requirements
189	RegulatoryCommissionExpenses (928) Regulatory Commission Expenses	8,150,436	7,158,756
190	DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr.
191	GeneralAdvertisingExpenses (930.1) General Advertising Expenses	625,620	577,555
192	MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses	2,734,522	3,034,742
193	RentsAdministrativeAndGeneralExpense (931) Rents	1,824,881	1,859,189
194	AdministrativeAndGeneralOperationExpense TOTAL Operation (Enter Total of Lines 181 thru 193)	65,528,325	66,665,766
195	AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance
196	MaintenanceOfGeneralPlant (935) Maintenance of General Plant	18,794,980	15,183,811
197	AdministrativeAndGeneralExpenses TOTAL Administrative & General Expenses (Total of Lines 194 and 196)	84,323,305	81,849,577
198	OperationsAndMaintenanceExpensesElectric TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)	2,406,033,988	1,709,965,184

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: MaintenanceOfComputerHardwareTransmission

Allocated maintenance expenses for joint use computer hardware, computer software and communication equipment are determined by using various factors, which include number of remote terminal units, number of radios, number of employees, and other factors assigned to each function.

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

PURCHASED POWER (Account 555)
Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatthours shown on bills rendered to the respondent, excluding purchases for energy storage. Report in column (h) the megawatthours shown on bills rendered to the respondent for energy storage purchases. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. The data in columns (g) through (n) must be totaled on the last line of the schedule. The total amount in columns (g) and (h) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13. Footnote entries as required and provide explanations following all required data.
					Actual Demand (MW)				POWER EXCHANGES		COST/SETTLEMENT OF POWER
Line No.	NameOfCompanyOrPublicAuthorityProvidingPurchasedPower Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	RateScheduleTariffNumber Ferc Rate Schedule or Tariff Number (c)	AverageMonthlyBillingDemand Average Monthly Billing Demand (MW) (d)	AverageMonthlyNonCoincidentPeakDemand Average Monthly NCP Demand (e)	AverageMonthlyCoincidentPeakDemand Average Monthly CP Demand (f)	MegawattHoursPurchasedOtherThanStorage MegaWatt Hours Purchased (Excluding for Energy Storage) (g)	MegawattHoursPurchasedForEnergyStorage MegaWatt Hours Purchased for Energy Storage (h)	EnergyReceivedThroughPowerExchanges MegaWatt Hours Received (i)	EnergyDeliveredThroughPowerExchanges MegaWatt Hours Delivered (j)	DemandChargesOfPurchasedPower Demand Charges ($) (k)	EnergyChargesOfPurchasedPower Energy Charges ($) (l)	OtherChargesOfPurchasedPower Other Charges ($) (m)	SettlementOfPower Total (k+l+m) of Settlement ($) (n)
1	(a) AEP Energy Partners, Inc, (Auction)	OS					223,754					9,846,389		9,846,389
2	(b) AEPSC as Agent for AEP OPCo's	OS					133					3,838		3,838
3	Axpo U.S. LLC	OS					565,397					30,686,247		30,686,247
4	B.P. Energy Company	OS					2,666,568					132,392,265		132,392,265
5	(c) BlueStar Energy Services, Inc.	OS					518					19,156		19,156
6	Conoco Inc.	OS					716,438					45,230,264		45,230,264
7	Constellation Energy Generation, LLC	OS					2,245,686					141,180,078		141,180,078
8	Constellation NewEnergy, Inc.	OS					1,407,698					141,664,579		141,664,579
9	DTE Energy Trading Inc.	OS					771,632					47,569,043		47,569,043
10	DXT Commodities N America LLC	OS					463,232					30,826,874		30,826,874
11	Dynegy Marketing & Trade	OS					3,024,999					179,471,587		179,471,587
12	Enel Trading North America LLC	OS					887,795					47,969,433		47,969,433
13	Energy Harbor, LLC	OS					1,637,277					75,846,659		75,846,659
14	Exelon Generation - Power Team	OS					453,354					17,751,381		17,751,381
15	FirstEnergy Trading Services	OS					3,625					92,400		92,400
16	Fowler Ridge II Wind Farm LLC	OS					234,909					10,251,303		10,251,303
17	Hartree Partners, LP	OS					165,553					7,599,212		7,599,212
18	Interstate Gas Supply, Inc.	OS					102,164					5,633,701		5,633,701
19	(d) Mingo Junction Energy Center	OS					0					1,221		1,221
20	(e) NextEra Energy Power Mktg LLC	OS					208,838					14,240,190		14,240,190
21	Northern States Power Company	OS					1,182					29,558		29,558
22	Ohio Auction Cost Reconciliation Rider	OS					0					3,784,180		3,784,180
23	OVEC Power Scheduling	OS					2,201,806				77,507,681	106,599,053		184,106,734
24	Paulding Wind Farm II, LLC	OS					335,439					17,165,474		17,165,474
25	PJM Interconnection	OS					60,683					23,957,291		23,957,291
26	R L Downs	OS					0					17,046		17,046
27	TransAlta Energy Marketing US	OS					573,645					30,111,745		30,111,745
28	Vitol Inc.	OS					1,024,757					63,615,380		63,615,380
29	Wyandot Solar LLC	OS					12,707					1,027,976		1,027,976
15	TOTAL						19,867,121	0	0	0	77,507,681	1,176,969,175	0	1,254,476,856

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower

Related party auction purchases.

(b) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower

Related party auction purchases.

(d) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower

The PUCO approved OPCO’s proposal to establish an Auction Cost Reconciliation Rider (ACRR) beginning June 1, 2015 to recover previously deferred uncollected auction costs and variable auction energy and capacity purchased power costs.

(e) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower

Associated energy revenues are reported on Page 310-311.

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")

Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter.
Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c).
Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c).
In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided.
Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract.
Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain.
Report in column (i) and (j) the total megawatthours received and delivered.
In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (0) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively.
Footnote entries and provide explanations following all required data.

TRANSFER OF ENERGY

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS

Line No.

(a)

(b)

(c)

(d)

(e)

(f)

(g)

(h)

(i)

(j)

(k)

(l)

(m)

(n)

PJM Network Integ Trans Rev Whlsle

Various

FNO

(a)

PJM OATT

Various

12,212,562

PJM Network Integ Trans Serv

Various

FNO

PJM OATT

Various

49,402,885

PJM Trans Enhancement Rev

Various

FNO

PJM OATT

Various

8,885,464

PJM Trans Enhancement Rev Whlsle

Various

FNO

PJM OATT

Various

285,177

PJM Network Integ Rev - Affil

Various

FNO

PJM OATT

Various

589,721

PJM Point to Point Trans Service

Various

LFP

PJM OATT

Various

14,433,798

PJM Trans Owner Admin Revenue

Various

OLF

PJM OATT

Various

303,150

PJM Trans Owner Serv Rev Whlsle

Various

OLF

PJM OATT

Various

188,292

PJM Trans Distribution & Metering

Various

PJM OATT

Various

(b)

1,372,137

PJM Power Factor Credit Rev Nonaff

Various

PJM OATT

Various

(c)

466,770

TOTAL

85,809,607

491,442

1,838,907

87,157,072

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: RateScheduleTariffNumber

Effective October 1, 2004, the administration of the transmission tariff was turned over to PJM. PJM does not provide any detail except for the total revenue by the major classes listed. OATT (Open Access Transmission Tariff) 3rd Revised Volume No. 6

(b) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Per Proforma ILDSA (Interconnection and Local Delivery Service Agreement) AEP Tariff 3rd Revised Volume No. 6.

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

TRANSMISSION OF ELECTRICITY BY ISO/RTOs
Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a). In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided. In column (d) report the revenue amounts as shown on bills or vouchers. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No.	Payment Received by (Transmission Owner Name) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Total Revenue by Rate Schedule or Tariff (d)	Total Revenue (e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
40	TOTAL

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. Enter ""TOTAL"" in column (a) as the last line. Footnote entries and provide explanations following all required data.
			TRANSFER OF ENERGY		EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.	NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	TransmissionOfElectricityByOthersEnergyReceived MegaWatt Hours Received (c)	TransmissionOfElectricityByOthersEnergyDelivered MegaWatt Hours Delivered (d)	DemandChargesTransmissionOfElectricityByOthers Demand Charges ($) (e)	EnergyChargesTransmissionOfElectricityByOthers Energy Charges ($) (f)	OtherChargesTransmissionOfElectricityByOthers Other Charges ($) (g)	ChargesForTransmissionOfElectricityByOthers Total Cost of Transmission ($) (h)
1	Wheeling Power	LFP					(a) 2,739,195	2,739,195
2	PJM-Enhancements	OS					(b) 57,844,596	57,844,596
3	PJM-NITS	OS					(c) 567,292,649	567,292,649
4	PJM-Trans Owner Serv	OS					(d) 3,069,050	3,069,050
	TOTAL		0	0	0	0	630,945,490	630,945,490

FOOTNOTE DATA

(a) Concept: OtherChargesTransmissionOfElectricityByOthers

Affiliated Company

(b) Concept: OtherChargesTransmissionOfElectricityByOthers

Transmission Enhancement Charges and Credits (PJM OATT Schedule 12).

Network Integration Transmission Service Charges-NITS (PJM OATT Schedule H).

(d) Concept: OtherChargesTransmissionOfElectricityByOthers

Transmission Owner Charges and Credits (PJM OATT Tariff Sixth Revised Volume No. 1).

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.	Description (a)	Amount (b)
1	IndustryAssociationDues Industry Association Dues
2	NuclearPowerResearchExpenses Nuclear Power Research Expenses
3	OtherExperimentalAndGeneralResearchExpenses Other Experimental and General Research Expenses	1,946
4	PublicationAndDistributionExpensesForSecuritiesToStockholders Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities
5	OtherMiscellaneousGeneralExpenses Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6	Affiliated Billings (Net)	375,584
7	Associated Business Development	1,263,404
8	Utility Corp Borrowing Program Shared Costs	137,790
9	Corporate Contributions & Memberships	891,002
10	PJM Capacity Market Non-Performance Insurance	6,247
11	Ohio Broadband Initiative	8,366
12	Energy Efficiency/Peak Demand Reduction Program
13	Miscellaneous	50,183
46	MiscellaneousGeneralExpenses TOTAL	2,734,522

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
Report in section A for the year the amounts for: (b) Depreciation Expense (Account 403); (c) Depreciation Expense for Asset Retirement Costs (Account 403.1); (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405). Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year. Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used. In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used. For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type of mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
	A. Summary of Depreciation and Amortization Charges
Line No.	FunctionalClassificationAxis Functional Classification (a)	DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments Depreciation Expense (Account 403) (b)	DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments Depreciation Expense for Asset Retirement Costs (Account 403.1) (c)	AmortizationOfLimitedTermPlantOrProperty Amortization of Limited Term Electric Plant (Account 404) (d)	AmortizationOfOtherElectricPlant Amortization of Other Electric Plant (Acc 405) (e)	DepreciationAndAmortization Total (f)
1	Intangible Plant			45,469,547		45,469,547
2	Steam Production Plant
3	Nuclear Production Plant
4	Hydraulic Production Plant-Conventional
5	Hydraulic Production Plant-Pumped Storage
6	Other Production Plant
7	Transmission Plant	68,924,975				68,924,975
8	Distribution Plant	164,726,559				164,726,559
9	Regional Transmission and Market Operation
10	General Plant	14,624,293		443,263		15,067,556
11	Common Plant-Electric
12	TOTAL	248,275,827		45,912,810		294,188,637

B. Basis for Amortization Charges
Section A Line 1 Column D represents amortization of capitalized software development costs over a 5 year life and costs associated with the Oracle strategic partnership which are over a 10 year life. Section A Line 10, Column D represents amortization of leasehold improvements to equipment and structures over the life of the lease.

	C. Factors Used in Estimating Depreciation Charges
Line No.	AccountNumberFactorsUsedInEstimatingDepreciationCharges Account No. (a)	DepreciablePlantBase Depreciable Plant Base (in Thousands) (b)	UtilityPlantEstimatedAverageServiceLife Estimated Avg. Service Life (c)	UtilityPlantNetSalvageValuePercentage Net Salvage (Percent) (d)	UtilityPlantAppliedDepreciationRate Applied Depr. Rates (Percent) (e)	MortalityCurveType Mortality Curve Type (f)	UtilityPlantWeightedAverageRemainingLife Average Remaining Life (g)
12	TRANSMISSION
13	352	151.377
14	352.15	0.323
15	353	1,523.98
16	353.15	12.459
17	353.16	25.15
18	354	3.327
19	354.15	21.597
20	354 - All Other	170.899
21	355	249.532
22	355.15	1.945
23	355 - All Other	267.906
24	356	162.466
25	356.15	17.475
26	356.16	2.065
27	356 - All Other	335.739
28	357	0.495
29	357 - All Other	15.756
30	358	1.194
31	358 - All Other	33.636
32	358.16	0.032
33	TOTAL TRANSMISSION	2,997.353
34	DISTRIBUTION
35	361	63.495
36	362	1,041.568
37	362.16	23.744
38	363	5.163
39	364	957.782
40	365	1,177.719
41	366	477.842
42	367	832.567
43	368	944.886
44	369	382.928
45	370	94.303
46	370.16	180.877
47	371	66.737
48	371 - AMI	0.095
49	372	0.103
50	373	54.975
51	TOTAL DISTRIBUTION	6,304.784
52	GENERAL PLANT
53	390	324.385
54	391	25.037
55	392	0.49
56	393	1.52
57	394	58.004
58	395	0.47
59	396	0.003
60	397	217.131
61	397.16	15.878
62	398	8.588
63	TOTAL GENERAL PLANT	651.506
64	DEPRECIABLE SUM	9,953.643

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

REGULATORY COMMISSION EXPENSES
Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous years, if being amortized) relating to format cases before a regulatory body, or cases in which such a body was a party. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization of amounts deferred in previous years. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization. List in columns (f), (g), and (h), expenses incurred during the year which were charged currently to income, plant, or other accounts. Minor items (less than $25,000) may be grouped.
						EXPENSES INCURRED DURING YEAR				AMORTIZED DURING YEAR
						CURRENTLY CHARGED TO
Line No.	RegulatoryCommissionDescription Description (Furnish name of regulatory commission or body the docket or case number and a description of the case) (a)	RegulatoryExpensesAssessedByRegulatoryCommission Assessed by Regulatory Commission (b)	RegulatoryExpensesOfUtility Expenses of Utility (c)	RegulatoryCommissionExpensesAmount Total Expenses for Current Year (d)	OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 at Beginning of Year (e)	NameOfDepartmentRegulatoryCommissionExpensesCharged Department (f)	AccountNumberRegulatoryCommissionExpensesCharged Account No. (g)	RegulatoryComissionExpensesIncurredAndCharged Amount (h)	RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets Deferred to Account 182.3 (i)	DeferredRegulatoryCommissionExpensesAmortizedInContraAccount Contra Account (j)	DeferredRegulatoryCommissionExpensesAmortized Amount (k)	OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 End of Year (l)
1	PUCO charge for funding the cost of hearing	111,309		111,309		Electric	928	111,309
2	and review process for long-term forecasts.
3	2018 AEP Ohio Solar Filing		343	343		Electric	928	343
4	AEP Ohio Electric Security Plan III		10,996	10,996		Electric	928	10,996
5	Ohio Distribution Investment Rider		322,906	322,906		Electric	928	322,906
6	Ohio SEET Filings		11,193	11,193		Electric	928	11,193
7	FERC Formula Rate Filing		132,543	132,543		Electric	928	32,258
8	Alternative Energy Rider		145,182	145,182		Electric	928	145,182
9	AEP Ohio Purchased Fuel Adjustment Audit		243,335	243,335
10	Miscellaneous Items - < $25K		324,392	324,392		Electric	928	668,012
11	AEP Ohio 2020 Base Rate Case		81,879	81,879	73,803	Electric	928	65,888		928	15,991	57,812
12	AEP Ohio Grid Smart Rider
13	2021 Quadrennial SEET Filing		6,752	6,752		Electric	928	6,752
14	State Commission Fees		5,867,924	5,867,924		Electric	928	5,867,924
15	AEP Ohio ESP V Filing		485,634	485,634		Electric	928	485,634
16	NEP Submetering Complaint		382,302	382,302		Electric	928	382,302
17	Ohio Purchased Power Agreement		23,746	23,746		Electric	928	23,746
46	TOTAL	111,309	8,039,127	8,150,436	73,803			8,134,445			15,991	57,812

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D and D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(Identify recipient regardless of affiliation.) For any R, D and D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts). Indicate in column (a) the applicable classification, as shown below: Classifications: Electric R, D and D Performed Internally: Generation hydroelectric Recreation fish and wildlife Other hydroelectric Fossil-fuel steam Internal combustion or gas turbine Nuclear Unconventional generation Siting and heat rejection Transmission Overhead Underground Distribution Regional Transmission and Market Operation Environment (other than equipment) Other (Classify and include items in excess of $50,000.) Total Cost Incurred Electric, R, D and D Performed Externally: Research Support to the electrical Research Council or the Electric Power Research Institute Research Support to Edison Electric Institute Research Support to Nuclear Power Groups Research Support to Others (Classify) Total Cost Incurred Include in column (c) all R, D and D items performed internally and in column (d) those items performed outside the company costing $50,000 or more, briefly describing the specific area of R, D and D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D and D activity. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year, listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e). Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, Development, and Demonstration Expenditures, Outstanding at the end of the year. If costs have not been segregated for R, D and D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by ""Est."" Report separately research and related testing facilities operated by the respondent.
					AMOUNTS CHARGED IN CURRENT YEAR
Line No.	ResearchDevelopmentAndDemonstrationClassification Classification (a)	ResearchDevelopmentAndDemonstrationDescription Description (b)	ResearchDevelopmentAndDemonstrationCostsIncurredInternally Costs Incurred Internally Current Year (c)	ResearchDevelopmentAndDemonstrationCostsIncurredExternally Costs Incurred Externally Current Year (d)	AccountNumberForResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Account (e)	ResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Amount (f)	ResearchDevelopmentAndDemonstrationExpenditures Unamortized Accumulation (g)
1	A.(1) Generation
2	(e)Unconventional Generation	1 item under $50,000
3	A.(2) Transmission	1 item under $50,000	14,009		566	14,009
4	A.(3) Distribution	1 items under $50,000	26,775		588	26,775
5	A.(6)Other	1 items under $50,000	179		566,588	179
6		Corporate Technology Prog Mgmt	35,423		566,588	35,423
7	(f) AMI Test Bed Development	1 item under $50,000	3,647		588	3,647
8	(g) DTC Walnut Maintenance	1 item under $50,000	6,347		566,588	6,347
9	A (7) TOTAL COSTS INCURRED INTERNALLY		86,380			86,380
10	ELECTRIC UTILITY RESEARCH, DEVELOPMENT &
11	DEMONSTRATION PERFORMED EXTERNALLY
12	B. Memberships	5 Items under $50,000		113,923	566,588	113,923
13	B.(1) Electric Power Research Institute	EPRI Research Portfolio		674,085	566,588	674,085
14		Electric Transportation		394,493	588	394,493
15		IT - EPRI Annual Research Port		77,982	566,588	77,982
16		Low Carbon Resource Initiative		141,274	566,588	141,274
17		T Line Robots - Reclass
18		7 items under $50,000		7,724	566,588	7,724
19	B. (4) Substation Equipment Management	1 items under $50,000
20	B(5) TOTAL COSTS INCURRED EXTERNALLY			1,409,481		1,409,481

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

DISTRIBUTION OF SALARIES AND WAGES
Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used.
Line No.	Classification (a)	Direct Payroll Distribution (b)	Allocation of Payroll Charged for Clearing Accounts (c)	Total (d)
1	SalariesAndWagesElectricAbstract Electric
2	SalariesAndWagesElectricOperationAbstract Operation
3	SalariesAndWagesElectricOperationProduction Production	8,937
4	SalariesAndWagesElectricOperationTransmission Transmission	78,550
5	SalariesAndWagesElectricOperationRegionalMarket Regional Market
6	SalariesAndWagesElectricOperationDistribution Distribution	24,598,722
7	SalariesAndWagesElectricOperationCustomerAccounts Customer Accounts	8,249,947
8	SalariesAndWagesElectricOperationCustomerServiceAndInformational Customer Service and Informational	4,375,310
9	SalariesAndWagesElectricOperationSales Sales	11,165
10	SalariesAndWagesElectricOperationAdministrativeAndGeneral Administrative and General	550,543
11	SalariesAndWagesElectricOperation TOTAL Operation (Enter Total of lines 3 thru 10)	36,772,088
12	SalariesAndWagesElectricMaintenanceAbstract Maintenance
13	SalariesAndWagesElectricMaintenanceProduction Production	992
14	SalariesAndWagesElectricMaintenanceTransmission Transmission	26,749
15	SalariesAndWagesElectricMaintenanceRegionalMarket Regional Market
16	SalariesAndWagesElectricMaintenanceDistribution Distribution	37,506,111
17	SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral Administrative and General	3,711,530
18	SalariesAndWagesElectricMaintenance TOTAL Maintenance (Total of lines 13 thru 17)	41,245,382
19	SalariesAndWagesElectricOperationAndMaintenanceAbstract Total Operation and Maintenance
20	SalariesAndWagesElectricProduction Production (Enter Total of lines 3 and 13)	9,929
21	SalariesAndWagesElectricTransmission Transmission (Enter Total of lines 4 and 14)	105,299
22	SalariesAndWagesElectricRegionalMarket Regional Market (Enter Total of Lines 5 and 15)
23	SalariesAndWagesElectricDistribution Distribution (Enter Total of lines 6 and 16)	62,104,833
24	SalariesAndWagesElectricCustomerAccounts Customer Accounts (Transcribe from line 7)	8,249,947
25	SalariesAndWagesElectricCustomerServiceAndInformational Customer Service and Informational (Transcribe from line 8)	4,375,310
26	SalariesAndWagesElectricSales Sales (Transcribe from line 9)	11,165
27	SalariesAndWagesElectricAdministrativeAndGeneral Administrative and General (Enter Total of lines 10 and 17)	3,160,987
28	SalariesAndWagesElectricOperationAndMaintenance TOTAL Oper. and Maint. (Total of lines 20 thru 27)	78,017,470	5,910,833	83,928,303
29	SalariesAndWagesGasAbstract Gas
30	SalariesAndWagesGasOperationAbstract Operation
31	SalariesAndWagesGasOperationProductionManufacturedGas Production - Manufactured Gas
32	SalariesAndWagesGasOperationProductionNaturalGas Production-Nat. Gas (Including Expl. And Dev.)
33	SalariesAndWagesGasOperationOtherGasSupply Other Gas Supply
34	SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing Storage, LNG Terminaling and Processing
35	SalariesAndWagesGasOperationTransmission Transmission
36	SalariesAndWagesGasOperationDistribution Distribution
37	SalariesAndWagesGasCustomerAccounts Customer Accounts
38	SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational
39	SalariesAndWagesGasSales Sales
40	SalariesAndWagesGasOperationAdministrativeAndGeneral Administrative and General
41	SalariesAndWagesGasOperation TOTAL Operation (Enter Total of lines 31 thru 40)
42	SalariesAndWagesGasMaintenanceAbstract Maintenance
43	SalariesAndWagesGasMaintenanceProductionManufacturedGas Production - Manufactured Gas
44	SalariesAndWagesGasMaintenanceProductionNaturalGas Production-Natural Gas (Including Exploration and Development)
45	SalariesAndWagesGasMaintenanceOtherGasSupply Other Gas Supply
46	SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing
47	SalariesAndWagesGasMaintenanceTransmission Transmission
48	SalariesAndWagesGasMaintenanceDistribution Distribution
49	SalariesAndWagesGasMaintenanceAdministrativeAndGeneral Administrative and General
50	SalariesAndWagesGasMaintenance TOTAL Maint. (Enter Total of lines 43 thru 49)
51	SalariesAndWagesGasOperationAndMaintenanceAbstract Total Operation and Maintenance
52	SalariesAndWagesGasProductionManufacturedGas Production-Manufactured Gas (Enter Total of lines 31 and 43)
53	SalariesAndWagesGasProductionNaturalGas Production-Natural Gas (Including Expl. and Dev.) (Total lines 32,
54	SalariesAndWagesGasOtherGasSupply Other Gas Supply (Enter Total of lines 33 and 45)
55	SalariesAndWagesGasStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing (Total of lines 31 thru
56	SalariesAndWagesGasTransmission Transmission (Lines 35 and 47)
57	SalariesAndWagesGasDistribution Distribution (Lines 36 and 48)
58	SalariesAndWagesGasCustomerAccounts Customer Accounts (Line 37)
59	SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational (Line 38)
60	SalariesAndWagesGasSales Sales (Line 39)
61	SalariesAndWagesGasAdministrativeAndGeneral Administrative and General (Lines 40 and 49)
62	SalariesAndWagesGasOperationAndMaintenance TOTAL Operation and Maint. (Total of lines 52 thru 61)
63	SalariesAndWagesOtherUtilityDepartmentsAbstract Other Utility Departments
64	SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance Operation and Maintenance
65	SalariesAndWagesOperationsAndMaintenance TOTAL All Utility Dept. (Total of lines 28, 62, and 64)	78,017,470	5,910,833	83,928,303
66	SalariesAndWagesUtilityPlantAbstract Utility Plant
67	SalariesAndWagesUtilityPlantConstructionAbstract Construction (By Utility Departments)
68	SalariesAndWagesUtilityPlantConstructionElectricPlant Electric Plant	82,243,309	6,230,995	88,474,304
69	SalariesAndWagesUtilityPlantConstructionGasPlant Gas Plant
70	SalariesAndWagesUtilityPlantConstructionOther Other (provide details in footnote):
71	SalariesAndWagesUtilityPlantConstruction TOTAL Construction (Total of lines 68 thru 70)	82,243,309	6,230,995	88,474,304
72	SalariesAndWagesPlantRemovalAbstract Plant Removal (By Utility Departments)
73	SalariesAndWagesPlantRemovalElectricPlant Electric Plant	12,734,645	964,814	13,699,459
74	SalariesAndWagesPlantRemovalGasPlant Gas Plant
75	SalariesAndWagesPlantRemovalOther Other (provide details in footnote):
76	SalariesAndWagesPlantRemoval TOTAL Plant Removal (Total of lines 73 thru 75)	12,734,645	964,814	13,699,459
77	SalariesAndWagesOtherAccountsAbstract Other Accounts (Specify, provide details in footnote):
78	SalariesAndWagesOtherAccountsDescription Other Accounts (Specify, provide details in footnote):
79	SalariesAndWagesOtherAccountsDescription 163 - Stores Expense Undistributed	7,812,277	7,812,277
80	SalariesAndWagesOtherAccountsDescription 165 - Other Prepayments
81	SalariesAndWagesOtherAccountsDescription 182 - Other Regulatory Assets
82	SalariesAndWagesOtherAccountsDescription 183 - Prelim Survey
83	SalariesAndWagesOtherAccountsDescription 184 - Clearing Accounts	5,294,365	5,294,365
84	SalariesAndWagesOtherAccountsDescription 185 - ODD Temporary Facilities	407,443		407,443
85	SalariesAndWagesOtherAccountsDescription 186 - Misc Deferred Debits	1,482,656		1,482,656
86	SalariesAndWagesOtherAccountsDescription 188 - Research & Development
87	SalariesAndWagesOtherAccountsDescription 228 - RAD Waste Accrual
88	SalariesAndWagesOtherAccountsDescription 242 - Misc Current & Accrued Liab
89	SalariesAndWagesOtherAccountsDescription 254 - Ohio Reliability
90	SalariesAndWagesOtherAccountsDescription 401 - Operation Expense - Nonassociated
91	SalariesAndWagesOtherAccountsDescription 402 - Maintenance Exp
92	SalariesAndWagesOtherAccountsDescription 407 - Regulatory Debits
93	SalariesAndWagesOtherAccountsDescription 417 - Misc Exp
94	SalariesAndWagesOtherAccountsDescription 451 - Misc Service Rev - Nonaffil
95	SalariesAndWagesOtherAccountsDescription 456 - Other Electric Revenue
95	SalariesAndWagesOtherAccounts TOTAL Other Accounts	14,996,741	13,106,642	1,890,099
96	SalariesAndWagesGeneralExpense TOTAL SALARIES AND WAGES	187,992,165		187,992,165

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

COMMON UTILITY PLANT AND EXPENSES
Describe the property carried in the utility's accounts as common utility plant and show the book cost of such plant at end of year classified by accounts as provided by Electric Plant Instruction 13, Common Utility Plant, of the Uniform System of Accounts. Also show the allocation of such plant costs to the respective departments using the common utility plant and explain the basis of allocation used, giving the allocation factors. Furnish the accumulated provisions for depreciation and amortization at end of year, showing the amounts and classifications of such accumulated provisions, and amounts allocated to utility departments using the common utility plant to which such accumulated provisions relate, including explanation of basis of allocation and factors used. Give for the year the expenses of operation, maintenance, rents, depreciation, and amortization for common utility plant classified by accounts as provided by the Uniform System of Accounts. Show the allocation of such expenses to the departments using the common utility plant to which such expenses are related. Explain the basis of allocation used and give the factors of allocation. Give date of approval by the Commission for use of the common utility plant classification and reference to the order of the Commission or other authorization.

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No.	Description of Item(s) (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1	Energy
2	Net Purchases (Account 555)				1,729
2.1	Net Purchases (Account 555.1)
3	Net Sales (Account 447)				194,670,836
4	Transmission Rights
5	Ancillary Services				20,065,952
6	Other Items (list separately)
7	Congestion
8	Operating Reserves				594,193
9	Transmission Purchase Expense				3
10	Transmission Losses				1
11	Meter Corrections				647,904
12	Inadvertent
13	Capacity Credits
14	Miscellaneous
46	TOTAL				173,361,060

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

PURCHASES AND SALES OF ANCILLARY SERVICES
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff. In columns for usage, report usage-related billing determinant and the unit of measure. On Line 1 columns (b), (c), (d), and (e) report the amount of ancillary services purchased and sold during the year. On Line 2 columns (b), (c), (d), and (e) report the amount of reactive supply and voltage control services purchased and sold during the year. On Line 3 columns (b), (c), (d), and (e) report the amount of regulation and frequency response services purchased and sold during the year. On Line 4 columns (b), (c), (d), and (e) report the amount of energy imbalance services purchased and sold during the year. On Lines 5 and 6, columns (b), (c), (d), and (e) report the amount of operating reserve spinning and supplement services purchased and sold during the period. On Line 7 columns (b), (c), (d), and (e) report the total amount of all other types ancillary services purchased or sold during the year. Include in a footnote and specify the amount for each type of other ancillary service provided.
		Amount Purchased for the Year			Amount Sold for the Year
		Usage - Related Billing Determinant			Usage - Related Billing Determinant
Line No.	Type of Ancillary Service (a)	Number of Units (b)	Unit of Measure (c)	Dollar (d)	Number of Units (e)	Unit of Measure (f)	Dollars (g)
1	Scheduling, System Control and Dispatch	(a) 0
2	Reactive Supply and Voltage
3	Regulation and Frequency Response
4	Energy Imbalance
5	Operating Reserve - Spinning
6	Operating Reserve - Supplement
7	Other
8	Total (Lines 1 thru 7)

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: AncillaryServicesPurchasedNumberOfUnits

The final grandfathered contracts (under the AEP OATT) expired 12/31/2010. Currently, services are provided under the SPP and PJM OATTs.

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

MONTHLY TRANSMISSION SYSTEM PEAK LOAD
Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No.	Month (a)	Monthly Peak MW - Total (b)	Day of Monthly Peak (c)	Hour of Monthly Peak (d)	Firm Network Service for Self (e)	Firm Network Service for Others (f)	Long-Term Firm Point-to-point Reservations (g)	Other Long-Term Firm Service (h)	Short-Term Firm Point-to-point Reservation (i)	Other Service (j)
	NAME OF SYSTEM: 0
1	January	(a) 0
2	February
3	March
4	Total for Quarter 1				0	0	0	0	0	0
5	April
6	May
7	June
8	Total for Quarter 2				0	0	0	0	0	0
9	July
10	August
11	September
12	Total for Quarter 3				0	0	0	0	0	0
13	October
14	November
15	December
16	Total for Quarter 4				0	0	0	0	0	0
17	Total				0	0	0	0	0	0

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: MonthlyPeakLoadExcludingIsoAndRto

Ohio Power Company's transmission service is administered through an RTO/ISO and requested information is not available on an individual operating company basis.

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

Monthly ISO/RTO Transmission System Peak Load
Report the monthly peak load on the respondent's transmission system. If the Respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Column (c) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (i) by month the system’s transmission usage by classification. Amounts reported as Through and Out Service in Column (g) are to be excluded from those amounts reported in Columns (e) and (f). Amounts reported in Column (j) for Total Usage is the sum of Columns (h) and (i).
Line No.	Month (a)	Monthly Peak MW - Total (b)	Day of Monthly Peak (c)	Hour of Monthly Peak (d)	Import into ISO/RTO (e)	Exports from ISO/RTO (f)	Through and Out Service (g)	Network Service Usage (h)	Point-to-Point Service Usage (i)	Total Usage (j)
	NAME OF SYSTEM: 0
1	January
2	February
3	March
4	Total for Quarter 1				0	0	0	0	0	0
5	April
6	May
7	June
8	Total for Quarter 2				0	0	0	0	0	0
9	July
10	August
11	September
12	Total for Quarter 3				0	0	0	0	0	0
13	October
14	November
15	December
16	Total for Quarter 4				0	0	0	0	0	0
17	Total Year to Date/Year				0	0	0	0	0	0

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2023-04-12

Year/Period of Report

End of:

2022

ELECTRIC ENERGY ACCOUNT
Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year.
Line No.	Item (a)	MegaWatt Hours (b)	Line No.	Item (a)	MegaWatt Hours (b)
1	SOURCES OF ENERGY		21	DISPOSITION OF ENERGY
2	Generation (Excluding Station Use):		22	Sales to Ultimate Consumers (Including Interdepartmental Sales)	44,642,493
3	Steam		23	Requirements Sales for Resale (See instruction 4, page 311.)	8,159
4	Nuclear		24	Non-Requirements Sales for Resale (See instruction 4, page 311.)	2,741,237
5	Hydro-Conventional		25	Energy Furnished Without Charge	(a) 28,190,076
6	Hydro-Pumped Storage		26	Energy Used by the Company (Electric Dept Only, Excluding Station Use)
7	Other		27	Total Energy Losses	665,308
8	Less Energy for Pumping		27.1	Total Energy Stored
9	Net Generation (Enter Total of lines 3 through 8)	0	28	TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES	19,867,121
10	Purchases (other than for Energy Storage)	19,867,121
10.1	Purchases for Energy Storage	0
11	Power Exchanges:
12	Received	0
13	Delivered	0
14	Net Exchanges (Line 12 minus line 13)	0
15	Transmission For Other (Wheeling)
16	Received
17	Delivered
18	Net Transmission for Other (Line 16 minus line 17)	0
19	Transmission By Others Losses
20	TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19)	19,867,121

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2023-04-12

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: NonChargedEnergy

Represents Megawatt Hours included in Line 22, Sales to Ultimate Customers, that were delivered and billed to shopping customers and provided by external suppliers.

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

MONTHLY PEAKS AND OUTPUT
Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system. Report in column (b) by month the system’s output in Megawatt hours for each month. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).
Line No.	MonthAxis Month (a)	EnergyActivity Total Monthly Energy (b)	NonRequiredSalesForResaleEnergy Monthly Non-Requirement Sales for Resale & Associated Losses (c)	MonthlyPeakLoad Monthly Peak - Megawatts (d)	DayOfMonthlyPeak Monthly Peak - Day of Month (e)	HourOfMonthlyPeak Monthly Peak - Hour (f)
	NAME OF SYSTEM: 0
29	January	1,748,938	292,996	2,814	29	9
30	February	1,510,974	262,567	2,794	14	19
31	March	1,420,671	217,920	2,413	13	10
32	April	1,304,106	222,399	2,189	24	19
33	May	1,237,283	216,532	2,580	31	19
34	June	1,567,611	284,769	2,918	22	19
35	July	1,721,459	228,631	3,137	19	19
36	August	1,819,959	247,932	3,233	29	17
37	September	1,696,958	198,344	3,177	21	18
38	October	1,747,646	163,680	2,626	18	21
39	November	1,841,574	223,777	3,113	18	18
40	December	2,249,942	284,048	3,872	23	11
41	Total	19,867,121	2,843,595

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

Steam Electric Generating Plant Statistics

1. Report data for plant in Service only.
2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants.
3. Indicate by a footnote any plant leased or operated as a joint facility.
4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.
5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.
6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mct.
7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20.
8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned.
9. Items under Cost of Plant are based on USofA accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.
10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.
11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.
12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant.

Line No.	Item (a)	Plant Name: 0
1	PlantKind Kind of Plant (Internal Comb, Gas Turb, Nuclear)
2	PlantConstructionType Type of Constr (Conventional, Outdoor, Boiler, etc)
3	YearPlantOriginallyConstructed Year Originally Constructed
4	YearLastUnitOfPlantInstalled Year Last Unit was Installed
5	InstalledCapacityOfPlant Total Installed Cap (Max Gen Name Plate Ratings-MW)
6	NetPeakDemandOnPlant Net Peak Demand on Plant - MW (60 minutes)
7	PlantHoursConnectedToLoad Plant Hours Connected to Load
8	NetContinuousPlantCapability Net Continuous Plant Capability (Megawatts)
9	NetContinuousPlantCapabilityNotLimitedByCondenserWater When Not Limited by Condenser Water
10	NetContinuousPlantCapabilityLimitedByCondenserWater When Limited by Condenser Water
11	PlantAverageNumberOfEmployees Average Number of Employees
12	NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh
13	CostOfLandAndLandRightsSteamProduction Cost of Plant: Land and Land Rights
14	CostOfStructuresAndImprovementsSteamProduction Structures and Improvements
15	CostOfEquipmentSteamProduction Equipment Costs
16	AssetRetirementCostsSteamProduction Asset Retirement Costs
17	CostOfPlant Total cost (total 13 thru 20)
18	CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 17/5) Including
19	OperationSupervisionAndEngineeringExpense Production Expenses: Oper, Supv, & Engr
20	FuelSteamPowerGeneration Fuel
21	CoolantsAndWater Coolants and Water (Nuclear Plants Only)
22	SteamExpensesSteamPowerGeneration Steam Expenses
23	SteamFromOtherSources Steam From Other Sources
24	SteamTransferredCredit Steam Transferred (Cr)
25	ElectricExpensesSteamPowerGeneration Electric Expenses
26	MiscellaneousSteamPowerExpenses Misc Steam (or Nuclear) Power Expenses
27	RentsSteamPowerGeneration Rents
28	Allowances Allowances
29	MaintenanceSupervisionAndEngineeringSteamPowerGeneration Maintenance Supervision and Engineering
30	MaintenanceOfStructuresSteamPowerGeneration Maintenance of Structures
31	MaintenanceOfBoilerPlantSteamPowerGeneration Maintenance of Boiler (or reactor) Plant
32	MaintenanceOfElectricPlantSteamPowerGeneration Maintenance of Electric Plant
33	MaintenanceOfMiscellaneousSteamPlant Maintenance of Misc Steam (or Nuclear) Plant
34	PowerProductionExpensesSteamPower Total Production Expenses	0
35	ExpensesPerNetKilowattHour Expenses per Net kWh

35	FuelKindAxis Plant Name
36	FuelKind Fuel Kind
37	FuelUnit Fuel Unit
38	QuantityOfFuelBurned Quantity (Units) of Fuel Burned
39	FuelBurnedAverageHeatContent Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)
40	AverageCostOfFuelPerUnitAsDelivered Avg Cost of Fuel/unit, as Delvd f.o.b. during year
41	AverageCostOfFuelPerUnitBurned Average Cost of Fuel per Unit Burned
42	AverageCostOfFuelBurnedPerMillionBritishThermalUnit Average Cost of Fuel Burned per Million BTU
43	AverageCostOfFuelBurnedPerKilowattHourNetGeneration Average Cost of Fuel Burned per kWh Net Gen
44	AverageBritishThermalUnitPerKilowattHourNetGeneration Average BTU per kWh Net Generation

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

Hydroelectric Generating Plant Statistics

Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings).
If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number.
If net peak demand for 60 minutes is not available, give that which is available specifying period.
If a group of employees attends more than one generating plant, report on line 11 the approximate average number of employees assignable to each plant.
The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
Report as a separate plant any plant equipped with combinations of steam, hydro, internal combustion engine, or gas turbine equipment.

Line No.	Item (a)	FERC Licensed Project No. 0 Plant Name: 0
1	PlantKind Kind of Plant (Run-of-River or Storage)
2	PlantConstructionType Plant Construction type (Conventional or Outdoor)
3	YearPlantOriginallyConstructed Year Originally Constructed
4	YearLastUnitOfPlantInstalled Year Last Unit was Installed
5	InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW)
6	NetPeakDemandOnPlant Net Peak Demand on Plant-Megawatts (60 minutes)
7	PlantHoursConnectedToLoad Plant Hours Connect to Load
8	NetPlantCapabilityAbstract Net Plant Capability (in megawatts)
9	NetPlantCapabilityUnderMostFavorableOperatingConditions (a) Under Most Favorable Oper Conditions
10	NetPlantCapabilityUnderMostAdverseOperatingConditions (b) Under the Most Adverse Oper Conditions
11	PlantAverageNumberOfEmployees Average Number of Employees
12	NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh
13	CostOfPlantAbstract Cost of Plant
14	CostOfLandAndLandRightsHydroelectricProduction Land and Land Rights
15	CostOfStructuresAndImprovementsHydroelectricProduction Structures and Improvements
16	CostOfReservoirsDamsAndWaterwaysHydroelectricProduction Reservoirs, Dams, and Waterways
17	EquipmentCostsHydroelectricProduction Equipment Costs
18	CostOfRoadsRailroadsAndBridgesHydroelectricProduction Roads, Railroads, and Bridges
19	AssetRetirementCostsHydroelectricProduction Asset Retirement Costs
20	CostOfPlant Total cost (total 13 thru 20)
21	CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 20 / 5)
22	ProductionExpensesAbstract Production Expenses
23	OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering
24	WaterForPower Water for Power
25	HydraulicExpenses Hydraulic Expenses
26	ElectricExpensesHydraulicPowerGeneration Electric Expenses
27	MiscellaneousHydraulicPowerGenerationExpenses Misc Hydraulic Power Generation Expenses
28	RentsHydraulicPowerGeneration Rents
29	MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration Maintenance Supervision and Engineering
30	MaintenanceOfStructuresHydraulicPowerGeneration Maintenance of Structures
31	MaintenanceOfReservoirsDamsAndWaterways Maintenance of Reservoirs, Dams, and Waterways
32	MaintenanceOfElectricPlantHydraulicPowerGeneration Maintenance of Electric Plant
33	MaintenanceOfMiscellaneousHydraulicPlant Maintenance of Misc Hydraulic Plant
34	PowerProductionExpensesHydraulicPower Total Production Expenses (total 23 thru 33)
35	ExpensesPerNetKilowattHour Expenses per net kWh

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

Pumped Storage Generating Plant Statistics
Large plants and pumped storage plants of 10,000 Kw or more of installed capacity (name plate ratings). If any plant is leased, operating under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. Give project number. If net peak demand for 60 minutes is not available, give that which is available, specifying period. If a group of employees attends more than one generating plant, report on Line 8 the approximate average number of employees assignable to each plant. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power System Control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses." Pumping energy (Line 10) is that energy measured as input to the plant for pumping purposes. Include on Line 36 the cost of energy used in pumping into the storage reservoir. When this item cannot be accurately computed leave Lines 36, 37 and 38 blank and describe at the bottom of the schedule the company's principal sources of pumping power, the estimated amounts of energy from each station or other source that individually provides more than 10 percent of the total energy used for pumping, and production expenses per net MWH as reported herein for each source described. Group together stations and other resources which individually provide less than 10 percent of total pumping energy. If contracts are made with others to purchase power for pumping, give the supplier contract number, and date of contract.
Line No.	Item (a)	FERC Licensed Project No. 0 Plant Name: 0
1	PlantConstructionType Type of Plant Construction (Conventional or Outdoor)
2	YearPlantOriginallyConstructed Year Originally Constructed
3	YearLastUnitOfPlantInstalled Year Last Unit was Installed
4	InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW)
5	NetPeakDemandOnPlant Net Peak Demaind on Plant-Megawatts (60 minutes)
6	PlantHoursConnectedToLoad Plant Hours Connect to Load While Generating
7	NetContinuousPlantCapability Net Plant Capability (in megawatts)
8	PlantAverageNumberOfEmployees Average Number of Employees
9	NetGenerationExcludingPlantUse Generation, Exclusive of Plant Use - kWh
10	EnergyUsedForPumping Energy Used for Pumping
11	NetOutputForLoad Net Output for Load (line 9 - line 10) - Kwh	0
12	CostOfPlantAbstract Cost of Plant
13	CostOfLandAndLandRightsPumpedStoragePlant Land and Land Rights
14	CostOfStructuresAndImprovementsPumpedStoragePlant Structures and Improvements
15	CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant Reservoirs, Dams, and Waterways
16	CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant Water Wheels, Turbines, and Generators
17	CostOfAccessoryElectricEquipmentPumpedStoragePlant Accessory Electric Equipment
18	CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant Miscellaneous Powerplant Equipment
19	CostOfRoadsRailroadsAndBridgesPumpedStoragePlant Roads, Railroads, and Bridges
20	AssetRetirementCostsPumpedStoragePlant Asset Retirement Costs
21	CostOfPlant Total cost (total 13 thru 20)
22	CostPerKilowattOfInstalledCapacity Cost per KW of installed cap (line 21 / 4)
23	ProductionExpensesAbstract Production Expenses
24	OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering
25	WaterForPower Water for Power
26	PumpedStorageExpenses Pumped Storage Expenses
27	ElectricExpensesPumpedStoragePlant Electric Expenses
28	MiscellaneousPumpedStoragePowerGenerationExpenses Misc Pumped Storage Power generation Expenses
29	RentsPumpedStoragePlant Rents
30	MaintenanceSupervisionAndEngineeringPumpedStoragePlant Maintenance Supervision and Engineering
31	MaintenanceOfStructuresPumpedStoragePlant Maintenance of Structures
32	MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant Maintenance of Reservoirs, Dams, and Waterways
33	MaintenanceOfElectricPlantPumpedStoragePlant Maintenance of Electric Plant
34	MaintenanceOfMiscellaneousPumpedStoragePlant Maintenance of Misc Pumped Storage Plant
35	PowerProductionExpenseBeforePumpingExpenses Production Exp Before Pumping Exp (24 thru 34)
36	PumpingExpenses Pumping Expenses
37	PowerProductionExpensesPumpedStoragePlant Total Production Exp (total 35 and 36)
38	ExpensesPerNetKilowattHour Expenses per kWh (line 37 / 9)
39	ExpensesPerNetKilowattHourGenerationAndPumping Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10))	0

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

GENERATING PLANT STATISTICS (Small Plants)
Small generating plants are steam plants of, less than 25,000 Kw; internal combustion and gas turbine-plants, conventional hydro plants and pumped storage plants of less than 10,000 Kw installed capacity (name plate rating). Designate any plant leased from others, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, and give a concise statement of the facts in a footnote. If licensed project, give project number in footnote. List plants appropriately under subheadings for steam, hydro, nuclear, internal combustion and gas turbine plants. For nuclear, see instruction 11, Page 402. If net peak demand for 60 minutes is not available, give the which is available, specifying period. If any plant is equipped with combinations of steam, hydro internal combustion or gas turbine equipment, report each as a separate plant. However, if the exhaust heat from the gas turbine is utilized in a steam turbine regenerative feed water cycle, or for preheated combustion air in a boiler, report as one plant.
									Production Expenses
Line No.	PlantName Name of Plant (a)	YearPlantOriginallyConstructed Year Orig. Const. (b)	InstalledCapacityOfPlant Installed Capacity Name Plate Rating (MW) (c)	NetPeakDemandOnPlant Net Peak Demand MW (60 min) (d)	NetGenerationExcludingPlantUse Net Generation Excluding Plant Use (e)	CostOfPlant Cost of Plant (f)	PlantCostPerMw Plant Cost (Incl Asset Retire. Costs) Per MW (g)	OperatingExpensesExcludingFuel Operation Exc'l. Fuel (h)	FuelProductionExpenses Fuel Production Expenses (i)	MaintenanceProductionExpenses Maintenance Production Expenses (j)	FuelKind Kind of Fuel (k)	FuelCostPerMmbtus Fuel Costs (in cents (per Million Btu) (l)	GenerationType Generation Type (m)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

ENERGY STORAGE OPERATIONS (Large Plants)
Large Plants are plants of 10,000 Kw or more. In columns (a) (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location. In column (d), report Megawatt hours (MWH) purchased, generated, or received in exchange transactions for storage. In columns (e), (f) and (g) report MWHs delivered to the grid to support production, transmission and distribution. The amount reported in column (d) should include MWHs delivered/provided to a generator’s own load requirements or used for the provision of ancillary services. In columns (h), (i), and (j) report MWHs lost during conversion, storage and discharge of energy. In column (k) report the MWHs sold. In column (l), report revenues from energy storage operations. In a footnote, disclose the revenue accounts and revenue amounts related to the income generating activity. In column (m), report the cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. In columns (n) and (o), report fuel costs for storage operations associated with self-generated power included in Account 501 and other costs associated with self-generated power. In columns (q), (r) and (s) report the total project plant costs including but not exclusive of land and land rights, structures and improvements, energy storage equipment, turbines, compressors, generators, switching and conversion equipment, lines and equipment whose primary purpose is to integrate or tie energy storage assets into the power grid, and any other costs associated with the energy storage project included in the property accounts listed.
Line No.	Name of the Energy Storage Project (a)	Functional Classification (b)	Location of the Project (c)	MWHs (d)	MWHs delivered to the grid to support Production (e)	MWHs delivered to the grid to support Transmission (f)	MWHs delivered to the grid to support Distribution (g)	MWHs Lost During Conversion, Storage and Discharge of Energy Production (h)	MWHs Lost During Conversion, Storage and Discharge of Energy Transmission (i)	MWHs Lost During Conversion, Storage and Discharge of Energy Distribution (j)	MWHs Sold (k)	Revenues from Energy Storage Operations (l)	Power Purchased for Storage Operations (555.1) (Dollars) (m)	Fuel Costs from associated fuel accounts for Storage Operations Associated with Self- Generated Power (Dollars) (n)	Other Costs Associated with Self-Generated Power (Dollars) (o)	Project Costs included in (p)	Production (Dollars) (q)	Transmission (Dollars) (r)	Distribution (Dollars) (s)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

TRANSMISSION LINE STATISTICS
Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. If required by a State commission to report individual lines for all voltages, do so but do not group totals for each voltage under 132 kilovolts. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g). Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. Base the plant cost figures called for in columns (j) to (l) on the book cost at end of year.
	DESIGNATION		VOLTAGE (KV) - (Indicate where other than 60 cycle, 3 phase)			LENGTH (Pole miles) - (In the case of underground lines report circuit miles)				COST OF LINE (Include in column (j) Land, Land rights, and clearing right-of-way)			EXPENSES, EXCEPT DEPRECIATION AND TAXES
Line No.	TransmissionLineStartPoint From	TransmissionLineEndPoint To	OperatingVoltageOfTransmissionLine Operating	DesignedVoltageOfTransmissionLine Designated	SupportingStructureOfTransmissionLineType Type of Supporting Structure	LengthForStandAloneTransmissionLines On Structure of Line Designated	LengthForTransmissionLinesAggregatedWithOtherStructures On Structures of Another Line	NumberOfTransmissionCircuits Number of Circuits	SizeOfConductorAndMaterial Size of Conductor and Material	CostOfLandAndLandRightsTransmissionLines Land	ConstructionAndOtherCostsTransmissionLines Construction Costs	OverallCostOfTransmissionLine Total Costs	OperatingExpensesOfTransmissionLine Operation Expenses	MaintenanceExpensesOfTransmissionLine Maintenance Expenses	RentExpensesOfTransmissionLine Rents	OverallExpensesOfTransmissionLine Total Expenses
	(a)	(b)	(c)	(d)	(e)	(f)	(g)	(h)	(i)	(j)	(k)	(l)	(m)	(n)	(o)	(p)
1	0168 BAKER	DON MARQUIS	765.00	765.00	3	26.41	0.00	1	954 ACSR
2	0168 BAKER	DON MARQUIS	765.00	765.00	3	10.32	0.00	1	954 ACSR
3	0171 KAMMER	DUMONT	765.00	765.00	3	225.45	0.00	1	4-954 ACSR
4	0171 Kammer	Dumont	765.00	765.00	1	0.23	0.00	1	4-954 ACSR
5	0194 AMOS	NORTH PROCTORVILLE	765.00	765.00	3	5.30	0.00	1	1351.5 AC
6	0195 GAVIN	MARYSVILLE	765.00	765.00	3	124.40	0.00	1	1351.5 AC
7	0232 AMOS	GAVIN	765.00	765.00	3	0.49	0.00	1	1351.5 AC
8	0233 GAVIN	KAMMER	765.00	765.00	3	2.62	0.00	1	1351.5 AC
9	0263 KAMMER	SOUTH CANTON	765.00	765.00	3	0.24	0.00	1	1351.5 AC
10	0263 KAMMER	SOUTH CANTON	765.00	765.00	3	78.44	0.00	1	1351.5 AC
11	0269 NORTH PROCTORV	HANGING ROCK	765.00	765.00	3	25.99	0.00	1	1351.5 AC
12	0270 HANGING ROCK	JEFFERSON	765.00	765.00	3	6.14	0.00	1	1351.5 AC
13	0047 SPORN	MUSKINGUM	345.00	345.00	3	0.00	0.00	1	1275 ACSR
14	0047 SPORN	MUSKINGUM	345.00	345.00	1	41.34	0.00	2	2-959.6 KCM
15	0048 MUSKINGUM	CENTRAL	345.00	345.00	3	28.10	0.00	1	2303 ACAR
16	0048 MUSKINGUM	CENTRAL	345.00	345.00	3	53.94	0.00	2	2303 ACAR
17	0052 CENTRAL	EAST LIMA	345.00	345.00	3	2.56	0.00	1	1275 ACSR
18	0052 CENTRAL	EAST LIMA	345.00	345.00	1	0.54	0.00	2	2303 ACAR
19	0052 CENTRAL	EAST LIMA	345.00	345.00	3	71.05	0.00	2	2303 ACAR
20	0070 EAST LIMA	SORENSON	345.00	345.00	3	12.34	0.00	1	1275 ACSR
21	0079 MUSKINGUM	TIDD	345.00	345.00	3	82.78	0.00	2	1414 ACSR
22	0079 MUSKINGUM	TIDD	345.00	345.00	1	0.41	0.00	1	1851 KCM
23	0079 MUSKINGUM	TIDD	345.00	345.00	1	0.39	0.00	1	2303 KCM
24	0088 KAMMER EXT. NO. 1		345.00	345.00	3	0.20	0.00	1	1414 ACSR
25	0088 KAMMER EXT. NO. 1 (WV)		345.00	345.00	3	0.38	0.00	1	1414 ACSR
26	0104 TIDD	CANTON CENTRAL	345.00	345.00	3	51.30	0.00	1	954 ACSR
27	0104 TIDD	CANTON CENTRAL	345.00	345.00	1	0.20	0.00	1	954 ACSR
28	0106 CANTON CENTRAL	JUNIPER	345.00	345.00	3	4.06	0.00	1	954 ACSR
29	0106 CANTON CENTRAL	JUNIPER	345.00	345.00	3	1.36	0.00	1	954 ACSR
30	0106 CANTON CENTRAL	JUNIPER	345.00	345.00	3	0.55	0.00	2	954 ACSR
31	0119 MUSKINGUM	OHIO CENTRAL	345.00	345.00	3	30.73	0.00	1	1414 ACSR
32	0119 MUSKINGUM	OHIO CENTRAL	345.00	345.00	3	12.51	0.00	1	954 ACSR
33	0142 KAMMER EXT. NO. 2		345.00	345.00	3	0.15	0.00	1	1414 ACSR
34	0142 KAMMER EXT. NO. 2 (WV)		345.00	345.00	3	0.05	0.00	1	1414 ACSR
35	0161 OHIO CENTRAL	FOSTORIA CENTRAL	345.00	345.00	3	100.56	0.00	1	954 ACSR
36	0161 OHIO CENTRAL	FOSTORIA CENTRAL	345.00	345.00	3	5.99	0.00	1	954 ACSR
37	0162 FOSTORIA CENTRAL	EAST LIMA	345.00	345.00	3	34.47	0.00	1	954 ACSR
38	0162 FOSTORIA CENTRAL	EAST LIMA	345.00	345.00	3	5.35	0.00	1	954 ACSR
39	0163 FOSTORIA CENTRAL	PEMBERVILLE	345.00	345.00	3	19.29	0.00	2	954 ACSR
40	0166 SOUTH CANTON	SAMMIS	345.00	345.00	3	0.74	0.00	1	954 ACSR
41	0167 SOUTH CANTON	STAR	345.00	345.00	3	0.75	0.00	1	954 ACSR
42	0172 SOUTHWEST LIMA EXTEN		345.00	345.00	3	14.62	0.00	2	1414 ACSR
43	0172 SOUTHWEST LIMA EXTEN		345.00	345.00	3	0.06	0.00	2	1708 KCM
44	0173 SOUTHWEST LIMA	MIAMI	345.00	345.00	3	18.04	0.00	1	954 ACSR
45	0173 SOUTHWEST LIMA	MIAMI	345.00	345.00	3	0.72	0.00	1	954 ACSR
46	0173 SOUTHWEST LIMA	MIAMI	345.00	345.00	2	0.60	0.00	1	954 ACSR
47	0208 TIDD	COLLIER	345.00	345.00	3	0.16	0.00	2	954 ACSR
48	0208 TIDD	COLLIER	345.00	345.00	3	0.15	0.00	1	2-636 KCM
49	0248 MARYSVILLE EXT NO		345.00	345.00	3	4.22	0.00	2	1275 ACSR
50	0249 MARYSVILLE EXT NO		345.00	345.00	3	4.84	0.00	2	2303 ACAR
51	0279 SOUTH CANTON	CANTON CENTRAL	345.00	345.00	3	8.16	0.00	2	954 ACSR
52	0365 WATERFORD EXTENSION	MUSKINGUM-SPORN	345.00	345.00	3	0.98	0.00	0	954 ACSR
53	0366 BEVERLY EXTENSION		345.00	345.00	3	0.10	0.00	1	2303 ACAR
54	0403 Sporn	Kyger Creek (OVEC)	345.00	345.00	1	0.03	0.00	1	1272 ACSS
55	0001 LIMA	FT WAYNE	138.00	138.00	1	0.10	0.00	2	397.5 ACS
56	0001 LIMA	FT WAYNE	138.00	138.00	3	15.68	0.00	2	397.5 ACS
57	0004 HOWARD	ASHLAND	138.00	138.00	3	6.15	0.00	1	397.5 ACS
58	0004 HOWARD	ASHLAND	138.00	138.00	3	1.84	0.00	2	397.5 ACS
59	0005 WINDSOR	CANTON	138.00	138.00	1	0.46	0.00	1	556.5 ACS
60	0005 WINDSOR	CANTON	138.00	138.00	3	13.84	0.00	1	200 CU
61	0006 WINDSOR	CANTON (WV)	138.00	138.00	3	0.32	0.00	1	556.5 ACS
62	0007 PHILO	HOWARD	138.00	138.00	3	78.31	0.00	2	556.5 ACS
63	0007 PHILO	HOWARD	138.00	138.00	1	2.30	0.00	2	556.5 ACS
64	0007 Philo	Howard	138.00	138.00	1	0.30	0.00	1	556.5 ACSR
65	0010 FOSTORIA	PEMBERVILLE	138.00	138.00	3	18.49	0.00	2	336.4 ACS
66	0010 FOSTORIA	PEMBERVILLE	138.00	138.00	3	0.06	0.00	1	477 ACSR
67	0010 FOSTORIA	PEMBERVILLE	138.00	138.00	1	0.00	0.00	1	556.5 ACS
68	0011 PHILO	RUTLAND	138.00	138.00	3	65.70	0.00	2	397.5 ACS
69	0016 SOUTH POINT	TURNER	138.00	138.00	3	0.48	0.00	2	397.5 ACS
70	0018 PHILO	TORREY	138.00	138.00	3	69.32	0.00	1	1033.5 AC
71	0018 PHILO	TORREY	138.00	138.00	1	0.04	0.00	1	397.5 KCM
72	0018 PHILO	TORREY	138.00	138.00	1	1.37	0.00	1	397.5 KCM
73	0019 CROOKSVILLE	WEST LANCASTER	138.00	138.00	3	30.57	0.00	2	397.5 ACS
74	0019 CROOKSVILLE	WEST LANCASTER	138.00	138.00	1	0.13	0.00	2	397.5 ACS
75	0020 PHILO	CANTON	138.00	138.00	3	73.10	0.00	1	1033.5 AC
76	0020 PHILO	CANTON	138.00	138.00	1	0.95	0.00	1	336.4 KCM
77	0025 TIDD	WAGENHALS	138.00	138.00	1	0.02	0.00	1	1033.5 KCM
78	0025 TIDD	WAGENHALS	138.00	138.00	3	52.82	0.00	1	1033.5 AC
79	0025 TIDD	WAGENHALS	138.00	138.00	1	0.62	0.00	1	556.5 KCM
80	0028 PORTSMOUTH	TRENTON NO. 2	138.00	138.00	1	50.02	0.00	1	477 ACSR
81	0028 PORTSMOUTH	TRENTON NO. 2	138.00	138.00	3	0.24	0.00	1	477 ACSR
82	0028 PORTSMOUTH	TRENTON NO. 2	138.00	138.00	3	0.45	0.00	2	6X477 ACS
83	0028 PORTSMOUTH	TRENTON NO. 2	138.00	138.00	1	0.38	0.00	2	6X477 KCM
84	0032 TRENTON	MUNCIE	138.00	138.00	3	24.62	0.00	1	397.5 ACS
85	0033 RUTLAND	SPORN	138.00	138.00	3	4.81	0.00	2	397.5 ACS
86	0034 SPORN	SOUTH POINT	138.00	138.00	3	8.91	0.00	1	397.5 ACS
87	0034 SPORN	SOUTH POINT	138.00	138.00	3	40.41	0.00	2	397.5 ACS
88	0034 SPORN	SOUTH POINT	138.00	138.00	1	0.79	0.00	1	397.5 KCM
89	0036 SPORN	PORTSMOUTH	138.00	138.00	1	0.20	0.00	1	477 KCM
90	0036 SPORN	PORTSMOUTH	138.00	138.00	3	0.00	0.00	1	477 ACSR
91	0036 SPORN	PORTSMOUTH	138.00	138.00	3	48.39	0.00	2	477 ACSR
92	0036 SPORN	PORTSMOUTH	138.00	138.00	1	0.26	0.00	1	1033.5 KCM
93	0037 HILLSBORO	MAYSVILLE	138.00	138.00	1	0.07	0.00	1	556.5 ACSR
94	0037 HILLSBORO	MAYSVILLE	138.00	138.00	2	33.54	0.00	1	477 ACSR
95	0038 CROOKSVILLE	NORTH NEWARK	138.00	138.00	1	30.67	0.00	1	397.5 ACS
96	0038 CROOKSVILLE	NORTH NEWARK	138.00	138.00	3	0.58	0.00	2	397.5 ACS
97	0039 WEST LANCASTER	SOUTH BALTIMORE	138.00	138.00	1	5.75	0.00	1	397.5 ACS
98	0039 WEST LANCASTER	SOUTH BALTIMORE	138.00	138.00	2	4.07	0.00	1	397.5 ACS
99	0041 NORTH NEWARK	WEST MT. VERNON	138.00	138.00	1	18.95	0.00	1	477 ACSR
100	0041 NORTH NEWARK	WEST MT. VERNON	138.00	138.00	3	2.81	0.00	2	477 ACSR
101	0042 SOUTH BALTIMORE	NORTH NEWARK	138.00	138.00	1	20.50	0.00	1	397.5 ACS
102	0042 SOUTH BALTIMORE	NORTH NEWARK	138.00	138.00	1	0.54	0.00	1	397.5 ACS
103	0042 SOUTH BALTIMORE	NORTH NEWARK	138.00	138.00	3	0.05	0.00	1	397.5 ACS
104	0042 SOUTH BALTIMORE	NORTH NEWARK	138.00	138.00	3	0.08	0.00	2	795 ACSR
105	0044 SUMMERFIELD	NATRIUM	138.00	138.00	3	27.07	0.00	2	556.5 ACS
106	0045 PHILO	MUSKINGUM	138.00	138.00	3	23.16	0.00	2	636 ACSR
107	0046 MUSKINGUM	SUMMERFIELD	138.00	138.00	1	0.27	0.00	2	556.5 ACS
108	0046 MUSKINGUM	SUMMERFIELD	138.00	138.00	3	25.08	0.00	2	556.5 ACS
109	0049 FOSTORIA	EAST LIMA	138.00	138.00	1	0.06	0.00	1	397.5 ACS
110	0049 FOSTORIA	EAST LIMA	138.00	138.00	1	0.45	0.00	1	336.4 KCM
111	0049 FOSTORIA	EAST LIMA	138.00	138.00	1	0.67	0.00	1	795 KCM
112	0049 FOSTORIA	EAST LIMA	138.00	138.00	3	39.66	0.00	2	397.5 ACS
113	0049 Fostoria	East Lima	138.00	138.00	1	0.40	0.00	2	397.5 ACS
114	0049 Fostoria	East Lima	138.00	138.00	1	0.07	0.00	2	795 ACSR
115	0050 EAST LIMA	LIMA	138.00	138.00	3	4.43	0.00	2	397.5 ACS
116	0055 TORREY	WOOSTER	138.00	138.00	1	26.39	0.00	1	556.5 ACS
117	0055 TORREY	WOOSTER	138.00	138.00	3	2.30	0.00	1	556.5 ACS
118	0056 WEST MT. VERNON	SOUTH KENTON	138.00	138.00	2	27.26	0.00	1	477 ACSR
119	0057 SOUTH KENTON	STERLING	138.00	138.00	3	0.09	0.00	1	336.4 ACS
120	0057 SOUTH KENTON	STERLING	138.00	138.00	2	24.28	0.00	1	477 KCM
121	0058 SOUTH POINT	PORTSMOUTH	138.00	138.00	3	0.04	0.00	1	397.5 ACS
122	0058 SOUTH POINT	PORTSMOUTH	138.00	138.00	3	33.17	0.00	2	397.5 ACS
123	0058 SOUTH POINT	PORTSMOUTH	138.00	138.00	1	1.40	0.00	2	397.5 KCM
124	0059 PHILO	CROOKSVILLE	138.00	138.00	3	15.37	0.00	2	336.4 ACS
125	0060 LIMA	STERLING	138.00	138.00	1	0.00	0.00	1	4/0 CU.
126	0060 LIMA	STERLING	138.00	138.00	3	0.00	0.00	1	795 ACSR
127	0061 EAST LIMA	WEST LIMA	138.00	138.00	1	0.15	0.00	2	556.5 ACS
128	0061 EAST LIMA	WEST LIMA	138.00	138.00	3	11.19	0.00	2	556.5 ACS
129	0061 EAST LIMA	WEST LIMA	138.00	138.00	3	1.05	0.00	3	556.5 ACS
130	0063 TORREY	MASSILLON	138.00	138.00	3	0.29	0.00	2	1033.5 AC
131	0066 WAGENHALS	WEST CANTON	138.00	138.00	3	9.16	0.00	1	556.5 ACS
132	0066 WAGENHALS	WEST CANTON	138.00	138.00	3	0.85	0.00	2	795 ACSR
133	0067 TORREY	AKRON	138.00	138.00	3	0.28	0.00	1	556.5 ACS
134	0069 TIDD	SOUTH CADIZ	138.00	138.00	1	11.09	0.00	1	477 ACSR
135	0069 TIDD	SOUTH CADIZ	138.00	138.00	1	0.05	0.00	1	1033.5 ACSR
136	0071 AKRON	CANTON	138.00	138.00	3	3.75	0.00	1	200 CU
137	0072 TIDD	WEIRTON NO. 2	138.00	138.00	1	7.78	0.00	1	556.5 ACS
138	0072 TIDD	WEIRTON NO. 2	138.00	138.00	3	0.38	0.00	1	556.5 ACS
139	0073 WEIRTON	SOUTH TORONTO	69.00	138.00	3	0.48	0.00	2	219.9 ACS
140	0073 WEIRTON	SOUTH TORONTO	138.00	138.00	3	0.14	0.00	1	556.5 ACS
141	0075 SPORN	KAISER NO. 1	138.00	138.00	3	4.25	0.00	2	795 ACSR
142	0076 LUCASVILLE	SARGENTS	138.00	138.00	1	11.31	0.00	1	636 ACSR
143	0076 LUCASVILLE	SARGENTS	138.00	138.00	1	0.57	0.00	1	636 KCM
144	0078 TIDD	WINDSOR JCT.	138.00	138.00	3	3.77	0.00	1	1780 ACSR
145	0080 NEWCOMERSTOWN	SOUTH COSHOCTON	138.00	138.00	1	13.12	0.00	1	336.4 ACS
146	0080 NEWCOMERSTOWN	SOUTH COSHOCTON	138.00	138.00	3	1.21	0.00	0	336.4 ACS
147	0081 FORD MOTOR EXT		138.00	138.00	3	0.25	0.00	2	397.5 ACS
148	0086 SPORN	KAISER NO. 2	138.00	138.00	3	5.67	0.00	2	795 ACSR
149	0087 WINDSOR JUNCTION	TILTONVILLE	138.00	138.00	3	3.81	0.00	1	556.5 ACS
150	0087 WINDSOR JUNCTION	TILTONVILLE	138.00	138.00	3	0.30	0.00	2	556.5 ACS
151	0089 WEST PHILO EXT. NO. 1		138.00	138.00	1	0.05	0.00	1	397.5 ACS
152	0090 WEST PHILO EXT. NO. 1		138.00	138.00	1	0.13	0.00	1	397.5 ACS
153	0091 KAMMER	OHIO FERRO ALLOYS	138.00	138.00	1	2.45	0.00	1	556.5 ACS
154	0091 KAMMER	OHIO FERRO ALLOYS (WV)	138.00	138.00	3	0.71	0.00	1	556.5 ACS
155	0095 PORTSMOUTH	TRENTON NO. 1	138.00	138.00	1	26.24	0.00	1	477 ACSR
156	0095 PORTSMOUTH	TRENTON NO. 1	138.00	138.00	1	0.25	0.00	1	477 KCM
157	0095 PORTSMOUTH	TRENTON NO. 1	138.00	138.00	3	1.04	0.00	1	477 ACSR
158	0095 PORTSMOUTH	TRENTON NO. 1	138.00	138.00	3	0.24	0.00	2	477 ACSR
159	0096 THIVENER	BUCKEYE CO-OP	138.00	138.00	1	4.94	0.00	1	219.9 ACS
160	0096 THIVENER	BUCKEYE CO-OP	138.00	138.00	1	1.22	0.00	1	219.9 KCM
161	0097 MERCERVILLE	APPLE GROVE	138.00	138.00	3	5.11	0.00	2	397.5 ACS
162	0098 MILLWOOD EXT.		138.00	138.00	1	0.10	0.00	1	500 CU.
163	0101 THIVENER EXT.		138.00	138.00	1	0.09	0.00	1	219.9 ACS
164	0102 MEIGS EXT. NO. 1		138.00	138.00	1	0.10	0.00	1	219.9 ACS
165	0103 MEIGS EXT NO. 2		138.00	138.00	1	0.10	0.00	1	219.9 ACS
166	0103 MEIGS EXT NO. 2		138.00	138.00	3	0.07	0.00	1	556.5 ACS
167	0108 OHIO CENTRAL	NORTH NEWARK	138.00	138.00	3	0.33	0.00	2	397.5 ACS
168	0108 OHIO CENTRAL	NORTH NEWARK	138.00	138.00	1	21.30	0.00	1	556.5 ACS
169	0110 NORTH STRASBURG EXT		138.00	138.00	1	0.06	0.00	1	1033.5 AC
170	0111 NORTH STRASBURG EXT		138.00	138.00	1	0.06	0.00	1	1033.5 AC
171	0112 ZANESVILLE EXT.		138.00	138.00	3	6.48	0.00	2	336.4 ACS
172	0113 HOWARD	BUCYRUS CENTER	138.00	138.00	3	16.30	0.00	1	556.5 ACS
173	0113 HOWARD	BUCYRUS CENTER	138.00	138.00	3	0.27	0.00	2	556.5 ACS
174	0114 SOUTH PEMBERVILLE	FREEMONT	138.00	138.00	1	14.18	0.00	1	556.5 ACS
175	0114 SOUTH PEMBERVILLE	FREEMONT	138.00	138.00	3	1.29	0.00	2	556.5 ACS
176	0118 SOUTH COSHOCTON	WOOSTER	138.00	138.00	2	39.51	0.00	1	477 ACSR
177	0120 OHIO CENTRAL	COSHOCTON JCT.	138.00	138.00	3	0.20	0.00	1	556.5 ACS
178	0120 OHIO CENTRAL	COSHOCTON JCT.	138.00	138.00	3	14.34	0.00	2	636 ACSR
179	0120 OHIO CENTRAL	COSHOCTON JCT.	138.00	138.00	1	0.18	0.00	1	636 KCM
180	0122 KAMMER	ORMET NO. 1	138.00	138.00	3	1.71	0.00	2	1033.5 AC
181	0123 FINDLAY CENTER EXT.		138.00	138.00	3	6.87	0.00	1	556.5 ACS
182	0125 TIDD	WEIRTON NO. 1	138.00	138.00	3	0.41	0.00	2	556.5 ACS
183	0126 ARROYO	EAST LIVERPOOL	138.00	138.00	3	0.15	0.00	1	556.5 ACS
184	0128 TIDD	NATRIUM	138.00	138.00	3	0.36	0.00	1	556.5 ACS
185	0129 HOWARD	FOSTORIA	138.00	138.00	3	44.54	0.00	2	397.5 ACSR
186	0129 HOWARD	FOSTORIA	138.00	138.00	1	0.17	0.00	2	397.5 ACSR
187	0129 HOWARD	FOSTORIA	138.00	138.00	1	0.10	0.00	2	959.6 ACSR/TW
188	0130 EAST WHEELERSB	TEXAS EASTERN	138.00	138.00	1	2.00	0.00	1	4/0 ACSR
189	0131 KAMMER	ORMET NO. 2	138.00	138.00	3	1.55	0.00	2	1033.5 AC
190	0133 SUNNYSIDE	WAGENHALS NO. 1	138.00	138.00	3	1.62	0.00	1	1033.5 AC
191	0133 SUNNYSIDE	WAGENHALS NO. 1	138.00	138.00	1	2.05	0.00	1	397.5 ACS
192	0134 TIDD	WHEELING STEEL	138.00	138.00	3	5.12	0.00	2	556.5 ACS
193	0141 MILLBROOK	SILOAM	138.00	138.00	3	1.60	0.00	2	556.5 ACS
194	0141 MILLBROOK	SILOAM	138.00	138.00	1	0.05	0.00	1	954 ACSR
195	0143 ZANESVILLE	OHIO CENTRAL	138.00	138.00	1	10.51	0.00	1	556.5 ACS
196	0143 ZANESVILLE	OHIO CENTRAL	138.00	138.00	3	2.32	0.00	1	556.5 ACS
197	0144 TORREY	TIMKEN	138.00	138.00	1	0.80	0.00	1	1033.5 AC
198	0144 TORREY	TIMKEN	138.00	138.00	3	0.86	0.00	1	1033.5 AC
199	0145 CANTON CENTRAL	TIMKEN	138.00	138.00	1	0.74	0.00	1	1033.5 AC
200	0145 CANTON CENTRAL	TIMKEN	138.00	138.00	3	5.52	0.00	1	636 ACSR
201	0146 EAST LIMA	WESTMINSTER	138.00	138.00	3	8.38	0.00	2	636 ACSR
202	0147 SUNNYSIDE	WAGENHALS NO. 2	138.00	138.00	1	2.03	0.00	1	397.5 ACS
203	0149 CANTON CENTRAL	WAGENHALS	138.00	138.00	3	2.02	0.00	2	1033.5 AC
204	0151 SOUTH CANTON	TORREY	138.00	138.00	3	1.26	0.00	1	1780 ACSR
205	0151 SOUTH CANTON	TORREY	138.00	138.00	3	1.60	0.00	2	556.5 ACS
206	0152 MALAGA	SPEIDEL	69.00	138.00	1	11.99	0.00	1	556.5 ACS
207	0153 BRIDGEVILLE EXT.		138.00	138.00	1	1.88	0.00	1	336.4 ACS
208	0142 MELMORE	TIFFIN CENTER	138.00	138.00		0.00	0.00	0
209	0158 ROBINSON PARK	RICHLAND	138.00	138.00	2	14.94	0.00	1	636 ACSR
210	0159 EAST LIMA	RICHLAND	138.00	138.00	2	27.74	0.00	1	636 ACSR
211	0164 FOSTORIA CENTRAL	FOSTORIA	138.00	138.00	3	0.08	0.00	1	1033.5 AC
212	0164 FOSTORIA CENTRAL	FOSTORIA	138.00	138.00	3	1.48	0.00	2	1033.5 AC
213	0169 SOUTH CALDWELL	SOUTH CUMBERLAND	138.00	138.00	1	10.83	0.00	1	556.5 ACSR
214	0170 HANGING ROCK EXT.		138.00	138.00	3	4.33	0.00	1	636 ACSR
215	0174 CANTON CENTRAL	BLUEBELL	138.00	138.00	1	0.25	0.00	1	795 ACSR
216	0174 CANTON CENTRAL	BLUEBELL	138.00	138.00	3	0.11	0.00	0	795 ACSR
217	0175 CANTON CENTRAL	CLOVERDALE	138.00	138.00	1	0.38	0.00	1	795 ACSR
218	0176 TIDD	STEUBENVILLE	138.00	138.00	3	7.30	0.00	1	795 ACSR
219	0177 SOUTHWEST LIMA	STERLING	138.00	138.00	3	5.21	0.00	2	1590 ACSR
220	0177 SOUTHWEST LIMA	STERLING	138.00	138.00	1	0.05	0.00	1	556.5 ACS
221	0178 SOUTHWEST LIMA	WEST LIMA	138.00	138.00	3	0.88	0.00	2	556.5 ACS
222	0180 OHIO CENTRAL EXT NO. 1		138.00	138.00	1	0.46	0.00	1	556.5 ACS
223	0181 OHIO CENTRAL EXT NO. 2		138.00	138.00	1	0.45	0.00	1	556.6 ACS
224	0182 SOUTH CANTON	WEST CANTON	138.00	138.00	1	5.20	0.00	2	795 ACSR
225	0182 SOUTH CANTON	WEST CANTON	138.00	138.00	1	0.13	0.00	2	664.8 KCM
226	0182 SOUTH CANTON	WEST CANTON	138.00	138.00	3	2.59	0.00	1	795 ACSR
227	0182 SOUTH CANTON	WEST CANTON	138.00	138.00	3	1.45	0.00	2	795 ACSR
228	0182 SOUTH CANTON	WEST CANTON	138.00	138.00	3	0.68	0.00	2	664.8 KCM
229	0183 KAMMER	WEST BELLAIRE	138.00	138.00	3	12.93	0.00	1	1033.5 AC
230	0183 KAMMER	WEST BELLAIRE	69.00	138.00	3	0.33	0.00	2	954 ACSR
231	0186 EAST ZANESVILLE EXT.		138.00	138.00	1	0.04	0.00	1	556.5 ACS
232	0187 WEST BELLAIRE	BRUES	138.00	138.00	3	4.26	0.00	1	556.5 ACS
233	0188 WEST BELLAIRE	TILTONVILLE	138.00	138.00	1	11.30	0.00	1	795 ACSR
234	0188 WEST BELLAIRE	TILTONVILLE	138.00	138.00	3	0.50	0.00	1	795 ACSR
235	0189 CROOKSVILLE TIE		138.00	138.00	1	0.20	0.00	1	556.5 ACS
236	0190 SOUTHWEST LIMA	WEST MOULTON	138.00	138.00	1	13.28	0.00	1	636 ACSR
237	0196 FREMONT CENTER	FREMONT	138.00	138.00	1	3.12	0.00	1	795 ACSR
238	0196 FREMONT CENTER	FREMONT	138.00	138.00	3	2.68	0.00	1	795 ACSR
239	0198 N. PROCTORVILLE	EAST HUNTINGTON	138.00	138.00	3	3.86	0.00	1	795 ACSR
240	0198 N. PROCTORVILLE	EAST HUNTINGTON	34.00	138.00	3	0.08	0.00	2	795 ACSR
241	0200 CAMPBELL ROAD	MIDWEST CO-OP	138.00	138.00	1	0.15	0.00	1	336.4 ACS
242	0201 N. PROCTORVILLE	SOUTH POINT	138.00	138.00	3	0.04	0.00	1	795 ACSR
243	0201 N. PROCTORVILLE	SOUTH POINT	138.00	138.00	3	10.83	0.00	2	795 ACSR
244	0202 MUSKINGUM	WOLF CREEK	138.00	138.00	1	0.00	0.00	1	556.5 ACS
245	0202 MUSKINGUM	WOLF CREEK	138.00	138.00	3	0.00	0.00	1	636 ACSR
246	0202 MUSKINGUM	WOLF CREEK	138.00	138.00	3	0.76	0.00	1	1233.6 ACSR
247	0203 SWITZER EXT. NO. 1		138.00	138.00	1	0.00	0.00	1	556.5 ACS
248	0204 SWITZER EXT. NO. 2		138.00	138.00	1	0.00	0.00	1	556.5 ACS
249	0210 BUCKLEY ROAD EXT.		138.00	138.00	1	2.75	0.00	1	795 ACSR
250	0213 WINDSOR EXT. NO. 2		0.00	138.00	1	0.11	0.00	1
251	0221 DARRAH	NORTH PROCTORVILLE	138.00	138.00	3	3.51	0.00	1	1033.5 AC
252	0223 DEXTER	MEIGS NO. 2	138.00	138.00	1	5.53	0.00	1	556.5 ACS
253	0224 NORTH RUTLAND	MEIGS NO. 1	138.00	138.00	1	3.84	0.00	1	556.5 ACS
254	0225 Amity	Academia	138.00	138.00	1	0.20	0.00	1	556.5 ACSR
255	0225 AMITY	ACADEMIA	138.00	138.00	3	0.14	0.00	1	556.5 ACS
256	0225 AMITY	ACADEMIA	138.00	138.00	3	6.33	0.00	2	795 ACSR
257	0226 ACADEMIA	WEST MT. VERNON	138.00	138.00	3	0.15	0.00	2	556.5 ACS
258	0226 ACADEMIA	WEST MT. VERNON	138.00	138.00	3	5.95	0.00	1	795 ACSR
259	0229 CANNELVILLE	GURNSEY MUSKINGUM C	138.00	138.00	1	0.11	0.00	1	336.4 ACS
260	0230 FAIRCREST EXT.		138.00	138.00	1	0.04	0.00	1	1033.5 AC
261	0235 WEST MILLERSPORT	HEATH	138.00	138.00	1	8.95	0.00	1	795 ACSR
262	0235 WEST MILLERSPORT	HEATH	138.00	138.00	3	3.06	0.00	1	795 ACSR
263	0238 NORTH PROCTORVILLE	EXTENSION	138.00	138.00	3	3.54	0.00	1	556.5 ACS
264	0240 NORTH CROWN CITY EXT		138.00	138.00	1	0.24	0.00	1	556.5 ACS
265	0241 NORTH CROWN CITY EXT		138.00	138.00	1	0.24	0.00	1	556.5 ACS
266	0242 HEATH EXT. NO. 2		138.00	138.00	3	1.29	0.00	1	795 ACSR
267	0243 HEATH EXT. NO. 1		138.00	138.00	3	1.29	0.00	1	556.5 ACS
268	0244 EAST SIDE EXT.		138.00	138.00	1	0.24	0.00	2	795 ACSR
269	0244 EAST SIDE EXT.		138.00	138.00	3	0.08	0.00	2	795 ACSR
270	0245 SOUTHEAST CANTON	SUNNYSIDE	138.00	138.00	3	2.31	0.00	2	1033.5 AC
271	0247 SOUTHEAST CANTON	WACO	138.00	138.00	3	2.12	0.00	2	1033.5 AC
272	0252 WEST DOVER EXT. NO.		138.00	138.00	1	0.10	0.00	1	1033.5 AC
273	0253 WEST DOVER EXT. NO.		138.00	138.00	1	0.09	0.00	1	1033.5 AC
274	0254 BUCKEYE CO-OP EXT. A		138.00	138.00	1	0.25	0.00	1	556.5 ACS
275	0257 GREENLAWN EXT.		138.00	138.00	1	0.97	0.00	2	795 ACSR
276	0257 GREENLAWN EXT.		138.00	138.00	3	0.12	0.00	0	795 ACSR
277	0260 EAST PROCTORVILLE EXT.		138.00	138.00	3	0.13	0.00	2	1033.5 AC
278	0264 FREMONT	SANDUSKY BAY	69.00	138.00	1	11.88	0.00	1	795 ACSR
279	0264 FREMONT	SANDUSKY BAY	69.00	138.00	3	0.25	0.00	0	795 ACSR
280	0265 WEST DOVER	SUGARCREEK	138.00	138.00	1	4.07	0.00	1	795 ACSR
281	0267 NORTH PORTSMOUTH	CENTRAL PORTSMOUTH	138.00	138.00	1	6.04	0.00	1	795 ACSR
282	0273 BUCKLEY ROAD	FREMONT CENTER	69.00	138.00	1	0.90	0.00	2	556.5 ACS
283	0274 WAYVIEW	HOOVER NORTH	69.00	138.00	3	0.02	0.00	1	795 ACSR
284	0274 WAYVIEW	HOOVER NORTH	69.00	138.00	3	1.04	0.00	2	795 ACSR
285	0275 WEST CANTON JCT.	WAYVIEW	138.00	138.00	1	1.11	0.00	1	795 ACSR
286	0275 WEST CANTON JCT.	WAYVIEW	138.00	138.00	1	1.80	0.00	2	795 ACSR
287	0275 WEST CANTON JCT.	WAYVIEW	138.00	138.00	3	1.89	0.00	1	795 ACSR
288	0276 BELDEN VILLAGE EXT.		138.00	138.00	1	1.51	0.00	1	795 ACSR
289	0280 EAST AMSTERDAM	CARROLL CO-OP	69.00	138.00	1	7.98	0.00	1	795 ACSR
290	0282 SOUTH POINT TIE		138.00	138.00	1	0.09	0.00	1	795 ACSR
291	0286 WEST CANTON TIE		138.00	138.00	1	0.16	0.00	2	795 ACSR
292	0289 OHIO CENTRAL EXT. NO.		138.00	138.00	1	0.27	0.00	1	636 ACSR
293	0290 SOUTH CANTON EXT. NO.		138.00	138.00	3	0.71	0.00	2	1033.5 AC
294	0294 SOUTH CANTON EXT. NO.		138.00	138.00	3	0.31	0.00	2	1033.5 AC
295	0295 BROADACRE EXT.		138.00	138.00	1	0.04	0.00	2	1780 ACSR
296	0307 WEST VAN WERT	DELPHOS CENTER	69.00	138.00	1	1.70	0.00	1	795 ACSR
297	0313 BUCKEYE COOP EXT. W		138.00	138.00	1	0.85	0.00	1	556.5 ACS
298	0316 ORDANANCE JCT. EXT.		138.00	138.00	1	0.10	0.00	2	1590 ACSR
299	0317 GUERNSEY	MUSKINGUM CO-OP EXT.	138.00	138.00	1	0.12	0.00	1	556.5 ACS
300	0318 BUCKEYE CO-OP EXT. M		138.00	138.00	1	0.15	0.00	1	556.5 ACS
301	0320 HEDDING ROAD	MORROW CO-OP	138.00	138.00	1	0.09	0.00	1	795 ACSR
302	0324 WEST MILLERSPORT	SOUTH CENTRAL POWER	138.00	138.00	1	0.20	0.00	1	556.5 ACS
303	0325 SHELBY MUNICIPAL EXT.		138.00	138.00	3	0.53	0.00	1	336.4 ACS
304	0326 BLOOMFIELD	GUERNSEY MUSKINGUM C	138.00	138.00	1	0.41	0.00	1	336.4 ACS
305	0327 NORTH CENTRAL CO-OP		138.00	138.00	1	0.45	0.00	1	336.4 ACS
306	0328 NORTH CHESIRE	EXTENSION NO. 2	138.00	138.00		0.00	0.00	0
307	0329 TYCOON EXT.		138.00	138.00	1	0.29	0.00	1	556.5 ACS
308	0331 LICKING CO-OP EXT.		138.00	138.00	1	0.04	0.00	1	336.4 ACS
309	0331 Licking Co-Op Extension	Bladensburg	138.00	138.00	1	0.04	0.00	1	795 ACSR
310	0333 ASHLEY EXT		69.00	138.00	1	0.62	0.00	1	336.4 ACS
311	0334 NORTH CHESHIRE	EXTENTION NO. 1	138.00	138.00	3	0.38	0.00	2	1033.5 AC
312	0336 SHUFFEL ROAD	TIMKEN RESEARCH	69.00	138.00	3	0.66	0.00	1	795 ACSR
313	0337 TIMKEN, RICHVILLE EX		138.00	138.00	1	1.11	0.00	2	1033.5 AC
314	0338 CONESVILLE COAL PREP		138.00	138.00	1	0.63	0.00	1	1033.5 AC
315	0339 A.G.A. GAS EXT.		138.00	138.00	1	0.16	0.00	1	336.4 ACS
316	0342 EAST WOOSTER EXT. NO.		138.00	138.00	3	5.15	0.00	2	556.5 ACS
317	0343 EAST WOOSTER EXT.		138.00	138.00	1	0.18	0.00	1	795 ACSR
318	0343 EAST WOOSTER EXT.		138.00	138.00	1	0.43	0.00	2	795 ACSR
319	0344 WAGENHALS	LTV STEEL NO. 1	138.00	138.00	3	0.65	0.00	1	1033.5 AC
320	0345 WAGENHALS	LTV STEEL NO. 2	138.00	138.00	3	0.68	0.00	1	1033.5 AC
321	0346 FOSTORIA TIE		138.00	138.00	1	0.02	0.00	1	336.4 ACS
322	0347 FOSTORIA CENTRAL EXT.		138.00	138.00	3	0.10	0.00	2	1033.5 AC
323	0348 FOSTORIA CENTRAL EXT.		138.00	138.00	3	0.10	0.00	1	1033.5 AC
324	0349 FOSTORIA POWER EXT.		138.00	138.00	3	0.10	0.00	3	336.4 ACS
325	0350 HANCOCK WOOD CO-OP		138.00	138.00	1	0.03	0.00	1	556.5 ACS
326	0351 EAST LEIPSIC EXT		138.00	138.00	1	6.57	0.00	2	795 ACSR
327	0352 BUCKEYE CO-OP EXT		138.00	138.00	1	0.09	0.00	1	336.4 ACS
328	0353 STERLING	FOUNDRY PARK	138.00	138.00	1	0.99	0.00	1	795 ACSR
329	0354 GAVIN EXT. NO. 1		138.00	138.00	3	3.10	0.00	2	1033.5 AC
330	0355 GAVIN EXT. NO. 2		138.00	138.00	3	2.97	0.00	2	1033.5 AC
331	0358 LICKING REC. EXT. A		138.00	138.00	1	0.21	0.00	2	556.5 ACS
332	0359 BUCKHORN	HOLMES	138.00	138.00	1	0.98	0.00	1	336.4 ACS
333	0360 ADAMS RUAL ELECTRICK	EMERALD	138.00	138.00	1	0.75	0.00	1	556.5 ACSR
334	0361 RILEY CREEK	PAULDING PUTNAM	138.00	138.00	3	1.20	0.00	1	336.4 ACS
335	0363 MEIGS NO. 2	WILKESVILLE	138.00	138.00		1.60	0.00	1
336	0364 NORTH CENTRAL CO-OP		138.00	138.00		1.84	0.00	1	556.5 ACS
337	0368 BALL HOLLOW	WASHINGTON CO-OP	138.00	138.00		0.05	0.00	1	556.5 ACS
338	0371 SPENCER RIDGE	BUCKINGHAM COAL	138.00	138.00	1	0.12	0.00	1	4/0 ACSR
339	0370 BUCKEYE CO-OP EXT		138.00	138.00	3	0.10	0.00	2	397.5 ACS
340	0372 NORTH BELLVILLE LOOP		138.00	138.00	1	0.11	0.00	2	556.5 ACS
341	0375 HANTHORN RD	G.O. ETHANOL	0.00	138.00	3	0.34	0.00	1	556.5 ACS
342	0376 WARNER EXTENSION	SUNNYSIDE-TORREY	138.00	138.00	1	0.30	0.00	1	397.5 ACS
343	0377 YELLOWBUSH		138.00	138.00	3	0.04	0.00	1	795 ACSR
344	0380 TIDD 345KV	138KV AUTO TRANS B BUS TIE	138.00	138.00	2	0.01	0.00	1	1590 ACSS
345	0381 Anguin Extension		138.00	138.00	1	0.84	0.00	2	795 ACSS
346	0382 City of St Marys	West Moulton	138.00	138.00	1	0.15	0.00	1	556 ACSR
347	0391 Lockbourne	SCP 138kV Bus Tie No. 2	138.00	138.00	1	0.03	0.00	1	636 ACSR
348	0392 Lockbourne	SCP 138kV Bus Tie No. 3	138.00	138.00	1	0.04	0.00	1	636 ACSR
349	0402 Marion Road	Mound Street	138.00	138.00	4	3.22	0.00	1	XLPE 5000 Prysmian
350	0408 Hartman Farm Extension No. 5		138.00	138.00	1	0.26	0.00	2	795 ACSS
351	0409 Hartman Farm Extension No. 6		138.00	138.00	1	0.29	0.00	2	795 ACSS
352	LINES < 132KV					2,050.32
353	Columbus Southern Power Co	Columbus Southern Power Co
354	9032 BEATTY	HAYDEN	345.00	345.00	1	0.00	0.00	1	2-954 ACSR
355	9032 BEATTY	HAYDEN	345.00	345.00	3	16.84	0.00	1	2-954 ACSR
356	9032 BEATTY	HAYDEN	345.00	345.00	1	0.44	0.00	1	2-954 ACSR
357	9034 CONESVILLE	CORRIDOR	345.00	345.00	3	53.48	0.00	1	2-1272 ACSR
358	9034 Conesville	Corridor	345.00	345.00	1	0.55	0.00	1	2-1272 ACSR
359	C633 POINT N	STR. 96-1	345.00	345.00	1,3	4.24	0.00	1	2-954 ACSR
360	C633B KIRK	CORRIDOR	345.00	345.00	2	11.96	0.00	2	2-954 ACSR
361	9037 HAYDEN	HYATT	345.00	345.00	3	12.00	0.00	1	2-954 ACSR
362	9038 HAYDEN	ROBERTS	345.00	345.00	1	5.58	0.00	1	2-954 ACSR
363	9039 POINT Z	CORRIDOR	345.00	345.00	2	12.44	0.00	1	2-954 ACSR
364	C613 KIRK EXT #1 (NORTH)		345.00	345.00	2	0.25	0.00	1	636 ACSR 26/7
365	C614 KIRK EXT #2 (SOUTH)		345.00	345.00	3	0.25	0.00	1	636 ACSR 26/7
366	8790 DAVIDSON	DUBLIN	138.00	138.00	4	3.15	0.00	1	2000 CU KCM
367	C710 DUBLIN	SAWMILL	138.00	138.00	1	6.40	0.00	1	636 ACSR 26/7
368	C795 KIMBERLY EXTENSION		138.00	138.00	1	0.56	0.00	2	636 ACSR 26/7
369	C796 DON MARQUIS LOOP #1		138.00	138.00	1	6.60	0.00	1	1033.5 KCM
370	C798 DON MARQUIS LOOP #2		138.00	138.00	1	0.65	0.00	1	1033.5 KCM
371	C799 GREIF EXTENSION		138.00	138.00	4	0.66	0.00	2	2000 kcm CU
372	C800 LICK	JACKSON	138.00	138.00	1	1.09	0.00	0
373	C850 WILLOW ISLAND	MILL CREEK	138.00	138.00	1	9.14	0.00	1	954 ACSR 45/7
374	C851 MILL CREEK	RIVERVIEW	138.00	138.00	1	10.38	0.00	1	954 ACSR 45/7
375	C851 MILL CREEK	RIVERVIEW	138.00	138.00	1	0.14	0.00	1	1033.5 ACSR
376	C852 RIVERVIEW	CORNER	138.00	138.00	1	7.09	0.00	1	954 ACSR 45/7
377	C853 CORNER	SHELL	138.00	138.00	1	2.13	0.00	1	336.4 ACSR 26/7
378	C854 PARKERSBURG	CORNER	138.00	138.00	1	0.02	0.00	1	336.4 ACSR
379	C854 PARKERSBURG	CORNER	138.00	138.00	2	1.25	0.00	1	336.4 ACSR
380	C855 MUSKINGUM	CORNER	138.00	138.00	1	15.79	0.00	1	556.5 ACSR 26/7
381	C856 BELMONT	RIVERVIEW	138.00	138.00	1	0.86	0.00	1	954 ACSR 45/7
382	C857 WASHINGTON	CORNER	138.00	138.00	1	6.51	0.00	1	954 ACSR 45/7
383	C858 RIVERVIEW	ELKEM METALS	138.00	138.00	1	0.80	0.00	1	954 ACSR 45/7
384	C976 Pine Ridge	Buckeye Co-Op	69.00	138.00	1	0.07	0.00	1	1033 ACSR
385	9006 GREENE	BEATTY	345.00	345.00	3	19.72	0.00	1	2-1024 ACAR
386	9006 GREENE	BEATTY	345.00	345.00	2	0.10	0.00	1	2-1024 ACAR
387	9007 MARQUIS	POINT X	345.00	345.00	1	0.39	0.00	1	2-954 KCM
388	9007 Don Marquis	Point X	345.00	345.00	2	0.18	0.00	1	2-983 ACAR
389	9007 MARQUIS	POINT X	345.00	345.00	3	45.43	0.00	1	2-983 ACAR
390	9010 STUART	POINT O	345.00	345.00	3	15.19	0.00	1	2-983 ACAR
391	9049 KILLEN-POINT O	MARQUIS	345.00	345.00	3	32.00	0.00	1	2-983 ACAR
392	9742 POINT Y	BEATTY	345.00	345.00	3	15.00	4.00	1	2-983 ACAR
393	9031 BEATTY	BIXBY	345.00	345.00	3	13.20	0.00	1	2-954 ACSR
394	9042 STUART	POINT Y	345.00	345.00	3	75.00	0.00	1	2-954 ACSR
395	9043 CONESVILLE	TOWER 71	345.00	345.00	2	42.76	0.00	1	2-954 ACSR
396	9043 TOWER 71	BIXBY	345.00	345.00	3	0.00	15.00	1	2-954 ACSR
397	9043 CONESVILLE	BIXBY	345.00	345.00	1	50.80	0.00	1	2-954 ACSR
398	9043 CONESVILLE	BIXBY	345.00	345.00	3	3.00	0.00	1	2-954 ACSR
399	9707 TOWER 27	BIXBY	345.00	345.00	3	0.00	9.00	1	2-954 ACSR
400	9707 TOWER 27	BIXBY	345.00	345.00	3	17.44	9.00	1	2-954 ACSR
401	9040 CONESVILLE	POINT Z	345.00	345.00	3	57.00	0.00	1	2-954 ACSR
402	9740 POINT Z	HYATT	345.00	345.00	3	9.00	0.00	1	2-954 ACSR
403	9740 POINT Z	HYATT	345.00	345.00	1	2.00	0.00	1	2-954 ACSR
404	C633A BIXBY	CORRIDOR (BIXBY-POINT N)	345.00	345.00	3	14.88	0.00	1	2-954 ACSR
405	8001 ROBERTS	BETHEL	138.00	138.00	1	0.00	0.00	2	636 ACSR
406	8001 ROBERTS	BETHEL	138.00	138.00	3	5.00	0.00	2	636 ACSR
407	8002 ROBERTS	KENNY	138.00	138.00	4	3.00	0.00	1	2500 ALUM
408	C789 BEAVER 138KV EXTENSION		138.00	138.00		0.00	0.00	0	0
409	8004 BETHEL	LINWORTH	138.00	138.00	3	0.00	3.00	1	636 ACSR
410	8004 BETHEL	LINWORTH	138.00	138.00	1	2.00	0.00	1	636 AA
411	8005 PICWAY	HARRISON	138.00	138.00	3	1.00	0.00	1	636 ACSR
412	8008 GROVES	BEXLEY	138.00	138.00	1	0.00	0.00	1	636 ACSR
413	8009 BEXLEY	ST. CLAIR	138.00	138.00	1	4.00	0.00	1	636 AA
414	8010 BIXBY	LSII	138.00	138.00	1	1.00	2.00	1	636 ACSR
415	8010 BIXBY	LSII	138.00	138.00	2	2.00	0.00	1	636 ACSR
416	8010 BIXBY	LSII	138.00	138.00	3	0.00	0.00	1	636 ACSR
417	8011 BIXBY	W. LANCASTER	138.00	138.00	2	0.00	0.00	1	4/O CWC
418	8011 BIXBY	W. LANCASTER	138.00	138.00	2	0.00	0.00	1	954 ACSR
419	8011 BIXBY	W. LANCASTER	138.00	138.00	2	0.00	0.00	1	636 ACSR
420	8015 LSII	MARION	138.00	138.00	1	2.17	0.00	1	636 ACSR
421	8015 LSII	MARION	138.00	138.00	3	3.00	0.00	1	636 ACSR
422	8016 MARION	CANAL	138.00	138.00	4	4.00	0.00	1	600 CU PIPT
423	8017 ST CLAIR	CLINTON	138.00	138.00	4	4.00	0.00	1	600 CU PIPT
424	8018 HARRISON	MARION	138.00	138.00	2	7.00	0.00	1	636 ACSR
425	8018 HARRISON	MARION	138.00	138.00	3	0.00	3.00	1	636 ACSR
426	8019 BIXBY	GROVES-ASTOR	138.00	138.00	1	8.42	0.00	1	636 AAA
427	8021 BEATTY	WILSON (EAST)	138.00	138.00	3	7.00	1.00	1	636 ACSR
428	8022 BEATTY	WILSON (WEST)	138.00	138.00	3	0.00	1.00	2	636 ACSR
429	8022 BEATTY	WILSON (WEST)	138.00	138.00	3	0.00	9.00	1	636 ACSR
430	8023 WAVERLY	SARGENTS	138.00	138.00	2	16.00	0.00	1	636 ACSR
431	8024 WAVERLY	ADAMS-SEAMAN	138.00	138.00	2	7.90	0.00	1	336 ACSR
432	8024 WAVERLY	ADAMS-SEAMAN	138.00	138.00	1	0.10	0.00	1	336.4 KCM
433	8024 WAVERLY	ADAMS-SEAMAN	138.00	138.00	1	0.14	0.00	1	1236.4 KCM
434	8025 CIRCLEVILLE	SCIPPO	138.00	138.00	2	0.96	0.00	1	336.4 ACSR
435	8025 CIRCLEVILLE	SCIPPO	138.00	138.00	1	0.62	0.00	1	336.4 KCM
436	8027 WAVERLY	LICK	138.00	138.00	2	16.00	0.00	1	636 ACSR
437	8027 WAVERLY	LICK	138.00	138.00	3	11.00	0.00	1	636 ACSR
438	8028 MORSE	GENOA-KARL	138.00	138.00	3	4.00	0.00	1	1272 ACSR
439	8028 MORSE	GENOA-KARL	138.00	138.00	1	4.94	0.00	1	636 ACSR
440	8028 MORSE	GENOA-KARL	138.00	138.00	2	2.00	0.00	1	600 CU PIPT
441	8029 OSU	HESS	138.00	138.00	4	1.00	0.00	1	636 ACSR
442	8030 WILSON	FIFTH-HESS	138.00	138.00	3	3.00	0.00	1	600 CU PIPT
443	8030 WILSON	FIFTH-HESS	138.00	138.00	4	2.00	0.00	1	636 ACSR
444	8031 WILSON	ROBERTS	138.00	138.00	3	5.00	0.00	1	636 ACSR
445	8031 WILSON	ROBERTS	138.00	138.00	1	0.00	0.00	1	636 ACSR
446	8031 WILSON	ROBERTS	138.00	138.00	1	1.00	0.00	2	636 ACSR
447	8032 BIXBY	BUCKEYE STEEL	138.00	138.00	3	3.00	1.00	1	636 ACSR
448	8032 BIXBY	BUCKEYE STEEL	138.00	138.00	2	2.00	0.00	1	636 AA
449	8032 BIXBY	BUCKEYE STEEL	138.00	138.00	1	1.17	0.00	1	1250 CU PIPT
450	8033 GAY	VINE	138.00	138.00	4	2.00	0.00	1	954 ACSR
451	8034 EAST BROAD	GAHANNA	138.00	138.00	1	0.03	1.03	1	636 AA
452	8034 EAST BROAD	GAHANNA	138.00	138.00	2	1.00	0.00	1	336.4 ACSR
453	8034 EAST BROAD	GAHANNA	138.00	138.00	2	3.00	0.00	1	636 ACSR
454	8035 HYATT	SAWMILL	138.00	138.00	1	5.43	0.00	2	1590 ACSR
455	8036 GAHANNA	MORSE	138.00	138.00	2	5.00	0.00	1	636 ACSR
456	8036 GAHANNA	MORSE	138.00	138.00	2	0.00	0.00	1	1272 ACSR
457	8037 CORRIDOR	MORSE-BLENDON	138.00	138.00	3	0.00	7.00	1	1272 ACSR
458	8037 CORRIDOR	MORSE-BLENDON	138.00	138.00	1	1.00	0.00	2	1272 ACSR
459	8038 CORRIDOR	MORSE	138.00	138.00	3	7.00	0.00	1	1272 ACSR
460	8039 KIRK	EAST BROAD	138.00	138.00	3	10.00	0.00	1	1272 ACSR
461	8040 KIRK	EAST BROAD	138.00	138.00	3	0.00	10.00	1	600 CU PIPT
462	8041 CANAL	MOUND	138.00	138.00	4	2.00	0.00	1	1272 ACSR
463	8043 CONESVILLE	TRENT	138.00	138.00	3	52.00	0.00	1	1272 ACSR
464	8043 CONESVILLE	TRENT	138.00	138.00	1	0.00	0.00	1	1272 ACSR
465	8044 TRENT	DELAWARE	138.00	138.00	3	12.61	0.00	1	1272 ACSR
466	8044 TRENT	DELAWARE	138.00	138.00	1	0.05	0.00	1	1272 ACSR
467	8046 ST. CLAIR	MIFFLIN STELZER	138.00	138.00	1	7.00	0.00	1	636 AA
468	8047 KENNY	KARL	138.00	138.00	3	1.00	0.00	1	1272 ACSR
469	8047 KENNY	KARL	138.00	138.00	3	3.00	0.00	1	336.4 ACSR
470	8047 KENNY	KARL	138.00	138.00	4	3.00	0.00	1	2500 ALUM
471	MORSE	CLINTON	138.00	138.00	3	0.00	5.00	1	1272 ACSR
472	MORSE	CLINTON	138.00	138.00	3	0.00	3.00	1	636 ACSR
473	8048 MORSE	HUNTLEY-CLINTON	138.00	138.00	3	3.00	0.00	1	636 AA
474	8049 BIXBY	GROVES	138.00	138.00	3	3.00	0.00	2	636 ACSR
475	8049 BIXBY	GROVES	138.00	138.00	1	1.00	0.00	2	636 ACSR
476	8049 BIXBY	GROVES	138.00	138.00	3	0.00	0.00	1	1272 ACSR
477	8049 BIXBY	GROVES	138.00	138.00	1	0.00	0.00	1	336.4 ACSR
478	8051 POSTON	STROUDS RUN-CROOKSVILLE	138.00	138.00	1	0.00	0.00	1	1272 KCM
479	8051 POSTON	STROUDS RUN-CROOKSVILLE	138.00	138.00	2	7.23	0.00	1	636 ACSR
480	8053 BEATTY	CANAL	138.00	138.00	1	10.78	2.00	2	636 AAC
481	8053 BEATTY	CANAL	138.00	138.00	1	0.75	0.00	2	795 KCM
482	8055 CONESVILLE	OHIO CENTRAL	138.00	138.00	2	12.00	0.00	1	636 ACSR
483	8056 EAST BROAD	ASTOR	138.00	138.00	1	2.92	0.00	1	636 AA
484	8056 EAST BRAOD	ASTOR	138.00	138.00	1	0.10	0.00	2	795 KCM
485	8057 HARRISON	BEATTY	138.00	138.00	1,3	8.57	0.12	1	336.4 ACSR
486	8058 HARRISON	S CENTRAL REA	138.00	138.00	1	0.00	0.00	1	636 AA
487	8060 BEATTY	MCCOMB	138.00	138.00	1	2.00	3.00	1	636 AA
488	8061 MORSE	STELZER	138.00	138.00	4	2.00	0.00	1	2500 CU PIPT
489	8061 MORSE	STELZER	138.00	138.00	1	2.00	0.00	1	636 AA
490	8062 HUNTLEY	LINWORTH	138.00	138.00	1	3.32	1.00	1	636 ACSR
491	8065 HYATT	GENOA	138.00	138.00	1	4.95	9.00	1	636 ACSR
492	8065 Hyatt	Genoa	138.00	138.00	2	0.08	0.00	2	636 ACSR
493	8066 BUCKEYE STEEL	GAY	138.00	138.00	1	3.00	0.00	1	636 AA
494	8066 BUCKEYE STEEL	GAY	138.00	138.00	4	1.00	0.00	1	1259 CU PIPT
495	8067 POSTON	ELLIOT-DEXTER	138.00	138.00	1	0.00	0.00	1	1272 KCM
496	8067 POSTON	ELLIOT-DEXTER	138.00	138.00	2	4.03	0.00	1	636 ACSR
497	8068 HYATT	HUNTLEY	138.00	138.00	1	12.00	0.00	1	636 ACSR
498	8069 LICK	ADDISON	138.00	138.00	2	29.00	0.00	1	336.4 ACSR
499	8069 LICK	ADDISON	138.00	138.00	1	0.00	0.00	1	336.4 ACSR
500	8070 SCIPPO	SCIOTO TRAIL - DUPONT	138.00	138.00	1	1.00	0.00	1	636 ACSR
501	8070 SCIPPO	SCIOTO TRAIL - DUPONT	138.00	138.00	2	0.00	1.00	1	636 ACSR
502	8070 SCIPPO	SCIOTO TRAIL - DUPONT	138.00	138.00	2	1.00	0.00	1	336 ACSR
503	8072 SAWMILL	BETHEL	138.00	138.00	1	0.00	0.00	1	636 ACSR
504	8072 SAWMILL	BETHEL	138.00	138.00	3	2.40	0.00	1	636 ACSR
505	8074 SCIPPO	HARGUS	138.00	138.00	1	1.00	0.00	1	636 ACSR
506	8075 MOUND	ST. CLAIR	138.00	138.00	4	2.00	0.00	1	600 CU PIPT
507	8077 WAVERLY	MULBERRY ROSS	138.00	138.00	1	2.00	0.00	1	636 ACSR
508	8077 WAVERLY	MULBERRY ROSS	138.00	138.00	1	2.14	0.00	1	636 ACSR
509	8078 MCCOMB	SULLIVANT-GAY	138.00	138.00	1	8.90	0.00	2	636 ACSR
510	8079 MULBERRY	ROSS	138.00	138.00	1	0.00	2.00	1	636 ACSR
511	8079 MULBERRY	ROSS	138.00	138.00	2	3.00	0.00	1	636 ACSR
512	8079 MULBERRY	ROSS	138.00	138.00	1	1.00	0.00	1	636 ACSR
513	8080 EAST BROAD	BEXLEY	138.00	138.00	1	6.00	0.00	1	954 ACSR
514	8080 EAST BROAD	BEXLEY	138.00	138.00	2	0.00	0.00	1	954 ACSR
515	8081 HYATT	ROSS	138.00	138.00	1	1.00	0.00	1	1272 ACSR
516	8082 CORRIDOR	GENOA	138.00	138.00	1	0.36	0.00	1	1272 ACSR
517	8083 CORRIDOR	GAHANNA	138.00	138.00	1	0.00	0.00	1	1272 ACSR
518	KIRK	W. MILLERSPORT	138.00	138.00	3	0.00	8.00	1	1272 ACSR
519	KIRK	W. MILLERSPORT	138.00	138.00	3	0.00	0.00	1	636 ACSR
520	8086 CONESVILLE	KIRK	138.00	138.00	1	2.53	0.00	1	1272 KCM
521	8086 Conesville	Kirk	138.00	138.00	1	0.11	0.00	1	1590 ACSR
522	8086 CONESVILLE	KIRK	138.00	138.00	2	0.00	0.00	1	1272 ACSR
523	8086 CONESVILLE	KIRK	138.00	138.00	3	37.88	0.00	2	1272 ACSR
524	8086 CONESVILLE	KIRK	138.00	138.00	3	5.47	0.00	1	1272 ACSR
525	8088 HESS	VINE	138.00	138.00	4	2.00	0.00	1	1250 CU PIPT
526	8092 VINE	CITY OF COLUMBUS EAST	138.00	138.00	1	1.28	0.00	1	983.1 ACAR
527	8098 VINE	CITY OF COLUMBUS WEST	138.00	138.00	1	1.00	0.00	1	983.1 ACSR
528	8099 ST. CLAIR	VINE	138.00	138.00	1	1.00	0.00	1	954 ACSR
529	8099 ST. CLAIR	VINE	138.00	138.00	4	1.00	0.00	1	2750 CU KCM
530	8102 CLINTON	OSU	138.00	138.00	4	4.00	0.00	1	600 CU PIPT
531	8105 DAVIDSON RD	ROBERTS-BETHEL	138.00	138.00	1	0.00	0.00	2	636 ACSR
532	8129 OSU	HESS	138.00	138.00	4	1.00	0.00	1	600 CU PIPT
533	8712 SCIPPO	EAST SCIPPO	138.00	138.00		0.00	0.00	0	636 ACSR
534	8788 FISHER 138KV		138.00	138.00	3	0.42	0.00	1	636 ACSR
535	C792 CLAYBURNE	KENWORTH	138	138	1	0.32	0.00	1	565.5 ACSR 18/1
536	C793 DELANO	KENWORTH	138	138	1	0.31	0.00	1	556.5 ACSR 18/1
537	C794 BOLTON EXTENSION		138	138		0.00	0.00	0
538	TRANSMISSION LINES	LESS THAN 132 KV				456.54	22.50	0
539	Line costs and expenses are	not available by individual								111,027,506	1,326,376,490	1,437,403,996	77,730	22,639,735		22,717,465
540	transmission line.	Total shown in Column j-p
36	TOTAL					6,318.41	131.65	655		111,027,506.00	1,326,376,490.00	1,437,403,996.00	77,730.00	22,639,735.00	0.00	22,717,465.00

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

TRANSMISSION LINES ADDED DURING YEAR
Report below the information called for concerning Transmission lines added or altered during the year. It is not necessary to report minor revisions of lines. Provide separate subheadings for overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (l) to (o), it is permissible to report in these columns the costs. Designate, however, if estimated amounts are reported. Include costs of Clearing Land and Rights-of-Way, and Roads and Trails, in column (l) with appropriate footnote, and costs of Underground Conduit in column (m). If design voltage differs from operating voltage, indicate such fact by footnote; also where line is other than 60 cycle, 3 phase, indicate such other characteristic.
	LINE DESIGNATION			SUPPORTING STRUCTURE		CIRCUITS PER STRUCTURE		CONDUCTORS				LINE COST
Line No.	TransmissionLineStartPoint From	TransmissionLineEndPoint To	LengthOfTransmissionLineAdded Line Length in Miles	SupportingStructureOfTransmissionLineType Type	AverageNumberOfSupportingStructuresOfTransmissionLinePerMiles Average Number per Miles	NumberOfTransmissionCircuitsPerStructurePresent Present	NumberOfTransmissionCircuitsPerStructureUltimate Ultimate	ConductorSize Size	ConductorSpecification Specification	ConductorConfigurationAndSpacing Configuration and Spacing	OperatingVoltageOfTransmissionLine Voltage KV (Operating)	CostOfLandAndLandRightsTransmissionLinesAdded Land and Land Rights	CostOfPolesTowersAndFixturesTransmissionLinesAdded Poles, Towers and Fixtures	CostOfConductorsAndDevicesTransmissionLinesAdded Conductors and Devices	Asset Retire. Costs	CostOfTransmissionLinesAdded Total	SupportingStructureConstructionType Construction
	(a)	(b)	(c)	(d)	(e)	(f)	(g)	(h)	(i)	(j)	(k)	(l)	(m)	(n)	(o)	(p)	(q)
1	0382 City of St Marys	West Moulton	0.15	1	1.00	1	1	556	ACSR		138		510,927	121,479		632,406
2	0391 Lockbourne	SCP 138kV Bus Tie No. 2	0	1	1.00	1	1	556	ACSR		138		71,936	10,180		82,116
3	0392 Lockbourne	SCP 138kV Bus Tie No. 3	0	1	1	1	1	556	ACSR		138		88,029	12,567		100,596
4	0402 Marion Road	Mound Street	3	4	4	1	1	XLPE 5000 KCM Prysmian			138	452,929	20,918,562	13,371,479		34,742,970
5	0408 Hartman Farm Extension No. 5		0	1	1	2	2	795	ACSS		138	985	245,969	43,939		290,893
44	TOTAL		4		8	6	6					453,914	21,835,423	13,559,644		35,848,981

Name of Respondent:

Ohio Power Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/12/2023

Year/Period of Report

End of:

2022

SUBSTATIONS
Report below the information called for concerning substations of the respondent as of the end of the year. Substations which serve only one industrial or street railway customer should not be listed below. Substations with capacities of Less than 10 MVA except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (f). Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company.
		Character of Substation		VOLTAGE (In MVa)						Conversion Apparatus and Special Equipment
Line No.	SubstationNameAndLocation Name and Location of Substation (a)	SubstationCharacterDescription Transmission or Distribution (b)	SubstationCharacterAttendedOrUnattended Attended or Unattended (b-1)	PrimaryVoltageLevel Primary Voltage (In MVa) (c)	SecondaryVoltageLevel Secondary Voltage (In MVa) (d)	TertiaryVoltageLevel Tertiary Voltage (In MVa) (e)	SubstationInServiceCapacity Capacity of Substation (In Service) (In MVa) (f)	NumberOfTransformersInService Number of Transformers In Service (g)	Number of Spare Transformers (h)	ConversionApparatusAndSpecialEquipmentType Type of Equipment (i)	NumberOfConversionApparatusAndSpecialEquipmentUnits Number of Units (j)	CapacityOfConversionApparatusAndSpecialEquipment Total Capacity (In MVa) (k)
1	ACADEMIA - OH	Transmission		138.00	69.00	13.00	129.00	1			0	0.00
2	ACADEMIA - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	18.00
3	ADA - OH	Distribution		69.00	13.09		20.00	1			0	0.00
4	ADAMS (CSP) - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
5	ADAMS (CSP) - OH	Transmission		138.00	69.00	13.09	56.00	1			0	0.00
6	ADAMS (CSP) - OH	Transmission		69.00	13.09		20.00	1			0	0.00
7	ADDISON - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.39
8	ADDISON - OH	Transmission		138.00	69.00	13.00	56.00	1			0	0.00
9	ADDISON - OH	Transmission		69.00	12.00		20.00	1			0	0.00
10	ADENA - OH	Distribution		69.00	13.09		20.00	1			0	0.00
11	AMLIN - OH	Distribution		138.00	13.80		50.00	0	1		0	0.00
12	AMLIN - OH	Distribution		138.00	13.80		30.00	1			0	0.00
13	AMLIN - OH	Distribution		138.00	36.20		18.00	1			0	0.00
14	AMSTERDAM - OH	Distribution		69.00	13.09		9.38	1			0	0.00
15	ANCHOR HOCKING (OP) - OH	Distribution		69.00	4.00		6.25	1			0	0.00
16	ANCHOR HOCKING (OP) - OH	Distribution		34.50	4.00		2.50	0	1		0	0.00
17	ANCHOR HOCKING (OP) - OH	Distribution		69.00	12.00		6.25	1			0	0.00
18	ANTWERP - OH	Distribution		69.00	12.47		10.50	1			0	0.00
19	APPLE CREEK - OH	Distribution		138.00	13.09		10.40	1			0	0.00
20	ARBOR STREET - OH	Distribution		69.00	13.09		9.38	1			0	0.00
21	ARLINGTON - OH	Distribution		34.50	13.09		6.25	1			0	0.00
22	ASH AVENUE - OH	Distribution		34.50	13.09		20.00	1			0	0.00
23	ASHLEY - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	28.80
24	ASHLEY - OH	Distribution		69.00	13.20		9.38	1			0	0.00
25	ASTOR - OH	Distribution		138.00	13.80	13.80	168.00	2			0	0.00
26	ASTOR - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	4	14.40
27	AUGLAIZE - OH	Distribution		69.00	13.09		14.06	2			0	0.00
28	AVONDALE - OH	Distribution		69.00	12.00		16.38	2			0	0.00
29	BALTIMORE - OH	Distribution		69.00	4.36		9.38	1			0	0.00
30	BANNOCK ROAD - OH	Distribution		69.00	13.09		20.00	1			0	0.00
31	BARNESVILLE - OH	Distribution		69.00	13.09		10.50	1			0	0.00
32	BASCOM - OH	Distribution		69.00	4.33		2.50	1			0	0.00
33	BASHAN - OH	Distribution		69.00	13.20		7.50	1			0	0.00
34	BATESVILLE - OH	Distribution		69.00	12.00		8.40	1			0	0.00
35	BEALL AVENUE - OH	Distribution		69.00	13.09		20.00	1			0	0.00
36	BEARTOWN - OH	Distribution		69.00	13.09		6.25	1			0	0.00
37	BEARTOWN - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	7.20
38	BEATTY ROAD - OH	Transmission		138.00	69.00	13.00	56.00	1			0	0.00
39	BEATTY ROAD - OH	Transmission		138.00	13.80		50.00	1			0	0.00
40	BEATTY ROAD - OH	Transmission		345.00	137.50	13.80	450.00	1			0	0.00
41	BEATTY ROAD - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	2	7.20
42	BEATTY ROAD - OH	Transmission		138.00	70.50	36.25	54.00	0	1		0	0.00
43	BEATTY ROAD - OH	Transmission		138.00	13.09		15.00	0	1		0	0.00
44	BEATTY ROAD - OH	Transmission		138.00	13.09			0	1		0	0.00
45	BEATTY ROAD - OH	Transmission		138.00	69.00	13.80	100.00	2			0	0.00
46	BEAVER - OH	Distribution		69.00	12.00		20.00	1			0	0.00
47	BEAVER - OH	Distribution		69.00	34.50	12.00	7.00	0	1		0	0.00
48	BEAVERDAM - OH	Distribution		34.50	13.09		9.74	1			0	0.00
49	BELDEN VILLAGE - OH	Distribution		138.00	13.09		34.40	2			0	0.00
50	BELLAIRE (OP) - OH	Distribution		69.00	12.00		6.25	1			0	0.00
51	BELLVILLE - OH	Distribution		69.00	12.00		9.38	1			0	0.00
52	BELPRE - OH	Distribution		138.00	13.09		40.00	2			0	0.00
53	BERKSHIRE - OH	Distribution		138.00	35.40	13.80	50.00	1			0	0.00
54	BERKSHIRE - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1	7.20
55	BERLIN (OP) - OH	Distribution		69.00	34.50		12.50	1			0	0.00
56	BERLIN (OP) - OH	Distribution		69.00	13.09		20.00	1			0	0.00
57	BERWICK - OH	Distribution		69.00	13.09		20.00	1			0	0.00
58	BETHEL ROAD - OH	Transmission		138.00	69.50	13.09	50.00	1			0	0.00
59	BETHEL ROAD - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	72.00
60	BETHEL ROAD - OH	Transmission		138.00	13.80	13.80	83.30	0	1		0	0.00
61	BETHEL ROAD - OH	Transmission		138.00	13.80	13.80	167.30	2			0	0.00
62	BETHEL ROAD - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	5	28.80
63	BEXLEY - OH	Transmission		138.00	40.00	13.80	83.33	2			0	0.00
64	BEXLEY - OH	Transmission		138.00	13.80	13.80	84.00	1			0	0.00
65	BEXLEY - OH	Transmission		40.00	0.00	0.00	0.00			STATCAP	1	10.80
66	BEXLEY - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	2	5.70
67	BEXLEY - OH	Transmission		138.00	39.40	13.80	41.67	0	1		0	0.00
68	BIG PRAIRIE - OH	Distribution		69.00	13.09		5.25	1			0	0.00
69	BILLIAR - OH	Distribution		69.00	13.09		18.75	2			0	0.00
70	BIXBY - OH	Transmission		138.00	13.80		41.67	1			0	0.00
71	BIXBY - OH	Transmission		138.00	13.80	13.80	75.00	1			0	0.00
72	BIXBY - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	2	6.30
73	BIXBY - OH	Transmission		69.00	13.80		7.00	0	1		0	0.00
74	BIXBY - OH	Transmission		69.00	13.20		22.40	0	1		0	0.00
75	BIXBY - OH	Transmission		138.00	13.80		50.00	0	1		0	0.00
76	BIXBY - OH	Transmission		138.00	70.50	36.20	30.00	0	1		0	0.00
77	BIXBY - OH	Transmission		40.00	14.50		33.00	0	1		0	0.00
78	BIXBY - OH	Transmission		69.00	4.36		9.38	0	1		0	0.00
79	BIXBY - OH	Transmission		34.50	4.00		9.38	0	1		0	0.00
80	BIXBY - OH	Transmission		69.00	13.80		22.40	0	1		0	0.00
81	BIXBY - OH	Transmission		23.00	13.09		9.38	0	1		0	0.00
82	BIXBY - OH	Transmission		138.00	34.50	13.80	50.00	0	1		0	0.00
83	BIXBY - OH	Transmission		138.00	69.00	36.20	30.00	0	1		0	0.00
84	BIXBY - OH	Transmission		34.50	13.80		6.25	0	1		0	0.00
85	BIXBY - OH	Transmission		69.00	13.09		9.38	0	1		0	0.00
86	BIXBY - OH	Transmission		40.00	13.80		9.38	0	1		0	0.00
87	BIXBY - OH	Transmission		345.00	138.00	35.00	675.00	1			0	0.00
88	BLACKJACK ROAD - OH	Distribution		69.00	12.00		20.00	1			0	0.00
89	BLACKLICK - OH	Distribution		138.00	13.80		50.00	1			0	0.00
90	BLACKLICK - OH	Distribution		138.00	35.40	13.80	50.00	1			0	0.00
91	BLACKLICK - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	1	3.60
92	BLACKLICK - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1	4.80
93	BLACKLICK - OH	Distribution		138.00	13.80		50.00	0	1		0	0.00
94	BLAIR - OH	Distribution		69.00	13.80		25.00	1			0	0.00
95	BLAIR - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
96	BLENDON - OH	Distribution		138.00	34.50	13.80	25.00	1			0	0.00
97	BLENDON - OH	Distribution		138.00	35.40	13.80	100.00	2			0	0.00
98	BLENDON - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1
99	BLISS PARK - OH	Distribution		69.00	13.09		20.00	1			0	0.00
100	BLOOM - OH	Distribution		69.00	13.20		9.38	1			0	0.00
101	BLOOM - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	1	2,250.00
102	BLOOM ROAD - OH	Distribution		69.00	13.09		9.38	1			0	0.00
103	BLOOMVILLE - OH	Distribution		69.00	13.09		4.69	1			0	0.00
104	BLUFFTON (OP) - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1	3.60
105	BLUFFTON (OP) - OH	Distribution		34.50	13.09		10.50	1			0	0.00
106	BOLIVAR - OH	Distribution		138.00	36.20		25.00	1			0	0.00
107	BOLTON - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1
108	BREMEN - OH	Distribution		69.00	13.09		9.38	1			0	0.00
109	BRIDGEPORT - OH	Distribution		69.00	13.09		20.00	1			0	0.00
110	BRIDGEPORT - OH	Distribution		12.00	0.01		0.30	1			0	0.00
111	BRIDGEPORT - OH	Distribution		69.00	4.00		3.00	1			0	0.00
112	BRIDGEVILLE - OH	Distribution		138.00	13.09		20.00	1			0	0.00
113	BRIGGSDALE - OH	Distribution		40.00	13.80		42.40	2			0	0.00
114	BRIGGSDALE - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	1	3.00
115	BRIGGSDALE - OH	Distribution			0.00	0.00	0.00			REACTIVE SPECIAL	3
116	BROADACRE - OH	Distribution		138.00	13.09		9.37	1			0	0.00
117	BROKEN SWORD - OH	Distribution		69.00	13.09		6.25	1			0	0.00
118	BROOKSIDE (CS) - OH	Distribution		138.00	13.80		100.00	2			0	0.00
119	BROOM ROAD - OH	Distribution		69.00	13.09		20.00	1			0	0.00
120	BROOM ROAD - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
121	BUCKLEY ROAD - OH	Transmission		138.00	69.50	13.09	128.80	1			0	0.00
122	BUCYRUS - OH	Distribution		69.00	13.09		20.00	1			0	0.00
123	BUCYRUS - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	13.19
124	BUCYRUS CENTER - OH	Transmission		138.00	69.50	13.09	75.00	1			0	0.00
125	BUCYRUS CENTER - OH	Transmission		69.00	13.09		20.00	1			0	0.00
126	BYESVILLE - OH	Distribution		69.00	13.09		30.00	1			0	0.00
127	CADIZ - OH	Distribution		69.00	13.09		10.50	1			0	0.00
128	CAIRO - OH	Distribution		69.00	12.99		3.92	1			0	0.00
129	CALCUTTA - OH	Distribution		69.00	13.09		20.00	1			0	0.00
130	CALDWELL - OH	Transmission		138.00	13.09		20.00	1			0	0.00
131	CALDWELL - OH	Transmission		138.00	34.50		9.37	1			0	0.00
132	CALIFORNIA - OH	Distribution		69.00	13.09		25.00	1			0	0.00
133	CAMBRIDGE - OH	Distribution		34.50	12.00		10.50	1			0	0.00
134	CAMBRIDGE - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1	9.60
135	CAMBRIDGE - OH	Distribution		34.50	4.00		7.50	1			0	0.00
136	CAMP SHERMAN - OH	Distribution		69.00	13.09		20.00	1			0	0.00
137	CAMP SHERMAN - OH	Distribution		69.00	13.00		2.00	1			0	0.00
138	CANAL ROAD - OH	Transmission		69.00	23.00		12.50	1			0	0.00
139	CANAL ROAD - OH	Transmission		138.00	69.00	34.50	84.00	1			0	0.00
140	CANAL STREET - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	3	23.40
141	CANAL STREET - OH	Distribution		138.00	13.80	13.80	252.00	3			0	0.00
142	CANAL STREET - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	3	21.60
143	CAREY SW - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	9.60
144	CARROLLTON - OH	Distribution		138.00	13.09		40.00	2			0	0.00
145	CARROTHERS - OH	Distribution		69.00	13.09		5.25	1			0	0.00
146	CARROTHERS - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.60
147	CENTER STREET - OH	Distribution		69.00	13.09		20.00	1			0	0.00
148	CENTERBURG - OH	Distribution		138.00	35.40	13.80	50.00	1			0	0.00
149	CENTRAL AVENUE (OP) - OH	Distribution		34.50	4.36		9.38	1			0	0.00
150	CENTRAL PORTSMOUTH - OH	Transmission		69.00	7.20		9.38	1			0	0.00
151	CENTRAL PORTSMOUTH - OH	Transmission		138.00	69.00	34.50	130.00	1			0	0.00
152	CHATFIELD - OH	Transmission		138.00	69.50	13.09	75.00	1			0	0.00
153	CHERRY AVENUE - OH	Distribution		69.00	12.00		10.00	2			0	0.00
154	CIRCLEVILLE - OH	Transmission		138.00	69.00	13.20	30.00	0	1		0	0.00
155	CIRCLEVILLE - OH	Transmission		138.00	13.20		30.00	1			0	0.00
156	CIRCLEVILLE - OH	Transmission		138.00	13.09		50.00	1			0	0.00
157	CIRCLEVILLE - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	12.00
158	CIRCLEVILLE - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	2	7.20
159	CIRCLEVILLE - OH	Transmission		138.00	69.00	13.20	30.00	1			0	0.00
160	CITIZENS - OH	Distribution		12.00	0.48		3.00	2			0	0.00
161	CLARK STREET - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	2	10.80
162	CLARK STREET - OH	Distribution		69.00	12.00		56.00	2			0	0.00
163	CLIFTMONT AVENUE - OH	Distribution		69.00	12.00		10.50	1			0	0.00
164	CLINTON - OH	Distribution		138.00	13.80	13.80	168.30	2			0	0.00
165	COAL GROVE - OH	Distribution		69.00	12.00		6.25	1			0	0.00
166	COLERAIN - OH	Distribution		69.00	13.09		9.38	1			0	0.00
167	COLUMBIA (CS) - OH	Distribution		40.00	13.20		15.00	1			0	0.00
168	COLUMBUS GROVE - OH	Distribution		69.00	12.47		8.40	1			0	0.00
169	COLUMBUS GROVE - OH	Distribution		69.00	13.09		2.50	1			0	0.00
170	CONESVILLE - OH	Distribution		69.00	12.00		2.50	1			0	0.00
171	CONESVILLE PLANT - OH	Transmission		345.00	138.00	34.50	675.00	1			0	0.00
172	CONESVILLE PLANT - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2	172.80
173	CONESVILLE PLANT - OH	Transmission		138.00	70.73	13.20	10.50	0	1		0	0.00
174	CONESVILLE PREPARATION PLANT - OH	Distribution		138.00	13.09		22.40	1			0	0.00
175	CONTINENTAL - OH	Distribution		69.00	13.09		7.00	1			0	0.00
176	COOLVILLE (CS) - OH	Distribution		69.00	13.20		10.50	1			0	0.00
177	COOLVILLE (CS) - OH	Distribution		69.00	13.09		9.38	1			0	0.00
178	COOPERMILL - OH	Distribution		69.00	13.09		9.38	1			0	0.00
179	COOPERMILL - OH	Distribution		69.00	4.00		9.38	1			0	0.00
180	COOPERMILL - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.39
181	COPELAND - OH	Distribution		69.00	13.20		10.50	1			0	0.00
182	COPELAND - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1
183	COPPERHEAD - OH	Distribution		34.50	7.20		333.00	1			0	0.00
184	CORNER - OH	Distribution		138.00	13.09		20.00	1			0	0.00
185	CORNERSTONE - OH	Distribution		69.00	13.09		40.00	2			0	0.00
186	CORRIDOR - OH	Transmission		345.00	138.00	34.50	675.00	1			0	0.00
187	CORRIDOR - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	115.20
188	CORRIDOR - OH	Transmission		138.00	34.50	13.80	100.00	2			0	0.00
189	CORWIN - OH	Distribution		138.00	13.09		45.00	2			0	0.00
190	COSHOCTON - OH	Distribution		69.00	12.00		22.40	1			0	0.00
191	COSHOCTON - OH	Distribution		69.00	4.00		8.40	0	1		0	0.00
192	COSHOCTON - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
193	COUNTY HOSPITAL - OH	Distribution		69.00	13.09		5.25	1			0	0.00
194	CRAWFIS COLLEGE - OH	Distribution		69.00	13.09		6.25	1			0	0.00
195	CRESTWOOD - OH	Distribution		34.50	13.09		40.00	2			0	0.00
196	CRIDERSVILLE - OH	Distribution		69.00	13.09		7.00	1			0	0.00
197	CROOKSVILLE - OH	Transmission		138.00	70.50	13.09	130.00	1			0	0.00
198	CROOKSVILLE - OH	Transmission		69.00	13.09		20.00	1			0	0.00
199	CROOKSVILLE - OH	Transmission		69.00	4.00		9.38	1			0	0.00
200	CROTON - OH	Distribution		34.50	13.80		6.25	1			0	0.00
201	CRYSTAL PARK - OH	Distribution		69.00	4.00		6.25	1			0	0.00
202	DAVIDSON (CS) - OH	Distribution		138.00	13.80		91.67	2			0	0.00
203	DAVIDSON (CS) - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	2	14.40
204	DAVON - OH	Distribution		69.00	13.20		11.20	1			0	0.00
205	DELANO - OH	Distribution		138.00	69.00	13.20	33.60	1			0	0.00
206	DELANO - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	28.80
207	DELANO - OH	Distribution		13.20	4.00		5.00	0	1		0	0.00
208	DELAWARE (CSP) - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	2	10.80
209	DELAWARE (CSP) - OH	Transmission		138.00	69.00	13.09	78.00	1			0	0.00
210	DELAWARE (CSP) - OH	Transmission		138.00	13.80		41.67	1			0	0.00
211	DELAWARE (CSP) - OH	Transmission		138.00	34.50	13.80	25.00	1			0	0.00
212	DELAWARE (CSP) - OH	Transmission		138.00	40.00	13.80	25.00	1			0	0.00
213	DELAWARE (CSP) - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	6.00
214	DELAWARE (CSP) - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	19.20
215	DELAWARE (CSP) - OH	Transmission		138.00	35.40	13.80	30.00	1			0	0.00
216	DELPHOS - OH	Distribution		69.00	13.09		19.88	2			0	0.00
217	DENNISON - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
218	DENNISON - OH	Transmission		69.00	36.20		20.00	1			0	0.00
219	DENNISON - OH	Transmission		34.50	4.00		6.00	2			0	0.00
220	DERWENT - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
221	DERWENT - OH	Distribution		69.00	13.20		9.38	1			0	0.00
222	DIAMOND STREET - OH	Transmission		69.00	23.00		7.50	1			0	0.00
223	DILLONVALE - OH	Distribution		69.00	13.09		7.50	1			0	0.00
224	DOGWOOD RIDGE - OH	Distribution		138.00	13.09		20.00	1			0	0.00
225	DON MARQUIS (OP-CS) (OVEC) - OH	Transmission		345.00						REACTOR	2	66.60
226	DON MARQUIS (OP-CS) (OVEC) - OH	Transmission		345.00	137.50	13.80	720.00	2			0	0.00
227	DON MARQUIS (OP-CS) (OVEC) - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2	115.20
228	DOW CHEMICAL-HANGING ROCK - OH	Distribution		69.00	12.00		12.50	2			0	0.00
229	DOW CHEMICAL-HEBRON - OH	Distribution		69.00	12.00		9.36	2			0	0.00
230	DRESDEN - OH	Distribution		69.00	12.00		10.50	1			0	0.00
231	DUBLIN(CS) - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	3	13.50
232	DUBLIN(CS) - OH	Distribution		138.00	13.80		150.00	3			0	0.00
233	DUCK CREEK - OH	Distribution		23.00	13.09		3.13	0	1		0	0.00
234	DUCK CREEK - OH	Distribution		138.00	13.09		22.40	1			0	0.00
235	DUEBER AVENUE - OH	Distribution		69.00	4.00		5.00	1			0	0.00
236	DUNKIRK (OP) - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	16.20
237	DUNKIRK (OP) - OH	Transmission		69.00	13.09		5.25	1			0	0.00
238	DUNKIRK (OP) - OH	Transmission		69.00	36.20		10.50	1			0	0.00
239	EAST AMSTERDAM - OH	Transmission		138.00	70.50	36.20	90.00	1			0	0.00
240	EAST ANTWERP - OH	Distribution		12.00	4.16		2.50	3			0	0.00
241	EAST ANTWERP - OH	Distribution		69.00	13.09		6.25	1			0	0.00
242	EAST BROAD STREET - OH	Transmission		138.00	13.80		30.00	1			0	0.00
243	EAST BROAD STREET - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	72.00
244	EAST BROAD STREET - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	4	12.30
245	EAST BROAD STREET - OH	Transmission		138.00	39.40	13.80	41.67	0	1		0	0.00
246	EAST BROAD STREET - OH	Transmission		40.00	0.00	0.00	0.00			STATCAP	1	10.80
247	EAST BROAD STREET - OH	Transmission		138.00	40.00	13.80	83.34	2			0	0.00
248	EAST BUCYRUS - OH	Distribution		69.00	13.09		9.37	1			0	0.00
249	EAST CAMBRIDGE - OH	Transmission		69.00	34.50		37.30	1			0	0.00
250	EAST CAMBRIDGE - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	21.60
251	EAST DELPHOS - OH	Distribution		69.00	13.09		7.00	1			0	0.00
252	EAST DOVER - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.39
253	EAST DOVER - OH	Distribution		69.00	13.09		9.38	1			0	0.00
254	EAST END FOSTORIA - OH	Distribution		69.00	4.36		9.38	1			0	0.00
255	EAST FREMONT - OH	Distribution		69.00	13.09		10.50	1			0	0.00
256	EAST FREMONT - OH	Distribution		69.00	4.36		9.37	1			0	0.00
257	EAST LANCASTER - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	16.20
258	EAST LANCASTER - OH	Distribution		69.00	12.00		14.38	2			0	0.00
259	EAST LEIPSIC - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	28.80
260	EAST LEIPSIC - OH	Transmission		69.00	36.20		25.00	1			0	0.00
261	EAST LEIPSIC - OH	Transmission		138.00	69.50	7.20	50.00	1			0	0.00
262	EAST LIMA - OH	Transmission		345.00	137.50	13.80	450.00	1			0	0.00
263	EAST LIMA - OH	Transmission		138.00	69.50	13.09	60.00	1			0	0.00
264	EAST LIMA - OH	Transmission		345.00	137.50	13.20	450.00	1			0	0.00
265	EAST LIMA - OH	Transmission		345.00	137.50	13.14	150.00	0	1		0	0.00
266	EAST LIVERPOOL - OH	Transmission		138.00	70.50	13.09	90.00	1			0	0.00
267	EAST LIVERPOOL - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
268	EAST LIVERPOOL-2ND STREET - OH	Distribution		69.00	4.00		8.00	2			0	0.00
269	EAST LIVERPOOL-E. END - OH	Distribution		69.00	4.00		4.69	1			0	0.00
270	EAST LOGAN - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
271	EAST MT CORY - OH	Distribution		34.50	13.09		3.13	1			0	0.00
272	EAST NEW CONCORD - OH	Distribution		138.00	13.09		9.38	1			0	0.00
273	EAST NEWARK - OH	Distribution		69.00	4.00		6.87	2			0	0.00
274	EAST NEWARK - OH	Distribution		69.00	13.09		25.00	1			0	0.00
275	EAST OTTAWA - OH	Transmission		69.00	13.09		20.00	1			0	0.00
276	EAST OTTAWA - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	19.79
277	EAST POINTE - OH	Distribution		138.00	13.09		20.00	1			0	0.00
278	EAST PROCTORVILLE - OH	Distribution		138.00	34.50		55.00	2			0	0.00
279	EAST SIDE (LIMA) - OH	Distribution		138.00	36.20		25.00	1			0	0.00
280	EAST SPRINGFIELD - OH	Distribution		69.00	4.00		3.75	1			0	0.00
281	EAST TIFFIN - OH	Distribution		69.00	13.09		10.50	1			0	0.00
282	EAST UNION - OH	Distribution		69.00	13.09		20.00	1			0	0.00
283	EAST WILLARD - OH	Distribution		69.00	13.09		10.50	1			0	0.00
284	EAST WOOSTER - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	43.20
285	EAST WOOSTER - OH	Transmission		138.00	69.50	13.09	84.00	1			0	0.00
286	EAST WOOSTER - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
287	EAST WOOSTER - OH	Transmission		138.00	13.09		20.00	1			0	0.00
288	EAST WOOSTER - OH	Transmission		138.00	24.14		25.00	0	1		0	0.00
289	EAST ZANESVILLE - OH	Transmission		138.00	69.00	12.00	50.00	1			0	0.00
290	EAST ZANESVILLE - OH	Transmission		138.00	69.00	13.00	50.00	1			0	0.00
291	EASTON STREET - OH	Distribution		69.00	13.09		42.40	2			0	0.00
292	EASTOWN ROAD - OH	Distribution		138.00	13.20		20.00	1			0	0.00
293	EASTOWN ROAD - OH	Distribution		138.00	13.09		22.40	1			0	0.00
294	EIGHTEEN STREET HEIGHTS - OH	Distribution		69.00	12.00		7.00	1			0	0.00
295	EIGHTEEN STREET HEIGHTS - OH	Distribution		69.00	13.09		9.38	1			0	0.00
296	ELIZABETH STREET - OH	Distribution		34.50	4.36		18.75	2			0	0.00
297	ELIZABETH STREET - OH	Distribution		4.16	0.00	0.00	0.00			Air Core Reactor	6	0.00
298	ELK - OH	Distribution		138.00	13.00		50.00	2			0	0.00
299	ELLIOTT - OH	Transmission		138.00	69.00	13.20	75.00	1			0	0.00
300	ETNA - OH	Distribution		69.00	13.09		5.60	1			0	0.00
301	ETNA - OH	Distribution		69.00	34.50		25.00	1			0	0.00
302	ETNA ROAD - OH	Distribution		40.00	13.80		22.00	1			0	0.00
303	ETNA ROAD - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	2	9.60
304	ETNA ROAD - OH	Distribution		40.00	13.80	4.30	41.80	2			0	0.00
305	FAIRCREST STREET - OH	Distribution		138.00	13.09		22.40	1			0	0.00
306	FAIRDALE - OH	Distribution		69.00	12.00		10.50	1			0	0.00
307	FAIRFIELD - OH	Distribution		69.00	4.36		10.50	1			0	0.00
308	FIFTH AVENUE - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	1	2.70
309	FIFTH AVENUE - OH	Distribution		138.00	39.40	13.80	41.67	1			0	0.00
310	FINDLAY - OH	Distribution		34.50	13.09		17.50	2			0	0.00
311	FINDLAY - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1	13.50
312	FINDLAY CENTER - OH	Transmission		138.00	69.50	35.00	75.00	1			0	0.00
313	FINDLAY CENTER - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	14.40
314	FINDLAY RESERVOIR#1 - OH	Distribution		34.50	2.40		0.50	3			0	0.00
315	FINDLAY RESERVOIR#2 - OH	Distribution		34.50	2.50		1.00	1			0	0.00
316	FONTAINE - OH	Distribution		69.00	4.36		3.00	1			0	0.00
317	FOREST (OP) - OH	Transmission		69.00	13.09		12.50	2			0	0.00
318	FOREST (OP) - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.39
319	FRAZEYSBURG - OH	Distribution		138.00	13.09		8.40	1			0	0.00
320	FREDERICKTOWN - OH	Distribution		69.00	13.09		20.00	1			0	0.00
321	FREMONT (OP) - OH	Transmission		138.00	69.50	13.09	130.00	1			0	0.00
322	FREMONT (OP) - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	19.79
323	FREMONT CENTER - OH	Transmission		69.00	13.09		6.25	1			0	0.00
324	FREMONT CENTER - OH	Transmission		138.00	70.50	13.09	130.00	1			0	0.00
325	FREMONT CENTER - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	43.20
326	FREMONT CENTER - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	13.19
327	FULTON (OP) - OH	Distribution		138.00	13.09		10.00	1			0	0.00
328	GAHANNA - OH	Distribution		138.00	13.80		50.00	1			0	0.00
329	GAHANNA - OH	Distribution		138.00	34.50	13.80	53.00	2			0	0.00
330	GAHANNA - OH	Distribution		138.00	35.40	13.80	50.00	1			0	0.00
331	GAHANNA - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	2	6.30
332	GALLOWAY ROAD - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	2	6.74
333	GALLOWAY ROAD - OH	Distribution		69.00	13.80		62.00	3			0	0.00
334	GAMBIER - OH	Distribution		69.00	12.00		20.00	1			0	0.00
335	GAVIN 1 AAS - OH	Generation		138.00	4.00		40.00	2			0	0.00
336	GAVIN 1 AAS - OH	Generation		138.00	13.80		150.00	3			0	0.00
337	GAVIN 138KV - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2	115.18
338	GAVIN 138KV - OH	Transmission		138.00	69.00	12.00	130.00	1			0	0.00
339	GAVIN 2 AAS - OH	Generation		138.00	13.80		150.00	3			0	0.00
340	GAVIN 2 AAS - OH	Generation		138.00	4.00		40.00	2			0	0.00
341	GAVIN 69KV - OH	Generation		69.00	4.00		10.50	1			0	0.00
342	GAVIN 69KV - OH	Generation		69.00	12.00		40.00	2			0	0.00
343	GAVIN DWAS - OH	Generation		138.00	4.16		20.00	1			0	0.00
344	GAVIN DWAS - OH	Generation		138.00	4.00		20.00	1			0	0.00
345	GAVIN PLANT - OH	Generation		138.00	4.00		20.00	1			0	0.00
346	GAVIN PLANT - OH	Generation		4.16	4.16		0.00	1			0	0.00
347	GAVIN PLANT - OH	Generation		4.16	0.60		40.50	31			0	0.00
348	GAVIN PLANT - OH	Generation		138.00	13.80		50.00	1			0	0.00
349	GAVIN UNIT (1) - OH	Generation		69.00	4.00		80.00	2			0	0.00
350	GAVIN UNIT (1) - OH	Generation		4.16			3.75	2			0	0.00
351	GAVIN UNIT (2) - OH	Generation		4.16				2			0	0.00
352	GAVIN UNIT (2) - OH	Generation		69.00	4.00		80.00	2			0	0.00
353	GAY STREET - OH	Distribution		138.00	13.80	13.80	252.00	3			0	0.00
354	GAY STREET - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	6	37.77
355	GENOA - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	2
356	GENOA - OH	Transmission		138.00	34.50	13.80	50.00	1			0	0.00
357	GENOA - OH	Transmission		138.00	69.00	12.00	130.00	1			0	0.00
358	GENOA - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2
359	GENOA - OH	Transmission		138.00	34.50	13.80	42.00	1			0	0.00
360	GENOA - OH	Transmission		138.00	70.50	13.80	90.00	1			0	0.00
361	GEORGES RUN - OH	Distribution		69.00	13.09		7.00	1			0	0.00
362	GINGER - OH	Distribution		69.00	12.47		6.25	0	1		0	0.00
363	GINGER - OH	Distribution		69.00	13.09		9.38	1			0	0.00
364	GLASSROCK - OH	Distribution		69.00	13.09		9.38	1			0	0.00
365	GLENMONT - OH	Distribution		34.50	12.00		1.50	1			0	0.00
366	GLENMOOR - OH	Distribution		69.00	12.00		20.00	1			0	0.00
367	GLENWOOD (OP) - OH	Distribution		69.00	12.00		4.20	1			0	0.00
368	GLOUSTER - OH	Distribution		13.20	4.00		3.00	1			0	0.00
369	GORSUCH - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2	86.40
370	GRANVILLE - OH	Distribution		69.00	13.09		25.00	1			0	0.00
371	GRANVILLE - OH	Distribution		69.00	12.00		22.40	1			0	0.00
372	GREELY - OH	Distribution		69.00	13.09		20.00	1			0	0.00
373	GREELY - OH	Distribution		69.00	4.36		6.25	1			0	0.00
374	GREENLAWN - OH	Transmission		138.00	69.50	13.09	75.00	1			0	0.00
375	GREENWICH - OH	Distribution		69.00	2.52		3.75	1			0	0.00
376	GREER - OH	Transmission		69.00	35.00		35.00	1			0	0.00
377	GREER - OH	Transmission		34.50	12.90		1.50	0	1		0	0.00
378	GREER - OH	Transmission		34.50	12.00		1.25	0	1		0	0.00
379	GREER - OH	Transmission		34.50	12.00		10.30	6			0	0.00
380	GROVES ROAD - OH	Transmission		138.00	13.80	13.80	168.00	2			0	0.00
381	GROVES ROAD - OH	Transmission		13.80	0.00	0.00	0.00			STATCAP	5	13.77
382	GROVES ROAD - OH	Transmission		46.00	0.00	0.00	0.00			STATCAP	1	10.80
383	GROVES ROAD - OH	Transmission		40.00	13.80		22.00	0	1		0	0.00
384	GROVES ROAD - OH	Transmission		138.00	13.80	13.80	83.30	0	1		0	0.00
385	GROVES ROAD - OH	Transmission		138.00	40.00	13.80	74.70	1			0	0.00
386	GROVES ROAD - OH	Transmission		138.00	13.80		50.00	1			0	0.00
387	GROVES ROAD - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1
388	HALL - OH	Distribution		138.00	13.80		91.67	2			0	0.00
389	HALL - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	2	14.40
390	HAMMONDSVILLE - OH	Transmission		69.00	4.36		6.25	1			0	0.00
391	HAMMONDSVILLE - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
392	HANERS - OH	Distribution		69.00	13.09		25.00	1			0	0.00
393	HANERS - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	3.59
394	HANGING ROCK - OH	Transmission		138.00	69.00	34.50	56.00	1			0	0.00
395	HARMAR - OH	Distribution		23.00	4.36		10.94	2			0	0.00
396	HARMAR HILL - OH	Distribution		138.00	13.09		20.00	1			0	0.00
397	HARPSTER - OH	Transmission		69.00	35.00		22.40	1			0	0.00
398	HARPSTER PUMPING - OH	Distribution		69.00	4.30		3.00	1			0	0.00
399	HARRISON - OH	Transmission		138.00	69.00	13.80	56.00	1			0	0.00
400	HAVILAND - OH	Transmission		138.00	70.50	13.09	90.00	1			0	0.00
401	HAVILAND - OH	Transmission		138.00	69.50	13.09	84.00	1			0	0.00
402	HEATH - OH	Transmission		138.00	69.00	12.00	128.80	1			0	0.00
403	HEATH - OH	Transmission		138.00	138.00	13.80	50.00	1			0	0.00
404	HEBRON - OH	Distribution		34.50	12.00		6.25	1			0	0.00
405	HEMLOCK - OH	Distribution		69.00	13.09		7.50	1			0	0.00
406	HESS STREET - OH	Distribution		138.00	13.80		166.68	4			0	0.00
407	HESS STREET - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	62.40
408	HESS STREET - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	2	12.60
409	HIGH STREET - OH	Distribution		69.00	12.00		8.40	1			0	0.00
410	HIGHLAND (CS) - OH	Distribution		69.00	13.20		44.90	2			0	0.00
411	HIGHLAND (CS) - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	13.19
412	HIGHLAND (CS) - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	2	5.40
413	HIGHLAND AVENUE - OH	Distribution		69.00	13.09		20.00	1			0	0.00
414	HIGHLAND TERRACE - OH	Distribution		69.00	13.09		10.50	1			0	0.00
415	HILLIARD - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	2	6.75
416	HILLIARD - OH	Distribution		69.00	13.80		69.80	3			0	0.00
417	HILLIARD - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.60
418	HILLNDALE - OH	Distribution		69.00	13.09		9.38	1			0	0.00
419	HILLVIEW DRIVE - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	52.80
420	HILLVIEW DRIVE - OH	Distribution		138.00	13.09		8.40	1			0	0.00
421	HOCKING - OH	Transmission		138.00	69.00	12.00	90.00	1			0	0.00
422	HOLRAN - OH	Distribution		69.00	13.09		3.13	1			0	0.00
423	HOLRAN - OH	Distribution		69.00	4.16		6.25	1			0	0.00
424	HOPEDALE - OH	Distribution		69.00	12.00		3.92	1			0	0.00
425	HOVER PARK - OH	Distribution		34.50	2.50		4.50	3			0	0.00
426	HOVER PARK - OH	Distribution		34.50	2.50		1.50	0	1		0	0.00
427	HOWARD - OH	Transmission		69.00	13.09		9.37	1			0	0.00
428	HOWARD - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	12.00
429	HOWARD - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2	115.18
430	HOWARD - OH	Transmission		138.00	69.50	11.00	90.00	1			0	0.00
431	HUGHES STREET - OH	Distribution		69.00	4.36		10.50	1			0	0.00
432	HUNTLEY - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	52.79
433	HUNTLEY - OH	Transmission		138.00	13.80		83.00	2			0	0.00
434	HUNTLEY - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	4	14.36
435	HUNTLEY - OH	Transmission		138.00	69.50	13.09	84.00	1			0	0.00
436	HUNTLEY - OH	Transmission		69.00	13.80		63.60	2			0	0.00
437	HUNTLEY - OH	Transmission		138.00	69.00	13.80	50.00	0	1		0	0.00
438	HYATT - OH	Transmission		138.00	35.40	13.80	50.00	1			0	0.00
439	ISLETA - OH	Distribution		34.50	13.09		3.75	1			0	0.00
440	JEFFERSON (CS) - OH	Distribution		69.00	13.20		21.00	2			0	0.00
441	JEFFERSON (CS) - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	2.70
442	JOHNSTOWN - OH	Distribution		34.50	13.80		9.38	1			0	0.00
443	JONES CITY - OH	Distribution		34.50	13.00		1.88	1			0	0.00
444	JUG STREET - OH	Transmission		138.00	35.40	13.80	50.00	1			0	0.00
445	JUG STREET - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1
446	JUG STREET - OH	Transmission		345.00	137.50	13.80	270.00	1			0	0.00
447	KAISER JUNCTION SW - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	27.00
448	KALIDA - OH	Transmission		69.00	34.50		20.00	1			0	0.00
449	KALIDA - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	18.00
450	KALIDA - OH	Transmission		69.00	13.09		14.63	2			0	0.00
451	KARL ROAD - OH	Distribution		138.00	13.80	13.80	251.30	3			0	0.00
452	KARL ROAD - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	5	25.20
453	KARL ROAD - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	3.60
454	KENNY - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	2	9.60
455	KENNY - OH	Distribution		138.00	13.80	13.80	168.00	2			0	0.00
456	KENTON - OH	Distribution		69.00	36.20		60.00	2			0	0.00
457	KENTON - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.39
458	KILLBUCK - OH	Distribution		34.50	7.20		1.88	0	1		0	0.00
459	KIMBERLY - OH	Distribution		138.00	13.09		40.00	2			0	0.00
460	KIMBOLTON - OH	Distribution		69.00	13.09		9.38	1			0	0.00
461	KIRK - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	3.59
462	KIRK - OH	Transmission		138.00	69.00	34.00	90.00	1			0	0.00
463	KOSSUTH - OH	Distribution		69.00	13.09		5.25	1			0	0.00
464	LAFAYETTE (OP) - OH	Distribution		69.00	13.09		7.00	1			0	0.00
465	LANCASTER - OH	Distribution		69.00	12.00		22.40	1			0	0.00
466	LANCASTER - OH	Distribution		69.00	4.00		18.75	3			0	0.00
467	LANCASTER - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	27.00
468	LANCASTER JUNCTION - OH	Distribution		69.00	12.00		22.40	1			0	0.00
469	LANCASTER JUNCTION - OH	Distribution		69.00	13.09		25.00	1			0	0.00
470	LATTY - OH	Distribution		69.00	13.09		3.75	1			0	0.00
471	LAYMAN - OH	Distribution		138.00	13.09		20.00	1			0	0.00
472	LAZELLE - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	3.59
473	LAZELLE - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.60
474	LAZELLE - OH	Distribution		69.00	13.80		44.80	2			0	0.00
475	LEE - OH	Distribution		69.00	12.00		10.50	1			0	0.00
476	LEIPSIC - OH	Distribution		69.00	13.09		14.63	2			0	0.00
477	LEXINGTON - OH	Distribution		69.00	13.09		6.25	1			0	0.00
478	LICK - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	43.20
479	LICK - OH	Transmission		138.00	69.00	13.20	90.00	3			0	0.00
480	LINCOLN STREET - OH	Distribution		69.00	13.80		60.00	2			0	0.00
481	LINDEN AVENUE - OH	Distribution		69.00	13.09		25.00	1			0	0.00
482	LINDEN AVENUE - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
483	LINDEN AVENUE - OH	Distribution		69.00	4.00		10.50	1			0	0.00
484	LINWORTH - OH	Distribution		138.00	40.00	13.80	41.67	1			0	0.00
485	LINWORTH - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	2	7.18
486	LINWORTH - OH	Distribution		138.00	13.80		41.67	1			0	0.00
487	LIVINGSTON AVENUE - OH	Distribution		40.00	13.00		44.00	2			0	0.00
488	LOCK SEVENTEEN - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.60
489	LOCK SEVENTEEN - OH	Distribution		69.00	13.00		10.50	1			0	0.00
490	LOCKWOOD ROAD - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	43.20
491	LOUISVILLE - OH	Distribution		69.00	12.00		20.00	1			0	0.00
492	MADISON (CS) - OH	Distribution		69.00	13.80		20.00	1			0	0.00
493	MADISON (CS) - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	7.19
494	MADISONBURG - OH	Distribution		69.00	13.09		20.00	1			0	0.00
495	MAHONING ROAD - OH	Distribution		69.00	12.00		22.40	1			0	0.00
496	MAPLE GROVE - OH	Distribution		69.00	13.09		9.37	1			0	0.00
497	MARION ROAD - OH	Transmission		40.00	13.00		12.50	0	1		0	0.00
498	MARION ROAD - OH	Transmission		138.00	40.00	13.00	83.33	1			0	0.00
499	MARION ROAD - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	3	10.58
500	MARION ROAD - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	52.79
501	MARION ROAD - OH	Transmission		138.00	39.40	13.80	166.66	2			0	0.00
502	MARK CENTER SW - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	12.00
503	MARTINS FERRY - OH	Distribution		69.00	12.00		10.50	1			0	0.00
504	MARTINSBURG ROAD - OH	Distribution		69.00	13.09		20.00	1			0	0.00
505	MARYSVILLE - OH	Transmission		765.00	345.00	34.50	750.00	0	1		0	0.00
506	MARYSVILLE - OH	Transmission		765.00						REACTOR	1	100.00
507	MAULE ROAD - OH	Distribution		69.00	13.09		20.00	1			0	0.00
508	MCCOMB (CS) - OH	Transmission		138.00	39.40	13.80	100.00	2			0	0.00
509	MCCOMB (CS) - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	86.40
510	MCCOMB (CS) - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	1	3.59
511	MCCOMB (OP) - OH	Distribution		34.50	13.09		15.63	2			0	0.00
512	MCDERMOTT - OH	Distribution		34.50	13.80		3.00	1			0	0.00
513	MEIGS (CS) - OH	Distribution		69.00	13.00		10.50	1			0	0.00
514	MEIGS (CS) - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	3.60
515	MEIGS (CS) - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	2	9.60
516	MEIGS (CS) - OH	Distribution		69.00	13.09		9.38	1			0	0.00
517	MEIGS NO. 1 - OH	Distribution		138.00	34.50		33.40	2			0	0.00
518	MEMORIAL DRIVE - OH	Distribution		69.00	13.09		22.40	1			0	0.00
519	MIFFLIN - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1
520	MIFFLIN - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	3.15
521	MIFFLIN - OH	Distribution		138.00	13.80		150.00	3			0	0.00
522	MILES AVENUE - OH	Distribution		138.00	13.09		20.00	1			0	0.00
523	MILL CREEK (CSP) - OH	Distribution		138.00	24.80		40.00	2			0	0.00
524	MILL CREEK (CSP) - OH	Distribution		138.00	13.09		50.00	2			0	0.00
525	MILL STREET - OH	Distribution		69.00	12.00		10.50	1			0	0.00
526	MILLBROOK PARK - OH	Transmission		138.00	69.00	34.50	75.00	1			0	0.00
527	MILLBROOK PARK - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	52.80
528	MILLBROOK PARK - OH	Transmission		138.00	13.09		12.00	1			0	0.00
529	MILLERSBURG - OH	Distribution		34.50	4.36		2.30	1			0	0.00
530	MILLERSBURG - OH	Distribution		34.50	4.33		2.00	1			0	0.00
531	MILLWOOD - OH	Distribution		138.00	13.09		12.00	1			0	0.00
532	MINERVA - OH	Distribution		69.00	13.09		20.00	1			0	0.00
533	MINFORD - OH	Distribution		69.00	12.00		10.50	1			0	0.00
534	MINK - OH	Distribution		138.00	35.40	13.80	30.00	1			0	0.00
535	MONROE STREET - OH	Distribution		69.00	12.00		20.00	1			0	0.00
536	MORSE ROAD - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	72.00
537	MORSE ROAD - OH	Distribution		138.00	13.80	13.80	242.30	3			0	0.00
538	MORSE ROAD - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	5	36.00
539	MOUND STREET - OH	Distribution		138.00	13.80	13.80	168.00	2			0	0.00
540	MOUND STREET - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	2	7.18
541	MOUNT STERLING - OH	Distribution		69.00	12.00		5.25	1			0	0.00
542	MOUNT VERNON (OP) - OH	Distribution		69.00	4.00		9.36	2			0	0.00
543	MOUNT VERNON (OP) - OH	Distribution		69.00	12.00		10.50	1			0	0.00
544	MUNGEN - OH	Distribution		34.50	13.00		5.00	1			0	0.00
545	MUSKINGUM RIVER 138KV - OH	Transmission		138.00	69.00	13.09	84.00	1			0	0.00
546	NEELYSVILLE - OH	Distribution		69.00	13.09		9.38	1			0	0.00
547	NEFFS - OH	Distribution		69.00	12.00		4.68	1			0	0.00
548	NEGLEY - OH	Distribution		138.00	13.09		20.00	1			0	0.00
549	NEW LEXINGTON - OH	Distribution		69.00	13.09		20.00	1			0	0.00
550	NEW LIBERTY - OH	Transmission		138.00	13.09		20.00	1			0	0.00
551	NEW LIBERTY - OH	Transmission		138.00	34.50		60.00	2			0	0.00
552	NEW LIBERTY - OH	Transmission		138.00	70.50	36.20	90.00	1			0	0.00
553	NEW LIBERTY - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	9.60
554	NEW LIBERTY - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	43.20
555	NEW MATAMORAS - OH	Distribution		23.00	13.09		6.25	1			0	0.00
556	NEW PHILADELPHIA - OH	Distribution		69.00	36.20		40.00	2			0	0.00
557	NEW PHILADELPHIA - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.39
558	NEWARK - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
559	NEWARK - OH	Distribution		69.00	4.36		14.00	2			0	0.00
560	NEWARK CENTER - OH	Transmission		138.00	69.00	12.00	128.00	1			0	0.00
561	NEWCOMERSTOWN - OH	Transmission		69.00	34.50	12.00	39.00	1			0	0.00
562	NEWCOMERSTOWN - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
563	NEWCOMERSTOWN - OH	Transmission		138.00	69.00	12.00	56.00	1			0	0.00
564	NOBLE CORRECTIONAL - OH	Distribution		34.50	12.00		4.20	1			0	0.00
565	NORTH BALTIMORE - OH	Distribution		34.50	13.09		20.00	1			0	0.00
566	NORTH BALTIMORE - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1	7.20
567	NORTH BELLVILLE - OH	Transmission		138.00	69.50	13.09	56.00	1			0	0.00
568	NORTH BELLVILLE - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	10.80
569	NORTH BLUFFTON - OH	Distribution		7.62	0.28		1.00	3			0	0.00
570	NORTH BLUFFTON - OH	Distribution		69.00	13.00		1.50	1			0	0.00
571	NORTH BUCYRUS - OH	Distribution		69.00	4.36		6.25	1			0	0.00
572	NORTH CAMBRIDGE - OH	Distribution		69.00	4.36		7.50	1			0	0.00
573	NORTH CAMBRIDGE - OH	Distribution		69.00	13.09		7.50	1			0	0.00
574	NORTH CANTON - OH	Distribution		69.00	13.09		25.00	1			0	0.00
575	NORTH COSHOCTON - OH	Transmission		69.00	34.50	12.00	39.00	1			0	0.00
576	NORTH COSHOCTON - OH	Transmission		69.00	12.00		22.40	1			0	0.00
577	NORTH COSHOCTON - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	18.00
578	NORTH CROWN CITY - OH	Transmission		138.00	13.00		7.50	2			0	0.00
579	NORTH CROWN CITY - OH	Transmission		138.00	13.09		7.50	2			0	0.00
580	NORTH DELPHOS - OH	Transmission		138.00	70.50	36.20	90.00	1			0	0.00
581	NORTH DELPHOS - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	18.00
582	NORTH END FOSTORIA - OH	Distribution		69.00	13.09		15.62	2			0	0.00
583	NORTH FINDLAY - OH	Transmission		138.00	69.50	35.00	84.00	1			0	0.00
584	NORTH FINDLAY - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1
585	NORTH FINDLAY - OH	Transmission		138.00	35.00		90.00	1			0	0.00
586	NORTH FINDLAY - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	43.20
587	NORTH FINDLAY - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	15.30
588	NORTH FREDERICKSBURG - OH	Distribution		69.00	12.00		7.00	1			0	0.00
589	NORTH FREMONT - OH	Distribution		69.00	13.09		20.00	1			0	0.00
590	NORTH HEBRON - OH	Distribution		69.00	34.50		20.00	1			0	0.00
591	NORTH HICKSVILLE - OH	Distribution		69.00	13.09		15.63	2			0	0.00
592	NORTH IRONTON - OH	Distribution		69.00	13.09		9.38	1			0	0.00
593	NORTH LEIPSIC - OH	Distribution		69.00	13.09		20.00	1			0	0.00
594	NORTH LEXINGTON - OH	Distribution		138.00	13.00		20.00	1			0	0.00
595	NORTH LOGAN - OH	Distribution		69.00	4.00		6.00	1			0	0.00
596	NORTH MCCONNELSVILLE - OH	Distribution		69.00	13.09		9.38	1			0	0.00
597	NORTH MIDDLEPOINT - OH	Distribution		69.00	13.09		5.25	1			0	0.00
598	NORTH MOUNT VERNON - OH	Distribution		69.00	4.00		9.37	1			0	0.00
599	NORTH MUSKINGUM - OH	Transmission		138.00	69.00	12.00	50.00	1			0	0.00
600	NORTH NEWARK - OH	Transmission		69.00	4.00		3.12	1			0	0.00
601	NORTH NEWARK - OH	Transmission		138.00	69.00	4.00	80.00	2			0	0.00
602	NORTH NEWARK - OH	Transmission		138.00	13.09		25.00	1			0	0.00
603	NORTH NEWARK - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	12.00
604	NORTH NEWARK - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	57.60
605	NORTH SPENCERVILLE - OH	Distribution		69.00	13.09		20.00	1			0	0.00
606	NORTH STRASBURG - OH	Distribution		138.00	4.33	0.00	2.50	1			0	0.00
607	NORTH UPPER SANDUSKY - OH	Distribution		69.00	13.09		20.00	1			0	0.00
608	NORTH WALDO - OH	Transmission		138.00	69.00	7.20	40.00	1			0	0.00
609	NORTH WALDO - OH	Transmission		69.00	13.09		7.00	1			0	0.00
610	NORTH WELLSVILLE - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	13.19
611	NORTH WELLSVILLE - OH	Distribution		69.00	12.00		10.50	1			0	0.00
612	NORTH WILLARD - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	13.19
613	NORTH WILLARD - OH	Distribution		69.00	13.09		20.00	1			0	0.00
614	NORTH WOODCOCK - OH	Transmission		138.00	69.50	35.50	50.00	1			0	0.00
615	NORTH WOODCOCK - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	4.80
616	NORTH WOOSTER - OH	Distribution		69.00	12.00		10.50	1			0	0.00
617	NORTH ZANESVILLE - OH	Distribution		138.00	13.09		47.40	2			0	0.00
618	NORTHEAST FINDLAY - OH	Transmission		138.00	36.20		30.00	1			0	0.00
619	NORTHWEST LIMA - OH	Distribution		138.00	13.09		20.00	1			0	0.00
620	NORVAL PARK - OH	Distribution		69.00	4.00		10.50	1			0	0.00
621	OAKLAND - OH	Distribution		69.00	12.00		12.00	2			0	0.00
622	OAKLAND - OH	Distribution		69.00			12.00	2			0	0.00
623	OAKWOOD ROAD - OH	Distribution		69.00	12.00		20.00	1			0	0.00
624	OERTELS CORNERS - OH	Distribution		69.00	12.00		22.40	1			0	0.00
625	OHIO CENTRAL - OH	Transmission		34.50	13.09		5.00	0	1		0	0.00
626	OHIO CENTRAL - OH	Transmission		138.00	69.00	12.00	56.00	0	1		0	0.00
627	OHIO CENTRAL - OH	Transmission		69.00	34.50		30.00	0	1		0	0.00
628	OHIO CENTRAL - OH	Transmission		138.00	69.00	13.09	78.00	0	1		0	0.00
629	OHIO CENTRAL - OH	Transmission		69.00	4.00		4.25	0	1		0	0.00
630	OHIO CITY - OH	Distribution		34.50	13.09		4.69	1			0	0.00
631	OSU - OH	Distribution		138.00	13.80		50.00	1			0	0.00
632	OSU - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	1	7.20
633	OTTOVILLE - OH	Distribution		69.00	13.09		4.68	1			0	0.00
634	OTTOVILLE - OH	Distribution		69.00	12.47		4.69	1			0	0.00
635	OTWAY - OH	Distribution		34.50	12.00		7.50	1			0	0.00
636	OWENS CORNING SW - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	27.00
637	PACKARD - OH	Distribution		138.00	13.20		20.00	1			0	0.00
638	PANDORA - OH	Distribution		69.00	13.09		9.38	1			0	0.00
639	PARK - OH	Distribution		69.00	13.80		33.60	1			0	0.00
640	PARK - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	2.70
641	PARSONS - OH	Distribution		40.00	13.80		40.00	2			0	0.00
642	PARSONS - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	2	6.30
643	PAULDING - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
644	PAULDING - OH	Distribution		69.00	13.09		20.00	1			0	0.00
645	PAYNE - OH	Distribution		69.00	13.09		7.00	1			0	0.00
646	PEACH MOUNT - OH	Distribution		13.20	4.00		6.25	1			0	0.00
647	PEACH MOUNT - OH	Distribution		34.50	12.00		6.00	1			0	0.00
648	PEKIN - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	9.60
649	PEKIN - OH	Transmission		69.00	13.09		5.25	1			0	0.00
650	PENNSVILLE - OH	Distribution		69.00	13.09		6.25	1			0	0.00
651	PITTSBURGH AVENUE - OH	Distribution		69.00	13.09		11.20	2			0	0.00
652	PLEASANT GROVE - OH	Distribution		69.00	13.09		6.25	1			0	0.00
653	PLEASANT STREET - OH	Transmission		69.00	34.50		9.38	1			0	0.00
654	PLEASANT STREET - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	10.80
655	PLEASANT STREET - OH	Transmission		69.00	13.09		25.00	1			0	0.00
656	PLEASANTVILLE - OH	Distribution		69.00	13.09		9.38	1			0	0.00
657	PLYMOUTH HEIGHTS - OH	Distribution		69.00	12.00		9.38	1			0	0.00
658	POLARIS - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	2	14.40
659	POLARIS - OH	Distribution		138.00	35.40	13.80	100.00	2			0	0.00
660	POMEROY(OP) - OH	Distribution		34.50	12.00		6.25	1			0	0.00
661	PORTERFIELD - OH	Distribution		138.00	13.09		14.00	1			0	0.00
662	POWELSON - OH	Distribution		138.00	13.09		20.00	1			0	0.00
663	POWHATAN - OH	Distribution		69.00	4.00		5.00	2			0	0.00
664	PROCTORVILLE - OH	Distribution		34.50	12.00		6.25	1			0	0.00
665	PROMWAY - OH	Distribution		138.00	13.09		20.00	1			0	0.00
666	QUARRY ROAD - OH	Distribution		69.00	12.00		22.40	1			0	0.00
667	RACINE HYDRO - OH	Transmission		69.00	13.09		9.38	1			0	0.00
668	RALSTON - OH	Distribution		69.00	12.00		10.50	1			0	0.00
669	RARDEN - OH	Distribution		69.00	34.50	13.00	38.00	2			0	0.00
670	RAVEN - OH	Distribution		69.00	13.20		12.50	1			0	0.00
671	RAY - OH	Distribution		69.00	13.09		25.00	3			0	0.00
672	RAY - OH	Distribution		69.00	34.50		15.63	2			0	0.00
673	REDFIELD - OH	Distribution		69.00	12.00		1.50	1			0	0.00
674	REEDURBAN - OH	Transmission		138.00	69.00	13.09	54.00	1			0	0.00
675	REEDURBAN - OH	Transmission		138.00	13.09		22.40	1			0	0.00
676	RENO - OH	Distribution		138.00	13.09		20.00	1			0	0.00
677	REYNOLDSBURG - OH	Distribution		40.00	13.20	4.15	10.00	1			0	0.00
678	REYNOLDSBURG - OH	Distribution		7.62	0.00	0.00	0.00			STATCAP	1	2.70
679	RIO - OH	Distribution		138.00	13.20		34.00	2			0	0.00
680	RIO - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	3.00
681	RIVERVIEW (CSP) - OH	Distribution		138.00	13.80		44.80	2			0	0.00
682	RIVERVIEW (CSP) - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	36.00
683	RIVERVIEW (OP) - OH	Distribution		69.00	13.09		22.40	1			0	0.00
684	RIVERVIEW (OP) - OH	Distribution		69.00	4.36		6.25	1			0	0.00
685	RIVERVIEW (OP) - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
686	ROBB AVENUE - OH	Distribution		34.50	4.00		10.00	6			0	0.00
687	ROBERTS - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2	172.80
688	ROBERTS - OH	Transmission		345.00	138.00	34.50		1			0	0.00
689	ROBERTS - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	1	3.59
690	ROBERTS - OH	Transmission		345.00	138.00	34.50	675.00	1			0	0.00
691	ROBERTS - OH	Transmission		138.00	13.80		83.67	2			0	0.00
692	ROBERTSVILLE - OH	Distribution		69.00	13.09		5.25	1			0	0.00
693	ROBYVILLE - OH	Distribution		69.00	12.00		3.00	2			0	0.00
694	ROCKBRIDGE - OH	Distribution		69.00	12.00		9.38	1			0	0.00
695	ROCKHILL (OP) - OH	Transmission		138.00	34.65	11.00	49.66	6			0	0.00
696	ROCKHILL (OP) - OH	Transmission		138.00	13.09		20.00	1			0	0.00
697	ROCKHILL (OP) - OH	Transmission		138.00	35.00		50.00	1			0	0.00
698	ROSE FARM - OH	Distribution		69.00	13.09		4.68	1			0	0.00
699	ROSEMOUNT - OH	Distribution		69.00	13.09		9.38	1			0	0.00
700	ROSEMOUNT - OH	Distribution		69.00	34.50		20.00	1			0	0.00
701	ROSS - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	3	10.77
702	ROSS - OH	Transmission		12.00	0.00	0.00	0.00			Reactor	2
703	ROZELLE - OH	Distribution		138.00	13.09		20.00	1			0	0.00
704	RUHLMAN - OH	Distribution		69.00	13.00		20.00	1			0	0.00
705	RUTLAND - OH	Transmission		138.00	34.50		20.00	1			0	0.00
706	S.B.C. CONTAINERS - OH	Distribution		69.00	13.09		6.25	1			0	0.00
707	SAINT CLAIR AVENUE (CS) - OH	Distribution		138.00	13.80	13.80	93.30	0	1		0	0.00
708	SAINT CLAIR AVENUE (CS) - OH	Distribution		138.00	13.80	13.80	176.66	2			0	0.00
709	SAINT CLAIR AVENUE (CS) - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	72.00
710	SAINT CLAIR AVENUE (CS) - OH	Distribution		138.00	0.00	0.00	0.00			Air Core Reactor	6
711	SAINT CLAIR AVENUE (OP) - OH	Distribution		69.00	13.09		22.40	1			0	0.00
712	SAINT CLAIRSVILLE - OH	Distribution		69.00	12.00		7.00	1			0	0.00
713	SAINT GEORGE STREET - OH	Distribution		69.00	4.00		7.00	1			0	0.00
714	SAVANNAH AVENUE - OH	Distribution		69.00	22.90	13.09	80.00	2			0	0.00
715	SAVANNAH AVENUE - OH	Distribution		69.00	13.09		15.00	1			0	0.00
716	SAWMILL - OH	Transmission		138.00	34.50	13.80	149.37	2			0	0.00
717	SAWMILL - OH	Transmission		138.00	13.80		25.00	1			0	0.00
718	SAWMILL - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	86.40
719	SAWMILL - OH	Transmission		138.00	69.00	13.00	90.00	1			0	0.00
720	SCHOENBRUNN - OH	Distribution		69.00	12.00		22.40	1			0	0.00
721	SCHROYER AVENUE - OH	Transmission		69.00	13.09		20.00	1			0	0.00
722	SCHROYER AVENUE - OH	Transmission		69.00	23.00	13.09	39.20	0	1		0	0.00
723	SCHROYER AVENUE - OH	Transmission		69.00	4.00		6.25	1			0	0.00
724	SCIO - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.60
725	SCIOTO TRAIL (CS) - OH	Distribution		138.00	13.20	7.24	30.00	1			0	0.00
726	SCIOTOVILLE - OH	Distribution		69.00	12.00		9.38	1			0	0.00
727	SEAMAN - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
728	SEAMAN - OH	Transmission		138.00	69.00	13.09	90.00	1			0	0.00
729	SEAMAN - OH	Transmission		69.00	13.09		20.00	1			0	0.00
730	SEAMAN - OH	Transmission		69.00	13.20		6.25	0	1		0	0.00
731	SENECAVILLE - OH	Distribution		69.00	13.09		5.00	1			0	0.00
732	SEROCO AVENUE - OH	Distribution		69.00	4.00		15.62	2			0	0.00
733	SHADYSIDE - OH	Distribution		69.00	13.09		10.50	1			0	0.00
734	SHANNON - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	2	12.60
735	SHANNON - OH	Distribution		138.00	13.80		71.67	2			0	0.00
736	SHARON VALLEY - OH	Distribution		69.00	13.09		25.00	1			0	0.00
737	SHARP ROAD - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	19.20
738	SHARP ROAD - OH	Transmission		138.00	69.00	12.00	84.00	1			0	0.00
739	SHAWNEE - OH	Distribution		69.00	13.09		9.38	1			0	0.00
740	SHAWNEE ROAD - OH	Transmission		138.00	69.50	35.00	75.00	1			0	0.00
741	SHAWNEE ROAD - OH	Transmission		138.00	13.09		22.40	1			0	0.00
742	SHERWOOD - OH	Distribution		69.00	13.09		7.00	1			0	0.00
743	SHINNICK STREET - OH	Distribution		69.00	4.36		9.37	1			0	0.00
744	SHREVE - OH	Distribution		69.00	13.09		12.50	1			0	0.00
745	SLATE MILLS - OH	Distribution		69.00	13.20		10.50	1			0	0.00
746	SMITHVILLE - OH	Distribution		69.00	12.00		6.25	1			0	0.00
747	SOMERTON - OH	Transmission		138.00	69.00	12.00	50.00	1			0	0.00
748	SOMERTON - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	28.80
749	SOUTH BELMONT - OH	Distribution		69.00	13.09		12.50	1			0	0.00
750	SOUTH BERWICK - OH	Transmission		345.00	68.80	13.09	150.00	1			0	0.00
751	SOUTH CADIZ - OH	Transmission		69.00	12.00		5.25	1			0	0.00
752	SOUTH CADIZ - OH	Transmission		138.00	69.00	13.09	75.00	1			0	0.00
753	SOUTH CADIZ - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	9.60
754	SOUTH CAMBRIDGE - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
755	SOUTH CAMBRIDGE - OH	Transmission		69.00	34.50	12.00	39.00	1			0	0.00
756	SOUTH CAMBRIDGE - OH	Transmission		69.00	34.50		50.00	2			0	0.00
757	SOUTH CANTON 138KV - OH	Transmission		138.00	13.09		8.40	1			0	0.00
758	SOUTH CANTON 345KV - OH	Transmission		345.00	137.50	35.00	675.00	1			0	0.00
759	SOUTH CANTON 345KV - OH	Transmission		345.00	138.00	34.50	675.00	1			0	0.00
760	SOUTH CANTON 765KV - OH	Transmission		765.00	345.00	34.50	2250.00	3			0	0.00
761	SOUTH CONVOY - OH	Distribution		34.50	13.09		6.25	1			0	0.00
762	SOUTH COSHOCTON - OH	Transmission		34.50	12.00		2.50	0	1		0	0.00
763	SOUTH COSHOCTON - OH	Transmission		138.00	13.09		12.00	1			0	0.00
764	SOUTH COSHOCTON - OH	Transmission		69.00	34.50	12.00	39.20	1			0	0.00
765	SOUTH COSHOCTON - OH	Transmission		138.00	36.00	7.20	30.00	1			0	0.00
766	SOUTH COSHOCTON - OH	Transmission		138.00	69.00	12.00	75.00	1			0	0.00
767	SOUTH CUMBERLAND - OH	Transmission		138.00	69.00	34.50	84.00	1			0	0.00
768	SOUTH DELPHOS - OH	Distribution		69.00	13.09		10.50	1			0	0.00
769	SOUTH FINDLAY - OH	Distribution		34.50	13.09		40.00	2			0	0.00
770	SOUTH FINDLAY - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1	12.00
771	SOUTH FULTONHAM - OH	Distribution		69.00	4.00		3.75	1			0	0.00
772	SOUTH GRANVILLE - OH	Distribution		69.00	13.09		20.00	1			0	0.00
773	SOUTH GREENWICH - OH	Distribution		69.00	13.09		9.38	1			0	0.00
774	SOUTH HICKSVILLE - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	18.00
775	SOUTH HICKSVILLE - OH	Transmission		138.00	69.50	13.09	75.00	1			0	0.00
776	SOUTH KENTON - OH	Transmission		138.00	69.00	0.22	30.00	2			0	0.00
777	SOUTH KENTON - OH	Transmission		138.00	69.50	13.09	56.00	1			0	0.00
778	SOUTH KENTON - OH	Transmission		2.40	0.00	0.00	0.00			STATCAP	1
779	SOUTH LANCASTER - OH	Transmission		138.00	69.00	12.00	60.00	1			0	0.00
780	SOUTH LANCASTER - OH	Transmission		138.00	69.00	34.50	130.00	1			0	0.00
781	SOUTH LUCASVILLE - OH	Distribution		138.00	13.09		12.50	1			0	0.00
782	SOUTH MARTINS FERRY - OH	Distribution		69.00	13.09		22.40	1			0	0.00
783	SOUTH MILLERSBURG - OH	Transmission		138.00	35.00	7.20	25.00	1			0	0.00
784	SOUTH MILLERSBURG - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	6.00
785	SOUTH MORRAL - OH	Distribution		69.00	13.09		5.25	1			0	0.00
786	SOUTH NEWARK - OH	Distribution		69.00	12.00		40.00	2			0	0.00
787	SOUTH POINT - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	67.20
788	SOUTH POINT - OH	Transmission		34.50	12.00		9.38	1			0	0.00
789	SOUTH POINT - OH	Transmission		138.00	69.00	34.50	129.00	1			0	0.00
790	SOUTH POINT - OH	Transmission		138.00	34.50		25.00	1			0	0.00
791	SOUTH SIDE LIMA - OH	Distribution		34.50	13.09		20.00	1			0	0.00
792	SOUTH SIDE LIMA - OH	Distribution		34.50	4.00		3.75	1			0	0.00
793	SOUTH SOMERSET - OH	Distribution		69.00	13.09		7.00	1			0	0.00
794	SOUTH TIFFIN - OH	Transmission		138.00	69.30	6.90	50.00	1			0	0.00
795	SOUTH TORONTO - OH	Transmission		138.00	69.50	13.09	60.00	1			0	0.00
796	SOUTH VAN WERT - OH	Distribution		69.00	13.09		22.40	1			0	0.00
797	SOUTH VAN WERT - OH	Distribution		69.00	4.36		5.25	1			0	0.00
798	SOUTH VANLUE - OH	Distribution		69.00	13.09		9.38	1			0	0.00
799	SOUTH WOOSTER - OH	Distribution		23.00	4.00		3.75	1			0	0.00
800	SOUTHEAST LOGAN - OH	Distribution		69.00	12.00		10.50	1			0	0.00
801	SOUTHWEST LIMA - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	24.00
802	SOUTHWEST LIMA - OH	Transmission		345.00	137.50	13.80	450.00	1			0	0.00
803	SPARTA PUMPING - OH	Distribution		23.00	4.00		3.75	1			0	0.00
804	ST RITAS HOSP - OH	Distribution		34.50	4.16		18.60	2			0	0.00
805	STANLEY COURT - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	13.19
806	STANLEY COURT - OH	Transmission		69.00	13.09		20.00	1			0	0.00
807	STANTON STREET - OH	Distribution		69.00	13.09		8.40	1			0	0.00
808	STATE LINE - OH	Distribution		69.00	4.00		3.75	1			0	0.00
809	STEUBENVILLE - OH	Transmission		138.00	69.00	12.00	112.00	1			0	0.00
810	STEUBENVILLE PUMPING - OH	Distribution		69.00	4.00		4.20	1			0	0.00
811	STONE CREEK - OH	Distribution		34.50	13.09		2.00	1			0	0.00
812	STONE STREET - OH	Distribution		69.00	4.36		5.00	1			0	0.00
813	STONE STREET - OH	Distribution		69.00	13.09		20.00	1			0	0.00
814	STONY HOLLOW - OH	Distribution		69.00	13.09		20.00	1			0	0.00
815	STRASBURG - OH	Distribution		138.00	36.20		30.00	1			0	0.00
816	STRATTON (OP) - OH	Distribution		69.00	4.36		5.25	1			0	0.00
817	STROUDS RUN - OH	Transmission		138.00	69.00	13.20	30.00	1			0	0.00
818	STROUDS RUN - OH	Transmission		138.00	69.00	12.00	84.00	1			0	0.00
819	SUGAR HILL (OP) - OH	Distribution		69.00	13.09		20.00	1			0	0.00
820	SUGARCREEK TERMINAL - OH	Distribution		69.00	35.00		30.00	1			0	0.00
821	SUGARCREEK TERMINAL - OH	Distribution		138.00	13.09		22.40	1			0	0.00
822	SULPHUR SPRINGS - OH	Distribution		138.00	13.09		8.40	1			0	0.00
823	SUMMERFIELD - OH	Transmission		138.00	69.00	12.00	84.00	1			0	0.00
824	SUMMERFIELD - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
825	SUMMERHILL - OH	Distribution		69.00	13.09		20.00	1			0	0.00
826	SUNNYSIDE - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	115.20
827	SUNNYSIDE - OH	Transmission		138.00	13.09		20.00	1			0	0.00
828	SUNNYSIDE - OH	Transmission		138.00	23.00	6.90	30.00	3			0	0.00
829	SUNNYSIDE - OH	Transmission		138.00	23.00		41.66	1			0	0.00
830	SUNSET BOULEVARD - OH	Distribution		69.00	13.09		22.40	1			0	0.00
831	SUPERIOR (CS) - OH	Distribution		69.00	12.00		6.25	1			0	0.00
832	TAYLOR - OH	Distribution		138.00	34.50	13.80	46.67	1			0	0.00
833	THAYER ROAD - OH	Distribution		138.00	13.09		40.00	2			0	0.00
834	THIRD STREET - OH	Distribution		69.00	13.09		20.00	1			0	0.00
835	THORNVILLE - OH	Distribution		69.00	13.09		20.00	1			0	0.00
836	TIDD 138KV - OH	Transmission		138.00	69.00	34.50	130.00	1			0	0.00
837	TIDD 138KV - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2	115.20
838	TIDD 138KV - OH	Transmission		138.00	13.09		8.40	0	1		0	0.00
839	TIDD 345KV - OH	Transmission		138.00	0.00	0.00	0.00			2500A Air-Core Reactor	2
840	TIDD 345KV - OH	Transmission		345.00	137.50	13.80	450.00	1			0	0.00
841	TIDD 69KV - OH	Transmission		69.00	12.00		3.75	1			0	0.00
842	TIFFIN CENTER - OH	Transmission		138.00	69.50	13.09	50.00	1			0	0.00
843	TIFFIN TAP-OFF - OH	Distribution		69.00	13.09		9.37	1			0	0.00
844	TILTONSVILLE - OH	Transmission		69.00	13.09		10.50	1			0	0.00
845	TILTONSVILLE - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	19.20
846	TILTONSVILLE - OH	Transmission		138.00	69.00	12.00	90.00	1			0	0.00
847	TIMKEN - OH	Transmission		138.00	24.14		334.60	4			0	0.00
848	TIMKEN MERCY - OH	Distribution		69.00	4.00		10.50	2			0	0.00
849	TORONTO - OH	Distribution		69.00	13.09		20.00	1			0	0.00
850	TORREY - OH	Transmission		138.00	23.00	11.00	92.00	6			0	0.00
851	TORREY - OH	Transmission		138.00	69.00	12.00	90.00	1			0	0.00
852	TORREY - OH	Transmission		69.00	13.09		10.50	1			0	0.00
853	TORREY - OH	Transmission		23.00	12.00		1.25	0	1		0	0.00
854	TORREY - OH	Transmission		138.00	23.00	11.00	16.00	0	1		0	0.00
855	TORREY - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	115.20
856	TORREY - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	9.60
857	TOTTEN - OH	Distribution		34.50	2.30		1.00	1			0	0.00
858	TRABUE - OH	Distribution		138.00	13.80		83.34	2			0	0.00
859	TRABUE - OH	Distribution		138.00	69.50	13.80	128.80	1			0	0.00
860	TRABUE - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	2	14.40
861	TRENT - OH	Distribution		138.00	34.50	13.80	46.67	1			0	0.00
862	TRENT - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	28.00
863	TWO RIDGES - OH	Distribution		69.00	12.00		20.00	1			0	0.00
864	UPPER SANDUSKY - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.39
865	UPPER SANDUSKY - OH	Distribution		69.00	13.09		20.00	1			0	0.00
866	UTICA (OP) - OH	Distribution		69.00	13.09		25.00	1			0	0.00
867	VAN WERT - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	16.20
868	VAN WERT - OH	Distribution		69.00	4.36		6.25	1			0	0.00
869	VAN WERT - OH	Distribution		69.00	13.09		22.40	1			0	0.00
870	VIGO - OH	Distribution		69.00	13.20		10.50	0	1		0	0.00
871	VIGO - OH	Distribution		69.00	13.09		20.00	1			0	0.00
872	VINE - OH	Distribution		138.00	13.80		91.67	2			0	0.00
873	VINE - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	86.40
874	VINE - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	3	17.97
875	VINE - OH	Distribution		138.00	13.80	13.80	93.30	1			0	0.00
876	WADE - OH	Distribution		23.00	13.09		4.20	1			0	0.00
877	WAGENHALS - OH	Transmission		138.00	23.50	7.20	30.00	1			0	0.00
878	WAGENHALS - OH	Transmission		138.00	69.00	23.00	84.00	1			0	0.00
879	WAGENHALS - OH	Transmission		138.00	70.50	13.09	130.00	1			0	0.00
880	WAGENHALS - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	115.20
881	WAKEFIELD - OH	Transmission		138.00	13.09		10.50	1			0	0.00
882	WALDO - OH	Distribution		69.00	12.00		3.75	1			0	0.00
883	WALDO - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.60
884	WALNUT CREEK - OH	Distribution		69.00	13.09		9.38	1			0	0.00
885	WALNUT CREEK - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	7.20
886	WAPAKONETA SW - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	12.00
887	WARSAW - OH	Distribution		34.50	12.00		3.75	1			0	0.00
888	WATER STREET - OH	Distribution		34.50	4.00		3.75	1			0	0.00
889	WATER STREET - OH	Distribution		34.50	12.00		4.68	1			0	0.00
890	WATERFORD (CSP) - OH	Distribution		23.00	13.09		7.95	2			0	0.00
891	WAVERLY - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	57.60
892	WAVERLY - OH	Transmission		138.00	69.00	13.53	30.00	1			0	0.00
893	WAVERLY - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	2	5.40
894	WAYVIEW - OH	Transmission		138.00	13.09		22.40	1			0	0.00
895	WAYVIEW - OH	Transmission		138.00	69.00	12.00	130.00	1			0	0.00
896	WEST ALIKANNA - OH	Distribution		69.00	13.09		6.25	1			0	0.00
897	WEST BELLAIRE - OH	Transmission		138.00	69.00	12.00	115.00	1			0	0.00
898	WEST BENTON - OH	Distribution		69.00	13.09		9.38	1			0	0.00
899	WEST CANTON - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	9.60
900	WEST CANTON - OH	Transmission		138.00	36.20		20.00	1			0	0.00
901	WEST CANTON - OH	Transmission		138.00	69.50	13.09	130.00	1			0	0.00
902	WEST CANTON - OH	Transmission		138.00	13.09		22.40	1			0	0.00
903	WEST CANTON - OH	Transmission		69.00	36.20		25.00	1			0	0.00
904	WEST CANTON - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	62.40
905	WEST COSHOCTON - OH	Transmission		138.00	69.00	13.09	56.00	1			0	0.00
906	WEST DOVER - OH	Transmission		138.00	69.50	13.09	90.00	1			0	0.00
907	WEST END FOSTORIA - OH	Transmission		69.00	4.36		6.25	1			0	0.00
908	WEST END FOSTORIA - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	21.60
909	WEST END FOSTORIA - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	57.59
910	WEST END FOSTORIA - OH	Transmission		69.00	4.16		3.75	1			0	0.00
911	WEST END FOSTORIA - OH	Transmission		138.00	69.50	13.09	75.00	1			0	0.00
912	WEST FOURTH STREET - OH	Distribution		34.50	4.16		6.25	1			0	0.00
913	WEST FREMONT - OH	Distribution		69.00	4.36		6.25	1			0	0.00
914	WEST GALION - OH	Distribution		69.00	13.09		9.38	1			0	0.00
915	WEST GRANVILLE - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
916	WEST GRANVILLE - OH	Distribution		69.00	12.00		10.50	1			0	0.00
917	WEST HEBRON - OH	Transmission		34.50	34.50		25.00	1			0	0.00
918	WEST HEBRON - OH	Transmission		138.00	69.00	34.50	128.80	1			0	0.00
919	WEST HEBRON - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	2	4.80
920	WEST HICKSVILLE - OH	Distribution		69.00	13.09		10.50	1			0	0.00
921	WEST LAFAYETTE - OH	Distribution		34.50	13.09		9.38	1			0	0.00
922	WEST LAFAYETTE - OH	Distribution		34.50	12.00		4.68	0	1		0	0.00
923	WEST LANCASTER - OH	Transmission		138.00	69.00	12.00	197.20	2			0	0.00
924	WEST LANCASTER - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	72.00
925	WEST LANCASTER - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
926	WEST LIMA - OH	Transmission		138.00	35.00		265.00	2			0	0.00
927	WEST LIMA - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	46.08
928	WEST LOGAN - OH	Distribution		69.00	12.00		20.00	1			0	0.00
929	WEST LONGLEY - OH	Distribution		69.00	2.50		2.00	1			0	0.00
930	WEST LOUISVILLE - OH	Distribution		69.00	12.00		19.88	2			0	0.00
931	WEST LOUISVILLE - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.89
932	WEST MALTA - OH	Distribution		69.00	12.00		6.25	1			0	0.00
933	WEST MALTA - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.60
934	WEST MELROSE - OH	Distribution		34.50	13.09		22.40	1			0	0.00
935	WEST MILLERSBURG - OH	Distribution		138.00	36.20		25.00	1			0	0.00
936	WEST MILLERSBURG - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
937	WEST MILLERSBURG - OH	Distribution		138.00	69.00	34.50	90.00	1			0	0.00
938	WEST MILLERSPORT - OH	Transmission		345.00	137.50	13.80	900.00	2			0	0.00
939	WEST MILLERSPORT - OH	Transmission		138.00	69.00	13.09	130.00	0	1		0	0.00
940	WEST MILLERSPORT - OH	Transmission		138.00	70.50	13.09	78.00	0	1		0	0.00
941	WEST MORRICAL - OH	Distribution		34.50	2.52		4.69	1			0	0.00
942	WEST MOULTON - OH	Transmission		69.00	13.09		20.00	1			0	0.00
943	WEST MOULTON - OH	Transmission		138.00	70.50	36.20	200.00	1			0	0.00
944	WEST MOUNT VERNON - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	13.20
945	WEST MOUNT VERNON - OH	Transmission		138.00	69.00	4.00	30.00	1			0	0.00
946	WEST MOUNT VERNON - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	52.60
947	WEST NEW PHILADELPHIA - OH	Transmission		138.00	13.09		30.50	2			0	0.00
948	WEST NEW PHILADELPHIA - OH	Transmission		138.00	69.00	12.00	128.80	1			0	0.00
949	WEST NEW PHILADELPHIA - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	72.00
950	WEST NEW PHILADELPHIA - OH	Transmission		138.00	34.50	4.00	15.00	1			0	0.00
951	WEST OAKWOOD - OH	Distribution		69.00	13.09		7.00	1			0	0.00
952	WEST PHILO - OH	Distribution		138.00	13.09		8.40	1			0	0.00
953	WEST TORONTO - OH	Distribution		69.00	13.09		10.50	1			0	0.00
954	WEST TRINWAY - OH	Distribution		138.00	13.09		20.00	1			0	0.00
955	WEST VAN WERT - OH	Transmission		69.00	35.00		25.00	1			0	0.00
956	WEST WOOSTER - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.39
957	WEST WOOSTER - OH	Distribution		69.00	12.00		22.40	1			0	0.00
958	WESTERVILLE - OH	Distribution		69.00	13.80		44.80	2			0	0.00
959	WHEELERSBURG - OH	Distribution		69.00	13.20		10.50	1			0	0.00
960	WHIRLPOOL (OP) - OH	Distribution		34.50	13.09		20.00	1			0	0.00
961	WHITE ROAD - OH	Distribution		138.00	13.80		50	1			0	0.00
962	WILDCAT - OH	Distribution		138.00	12.00		9	1			0	0.00
963	WILKESVILLE - OH	Distribution		138.00	13.09		11	1			0	0.00
964	WILLARD - OH	Distribution		69.00	13.09		9	1			0	0.00
965	WILSON ROAD - OH	Transmission		138.00	39.40	13.80	83	2			0	0.00
966	WILSON ROAD - OH	Transmission		13.20	0.00	0.00	0			STATCAP	2	7.18
967	WILSON ROAD - OH	Transmission		138.00	13.80	13.80	42	1			0	0.00
968	WILSON ROAD - OH	Transmission		138.00	0.00	0.00	0			STATCAP	1	72.00
969	WILSON ROAD - OH	Transmission		138.00	39.40	13.80	42	0	1		0	0.00
970	WILSON ROAD - OH	Transmission		46.00	0.00	0.00	0			STATCAP	1	10.80
971	WINTERSVILLE - OH	Distribution		69.00	12.00		11	1			0	0.00
972	WOLF CREEK (CSP) - OH	Transmission		138.00	13.09		20	1			0	0.00
973	WOODLAWN (OP) - OH	Distribution		138.00	13.09		20	1			0	0.00
974	WOOSTER - OH	Transmission		138.00	24.14		25	1			0	0.00
975	WOOSTER - OH	Transmission		138.00	0.00	0.00	0			STATCAP	1	28.80
976	WOOSTER - OH	Transmission		138.00	69.50	13.09	50	1			0	0.00
977	WOOSTER - OH	Transmission		138.00	0.00	0.00	0			STATCAP	1	21.60
978	WOOSTER - OH	Transmission		138.00	13.09		20	1			0	0.00
979	ZANESVILLE - OH	Transmission		138.00	13.09		25	1			0	0.00
980	ZANESVILLE - OH	Transmission		138.00	69.00	12.00	130	1			0	0.00
981	ZANESVILLE - OH	Transmission		138.00	0.00	0.00	0			STATCAP	1	57.60
982	ZOARVILLE - OH	Distribution		69.00	13.09		9	1			0	0.00
983	ZUBER - OH	Distribution		13.80	0.00	0.00	0			STATCAP	1	7.20
984	ZUBER - OH	Distribution		138.00	13.80		50	1			0	0.00
985	KAMMER 400 YARD - WV	Transmission		765.00	345.00	34.50	1000	2			0	0.00
986	TotalDistributionSubstationMember											3,641.10
987	TotalTransmissionSubstationMember											3,958.98
988	Total											7,600.08

Schedules	Pages
Comparative Balance Sheet	110-113
Statement of Income	114-117
Statement of Retained Earnings	118-119
Statement of Cash Flows	120-121
Notes to Financial Statements	122-123

GENERAL INFORMATION
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept. Jeffrey W. Hoersdig 1 Riverside Plaza, Columbus, OH 43215-2373
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized. State of Incorporation: Date of Incorporation: Incorporated Under Special Law:
3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased. (a) Name of Receiver or Trustee Holding Property of the Respondent: (b) Date Receiver took Possession of Respondent Property: (c) Authority by which the Receivership or Trusteeship was created: (d) Date when possession by receiver or trustee ceased:
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated. Electric - Ohio
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements? (1) ☐ Yes (2) ☑ No

CORPORATIONS CONTROLLED BY RESPONDENT
Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests. Definitions See the Uniform System of Accounts for a definition of control. Direct control is that which is exercised without interposition of an intermediary. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party.
Line No.	NameOfCompanyControlledByRespondent Name of Company Controlled (a)	CompanyControlledByRespondentKindOfBusinessDescription Kind of Business (b)	VotingStockOwnedByRespondentPercentage Percent Voting Stock Owned (c)	FootnoteReferences Footnote Ref. (d)
1	Ohio Phase-In-Recovery Funding, LLC(Limited Liability Company. Ohio Power Company initially capitalized the SPE at 0.50% initial principal balance of the Phase-In-Recovery Bonds)	Special Purpose Entity (SPE)

OFFICERS
Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made.
Line No.	OfficerTitle Title (a)	OfficerName Name of Officer (b)	OfficerSalary Salary for Year (c)	DateOfficerIncumbencyStarted Date Started in Period (d)	DateOfficerIncumbencyEnded Date Ended in Period (e)
1	(a) Footnote

DIRECTORS
Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), name and abbreviated titles of the directors who are officers of the respondent. Provide the principle place of business in column (b), designate members of the Executive Committee in column (c), and the Chairman of the Executive Committee in column (d).
Line No.	NameAndTitleOfDirector Name (and Title) of Director (a)	PrincipalBusinessAddress Principal Business Address (b)	MemberOfTheExecutiveCommittee Member of the Executive Committee (c)	ChairmanOfTheExecutiveCommittee Chairman of the Executive Committee (d)
1	Nicholas K. Akins, Chairman of the Board and Chief Executive Officer	Columbus, Ohio	false	false
2	Julia A. Sloat, Vice President and Chief Financial Officer	Columbus, Ohio	false	false
3	Christian T. Beam, Executive Vice President, Energy Services	Columbus, Ohio	false	false
4	Paul,Chodak, Vice President	Columbus, Ohio	false	false
5	David M. Feinberg, Vice President and Secretary	Columbus, Ohio	false	false
6	Ann P. Kelly, Vice President and Chief Financial Officer	Columbus, Ohio	false	false
7	Therace M. Risch, Vice President	Columbus, Ohio	false	false
8	Peggy I.Simmons,Executive Vice President, Utilities	Columbus, Ohio	false	false
9	Toby L.Thomas, Vice President	Columbus, Ohio	false	false
10	Marc D.Reitter, President and Chief Operating Officer	Columbus, Ohio	false	false
11	Rajagopalan.Sundararajan,Executive Vice President, External Affairs	Columbus, Ohio	false	false
12	Phillip R.Ulrich, Vice President	Columbus, Ohio	false	false
13	Charles R.Patton, Vice President	Columbus, Ohio	false	false
14	Lisa M. Barton, Vice President	Columbus, Ohio	false	false
15	Note: Respondent does not have an Executive Committee

FERC FINANCIAL REPORT
FERC FORM No. 1: Annual Report of
Major Electric Utilities, Licensees
and Others and Supplemental
Form 3-Q: Quarterly Financial Report

INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

Purpose

Who Must Submit

What and Where to Submit

When to Submit

Where to Send Comments on Public Reporting Burden.

GENERAL INSTRUCTIONS

EXCERPTS FROM THE LAW

GENERAL PENALTIES




FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report

These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature

LIST OF SCHEDULES (Electric Utility)
Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".
Line No.	Title of Schedule (a)	Reference Page No. (b)	Remarks (c)
	ScheduleIdentificationAbstract Identification	1
	ScheduleListOfSchedulesAbstract List of Schedules	2
1	ScheduleGeneralInformationAbstract General Information	101
2	ScheduleControlOverRespondentAbstract Control Over Respondent	102
3	ScheduleCorporationsControlledByRespondentAbstract Corporations Controlled by Respondent	103
4	ScheduleOfficersAbstract Officers	104
5	ScheduleDirectorsAbstract Directors	105
6	ScheduleInformationOnFormulaRatesAbstract Information on Formula Rates	106
7	ScheduleImportantChangesDuringTheQuarterYearAbstract Important Changes During the Year	108
8	ScheduleComparativeBalanceSheetAbstract Comparative Balance Sheet	110
9	ScheduleStatementOfIncomeAbstract Statement of Income for the Year	114
10	ScheduleRetainedEarningsAbstract Statement of Retained Earnings for the Year	118
12	ScheduleStatementOfCashFlowsAbstract Statement of Cash Flows	120
12	ScheduleNotesToFinancialStatementsAbstract Notes to Financial Statements	122
13	ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract Statement of Accum Other Comp Income, Comp Income, and Hedging Activities	122a
14	ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep	200
15	ScheduleNuclearFuelMaterialsAbstract Nuclear Fuel Materials	202
16	ScheduleElectricPlantInServiceAbstract Electric Plant in Service	204
17	ScheduleElectricPropertyLeasedToOthersAbstract Electric Plant Leased to Others	213
18	ScheduleElectricPlantHeldForFutureUseAbstract Electric Plant Held for Future Use	214
19	ScheduleConstructionWorkInProgressElectricAbstract Construction Work in Progress-Electric	216
20	ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract Accumulated Provision for Depreciation of Electric Utility Plant	219
21	ScheduleInvestmentsInSubsidiaryCompaniesAbstract Investment of Subsidiary Companies	224
22	ScheduleMaterialsAndSuppliesAbstract Materials and Supplies	227
23	ScheduleAllowanceInventoryAbstract Allowances	228
24	ScheduleExtraordinaryPropertyLossesAbstract Extraordinary Property Losses	230a
25	ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract Unrecovered Plant and Regulatory Study Costs	230b
26	ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract Transmission Service and Generation Interconnection Study Costs	231
27	ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets	232
28	ScheduleMiscellaneousDeferredDebitsAbstract Miscellaneous Deferred Debits	233
29	ScheduleAccumulatedDeferredIncomeTaxesAbstract Accumulated Deferred Income Taxes	234
30	ScheduleCapitalStockAbstract Capital Stock	250
31	ScheduleOtherPaidInCapitalAbstract Other Paid-in Capital	253
32	ScheduleCapitalStockExpenseAbstract Capital Stock Expense	254b
33	ScheduleLongTermDebtAbstract Long-Term Debt	256
34	ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax	261
35	ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract Taxes Accrued, Prepaid and Charged During the Year	262
36	ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract Accumulated Deferred Investment Tax Credits	266
37	ScheduleOtherDeferredCreditsAbstract Other Deferred Credits	269
38	ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract Accumulated Deferred Income Taxes-Accelerated Amortization Property	272
39	ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract Accumulated Deferred Income Taxes-Other Property	274
40	ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract Accumulated Deferred Income Taxes-Other	276
41	ScheduleOtherRegulatoryLiabilitiesAbstract Other Regulatory Liabilities	278
42	ScheduleElectricOperatingRevenuesAbstract Electric Operating Revenues	300
43	ScheduleRegionalTransmissionServiceRevenuesAbstract Regional Transmission Service Revenues (Account 457.1)	302	NA
44	ScheduleSalesOfElectricityByRateSchedulesAbstract Sales of Electricity by Rate Schedules	304
45	ScheduleSalesForResaleAbstract Sales for Resale	310
46	ScheduleElectricOperationsAndMaintenanceExpensesAbstract Electric Operation and Maintenance Expenses	320
47	SchedulePurchasedPowerAbstract Purchased Power	326
48	ScheduleTransmissionOfElectricityForOthersAbstract Transmission of Electricity for Others	328
49	ScheduleTransmissionOfElectricityByIsoOrRtoAbstract Transmission of Electricity by ISO/RTOs	331	NA
50	ScheduleTransmissionOfElectricityByOthersAbstract Transmission of Electricity by Others	332
51	ScheduleMiscellaneousGeneralExpensesAbstract Miscellaneous General Expenses-Electric	335
52	ScheduleDepreciationDepletionAndAmortizationAbstract Depreciation and Amortization of Electric Plant (Account 403, 404, 405)	336
53	ScheduleRegulatoryCommissionExpensesAbstract Regulatory Commission Expenses	350
54	ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract Research, Development and Demonstration Activities	352
55	ScheduleDistributionOfSalariesAndWagesAbstract Distribution of Salaries and Wages	354
56	ScheduleCommonUtilityPlantAndExpensesAbstract Common Utility Plant and Expenses	356
57	ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract Amounts included in ISO/RTO Settlement Statements	397
58	SchedulePurchasesSalesOfAncillaryServicesAbstract Purchase and Sale of Ancillary Services	398
59	ScheduleMonthlyTransmissionSystemPeakLoadAbstract Monthly Transmission System Peak Load	400
60	ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract Monthly ISO/RTO Transmission System Peak Load	400a	NA
61	ScheduleElectricEnergyAccountAbstract Electric Energy Account	401a
62	ScheduleMonthlyPeakAndOutputAbstract Monthly Peaks and Output	401b
63	ScheduleSteamElectricGeneratingPlantStatisticsAbstract Steam Electric Generating Plant Statistics	402
64	ScheduleHydroelectricGeneratingPlantStatisticsAbstract Hydroelectric Generating Plant Statistics	406
65	SchedulePumpedStorageGeneratingPlantStatisticsAbstract Pumped Storage Generating Plant Statistics	408
66	ScheduleGeneratingPlantStatisticsAbstract Generating Plant Statistics Pages	410
0	ScheduleEnergyStorageOperationsLargePlantsAbstract Energy Storage Operations (Large Plants)	414
67	ScheduleTransmissionLineStatisticsAbstract Transmission Line Statistics Pages	422
68	ScheduleTransmissionLinesAddedAbstract Transmission Lines Added During Year	424
69	ScheduleSubstationsAbstract Substations	426
70	ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract Transactions with Associated (Affiliated) Companies	429
71	FootnoteDataAbstract Footnote Data	450
	StockholdersReportsAbstract Stockholders' Reports (check appropriate box)
	Stockholders' Reports Check appropriate box: ☐ Two copies will be submitted ☐ No annual report to stockholders is prepared

CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.

American Electric Power Company, Inc. Ownership of 100% of the Common Stock

INFORMATION ON FORMULA RATES
Does the respondent have formula rates?		☑ Yes ☐ No
Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate.
Line No.	RateScheduleTariffNumber FERC Rate Schedule or Tariff Number (a)	ProceedingDocketNumber FERC Proceeding (b)
1	PJM Interconnection LLC - Attachment H-14	ER17-405

INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)?			☑ Yes ☐ No
If yes, provide a listing of such filings as contained on the Commission's eLibrary website.
Line No.	AccessionNumber Accession No. (a)	DocumentDate Document Date / Filed Date (b)	DocketNumber Docket No. (c)	DescriptionOfFiling Description (d)	RateScheduleTariffNumber Formula Rate FERC Rate Schedule Number or Tariff Number (e)
1	20221208-5094	12/08/2022	ER17-405	AEP PJM OATT Proj Transmission	PJM OATT Attachment H-14
2	20221101-5174	11/01/2022	ER17-405	AEP PJM OATT Proj Transmission	PJM OATT Attachment H-14
3	20220527-5370	05/27/2022	ER17-405	AEP PJM OATT Proj Transmission	PJM OATT Attachment H-14

INFORMATION ON FORMULA RATES - Formula Rate Variances
If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from amounts reported in the Form 1. The footnote should provide a narrative description explaining how the "rate" (or billing) was derived if different from the reported amount in the Form 1. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote.
Line No.	PageNumberOfFormulaRateVariances Page No(s). (a)	ScheduleOfFormulaRateVariances Schedule (b)	ColumnOfFormulaRateVariances Column (c)	LineNumberOfFormulaRateVariances Line No. (d)
1	204-207	Electric Plant in Service	g	49
2	214	Electric Plant Held for Future Use	d	46
3	216	Construction Work In Progress	b	1
4	219	Accumulated Depreciation	b	21
5	310-311	Sales for Resale	k	1
6	320	Electric Operations & Maintenance Expense	b	5
7	320	Electric Operations & Maintenance Expense	b	25
8	320	Electric Operations & Maintenance Expense	b	31
9	321	Electric Operations & Maintenance Expense	b	93
10	323	Electric Operations & Maintenance Expense	b	185
11	336	Depreciation Expense	b	7
12	354	Distribution of Wages and Salaries	b	28

COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlant Utility Plant (101-106, 114)	200	10,747,727,035	10,109,679,319
3	ConstructionWorkInProgress Construction Work in Progress (107)	200	483,318,237	367,273,503
4	UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3)		11,231,045,272	10,476,952,821
5	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)	200	3,019,297,768	2,913,414,961
6	UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5)		8,211,747,504	7,563,537,860
7	NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)	202
8	NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly Nuclear Fuel Materials and Assemblies-Stock Account (120.2)
9	NuclearFuelAssembliesInReactorMajorOnly Nuclear Fuel Assemblies in Reactor (120.3)
10	SpentNuclearFuelMajorOnly Spent Nuclear Fuel (120.4)
11	NuclearFuelUnderCapitalLeases Nuclear Fuel Under Capital Leases (120.6)
12	AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)	202
13	NuclearFuelNet Net Nuclear Fuel (Enter Total of lines 7-11 less 12)
14	UtilityPlantAndNuclearFuelNet Net Utility Plant (Enter Total of lines 6 and 13)		8,211,747,504	7,563,537,860
15	OtherElectricPlantAdjustments Utility Plant Adjustments (116)
16	GasStoredUndergroundNoncurrent Gas Stored Underground - Noncurrent (117)
17	OtherPropertyAndInvestmentsAbstract OTHER PROPERTY AND INVESTMENTS
18	NonutilityProperty Nonutility Property (121)		19,244,970	19,244,970
19	AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122)		5,294,265	4,131,262
20	InvestmentInAssociatedCompanies Investments in Associated Companies (123)		430,000	430,000
21	InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1)	224	2,547,323	2,029,553
23	NoncurrentPortionOfAllowances Noncurrent Portion of Allowances	228
24	OtherInvestments Other Investments (124)		8,065,169	9,132,024
25	SinkingFunds Sinking Funds (125)
26	DepreciationFund Depreciation Fund (126)
27	AmortizationFundFederal Amortization Fund - Federal (127)
28	OtherSpecialFunds Other Special Funds (128)
29	SpecialFunds Special Funds (Non Major Only) (129)		120,407,548	169,853,221
30	DerivativeInstrumentAssetsLongTerm Long-Term Portion of Derivative Assets (175)
31	DerivativeInstrumentAssetsHedgesLongTerm Long-Term Portion of Derivative Assets - Hedges (176)
32	OtherPropertyAndInvestments TOTAL Other Property and Investments (Lines 18-21 and 23-31)		145,400,745	196,558,506
33	CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS
34	CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130)
35	Cash Cash (131)		9,604,930	2,990,480
36	SpecialDeposits Special Deposits (132-134)		1,743,801	15,327,429
37	WorkingFunds Working Fund (135)
38	TemporaryCashInvestments Temporary Cash Investments (136)
39	NotesReceivable Notes Receivable (141)
40	CustomerAccountsReceivable Customer Accounts Receivable (142)		126,063,481	83,005,369
41	OtherAccountsReceivable Other Accounts Receivable (143)		87,764	5,939,084
42	AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144)		3,614	525,177
43	NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145)			41,991,513
44	AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146)		91,281,940	64,075,272
45	FuelStock Fuel Stock (151)	227
46	FuelStockExpensesUndistributed Fuel Stock Expenses Undistributed (152)	227
47	Residuals Residuals (Elec) and Extracted Products (153)	227
48	PlantMaterialsAndOperatingSupplies Plant Materials and Operating Supplies (154)	227	109,536,658	74,134,855
49	Merchandise Merchandise (155)	227
50	OtherMaterialsAndSupplies Other Materials and Supplies (156)	227
51	NuclearMaterialsHeldForSale Nuclear Materials Held for Sale (157)	202/227
52	AllowanceInventoryAndWithheld Allowances (158.1 and 158.2)	228
53	NoncurrentPortionOfAllowances (Less) Noncurrent Portion of Allowances	228
54	StoresExpenseUndistributed Stores Expense Undistributed (163)	227
55	GasStoredCurrent Gas Stored Underground - Current (164.1)
56	LiquefiedNaturalGasStoredAndHeldForProcessing Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57	Prepayments Prepayments (165)		8,008,663	6,594,846
58	AdvancesForGas Advances for Gas (166-167)
59	InterestAndDividendsReceivable Interest and Dividends Receivable (171)
60	RentsReceivable Rents Receivable (172)		3,587,760	3,273,990
61	AccruedUtilityRevenues Accrued Utility Revenues (173)		17,812,366	1,296,518
62	MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174)		67,402,238	79,379,846
63	DerivativeInstrumentAssets Derivative Instrument Assets (175)		19,484	828
64	DerivativeInstrumentAssetsLongTerm (Less) Long-Term Portion of Derivative Instrument Assets (175)
65	DerivativeInstrumentAssetsHedges Derivative Instrument Assets - Hedges (176)
66	DerivativeInstrumentAssetsHedgesLongTerm (Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67	CurrentAndAccruedAssets Total Current and Accrued Assets (Lines 34 through 66)		435,145,471	377,484,852
68	DeferredDebitsAbstract DEFERRED DEBITS
69	UnamortizedDebtExpense Unamortized Debt Expenses (181)		21,323,477	22,718,242
70	ExtraordinaryPropertyLosses Extraordinary Property Losses (182.1)	230a
71	UnrecoveredPlantAndRegulatoryStudyCosts Unrecovered Plant and Regulatory Study Costs (182.2)	230b
72	OtherRegulatoryAssets Other Regulatory Assets (182.3)	232	390,041,416	352,104,457
73	PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183)		519,548	71
74	PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges Preliminary Natural Gas Survey and Investigation Charges 183.1)
75	OtherPreliminarySurveyAndInvestigationCharges Other Preliminary Survey and Investigation Charges (183.2)
76	ClearingAccounts Clearing Accounts (184)
77	TemporaryFacilities Temporary Facilities (185)
78	MiscellaneousDeferredDebits Miscellaneous Deferred Debits (186)	233	405,297,415	363,165,008
79	DeferredLossesFromDispositionOfUtilityPlant Def. Losses from Disposition of Utility Plt. (187)
80	ResearchDevelopmentAndDemonstrationExpenditures Research, Devel. and Demonstration Expend. (188)	352
81	UnamortizedLossOnReacquiredDebt Unamortized Loss on Reaquired Debt (189)		1,794,588	2,866,937
82	AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190)	234	218,820,938	204,357,451
83	UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191)
84	DeferredDebits Total Deferred Debits (lines 69 through 83)		1,037,797,383	945,212,167
85	AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84)		9,830,091,103	9,082,793,385

COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	ProprietaryCapitalAbstract PROPRIETARY CAPITAL
2	CommonStockIssued Common Stock Issued (201)	250	321,201,454	321,201,454
3	PreferredStockIssued Preferred Stock Issued (204)	250
4	CapitalStockSubscribed Capital Stock Subscribed (202, 205)
5	StockLiabilityForConversion Stock Liability for Conversion (203, 206)
6	PremiumOnCapitalStock Premium on Capital Stock (207)
7	OtherPaidInCapital Other Paid-In Capital (208-211)	253	837,802,212	838,781,212
8	InstallmentsReceivedOnCapitalStock Installments Received on Capital Stock (212)	252
9	DiscountOnCapitalStock (Less) Discount on Capital Stock (213)	254
10	CapitalStockExpense (Less) Capital Stock Expense (214)	254b
11	RetainedEarnings Retained Earnings (215, 215.1, 216)	118	1,923,617,137	1,681,376,499
12	UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1)	118	5,472,230	4,915,703
13	ReacquiredCapitalStock (Less) Reaquired Capital Stock (217)	250
14	NoncorporateProprietorship Noncorporate Proprietorship (Non-major only) (218)
15	AccumulatedOtherComprehensiveIncome Accumulated Other Comprehensive Income (219)	122(a)(b)	8,878	19,530
16	ProprietaryCapital Total Proprietary Capital (lines 2 through 15)		3,088,101,911	2,846,294,399
17	LongTermDebtAbstract LONG-TERM DEBT
18	Bonds Bonds (221)	256
19	ReacquiredBonds (Less) Reaquired Bonds (222)	256
20	AdvancesFromAssociatedCompanies Advances from Associated Companies (223)	256
21	OtherLongTermDebt Other Long-Term Debt (224)	256	3,000,641,808	3,000,748,198
22	UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225)
23	UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226)		9,000,032	9,508,727
24	LongTermDebt Total Long-Term Debt (lines 18 through 23)		2,991,641,777	2,991,239,471
25	OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES
26	ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227)		74,508,053	83,449,573
27	AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1)
28	AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2)		156,115	276,600
29	AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3)		5,010,906	5,962,545
30	AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4)		1,694,011	1,899,511
31	AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229)		3,521,938	3,521,938
32	LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities		37,893,313	85,828,895
33	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges
34	AssetRetirementObligations Asset Retirement Obligations (230)		4,999,309	1,890,073
35	OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34)		127,783,645	182,829,135
36	CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES
37	NotesPayable Notes Payable (231)
38	AccountsPayable Accounts Payable (232)		337,319,855	213,484,925
39	NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233)		172,861,738
40	AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234)		126,063,622	125,475,611
41	CustomerDeposits Customer Deposits (235)		96,496,602	66,427,967
42	TaxesAccrued Taxes Accrued (236)	262	730,879,492	697,975,157
43	InterestAccrued Interest Accrued (237)		36,080,389	35,763,904
44	DividendsDeclared Dividends Declared (238)
45	MaturedLongTermDebt Matured Long-Term Debt (239)
46	MaturedInterest Matured Interest (240)
47	TaxCollectionsPayable Tax Collections Payable (241)		4,834	12
48	MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242)		55,121,915	40,205,131
49	ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243)		18,114,183	17,556,997
50	DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244)		39,715,341	92,565,601
51	LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities		37,893,313	85,828,895
52	DerivativeInstrumentLiabilitiesHedges Derivative Instrument Liabilities - Hedges (245)
53	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges (Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54	CurrentAndAccruedLiabilities Total Current and Accrued Liabilities (lines 37 through 53)		1,574,764,658	1,203,626,410
55	DeferredCreditsAbstract DEFERRED CREDITS
56	CustomerAdvancesForConstruction Customer Advances for Construction (252)
57	AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255)	266	11	512
58	DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256)
59	OtherDeferredCredits Other Deferred Credits (253)	269	89,640,544	38,222,082
60	OtherRegulatoryLiabilities Other Regulatory Liabilities (254)	278	638,211,077	615,289,045
61	UnamortizedGainOnReacquiredDebt Unamortized Gain on Reaquired Debt (257)
62	AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty Accum. Deferred Income Taxes-Accel. Amort.(281)	272
63	AccumulatedDeferredIncomeTaxesOtherProperty Accum. Deferred Income Taxes-Other Property (282)		1,166,502,721	1,060,034,309
64	AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283)		153,444,759	145,258,021
65	DeferredCredits Total Deferred Credits (lines 56 through 64)		2,047,799,112	1,858,803,970
66	LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)		9,830,091,103	9,082,793,385

STATEMENT OF INCOME
Quarterly Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter. If additional columns are needed, place them in a footnote. Annual or Quarterly if applicable Do not report fourth quarter data in columns (e) and (f) Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above. Use page 122 for important notes regarding the statement of income for any account thereof. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.	Title of Account (a)	(Ref.) Page No. (b)	Total Current Year to Date Balance for Quarter/Year (c)	Total Prior Year to Date Balance for Quarter/Year (d)	Current 3 Months Ended - Quarterly Only - No 4th Quarter (e)	Prior 3 Months Ended - Quarterly Only - No 4th Quarter (f)	Electric Utility Current Year to Date (in dollars) (g)	Electric Utility Previous Year to Date (in dollars) (h)	Gas Utiity Current Year to Date (in dollars) (i)	Gas Utility Previous Year to Date (in dollars) (j)	Other Utility Current Year to Date (in dollars) (k)	Other Utility Previous Year to Date (in dollars) (l)
1	UtilityOperatingIncomeAbstract UTILITY OPERATING INCOME
2	OperatingRevenues Operating Revenues (400)	300	3,678,147,026	2,902,386,985			3,678,147,026	2,902,386,985
3	OperatingExpensesAbstract Operating Expenses
4	OperationExpense Operation Expenses (401)	320	2,220,400,859	1,551,797,442			2,220,400,859	1,551,797,442
5	MaintenanceExpense Maintenance Expenses (402)	320	185,633,127	158,167,742			185,633,127	158,167,742
6	DepreciationExpense Depreciation Expense (403)	336	248,275,827	258,106,708			248,275,827	258,106,708
7	DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1)	336
8	AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405)	336	45,912,810	43,861,977			45,912,810	43,861,977
9	AmortizationOfElectricPlantAcquisitionAdjustments Amort. of Utility Plant Acq. Adj. (406)	336
10	AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)
11	AmortizationOfConversionExpenses Amort. of Conversion Expenses (407.2)
12	RegulatoryDebits Regulatory Debits (407.3)		1,146,836	1,574,193			1,146,836	1,574,193
13	RegulatoryCredits (Less) Regulatory Credits (407.4)			574,879				574,879
14	TaxesOtherThanIncomeTaxesUtilityOperatingIncome Taxes Other Than Income Taxes (408.1)	262	502,287,818	480,442,903			502,287,818	480,442,903
15	IncomeTaxesOperatingIncome Income Taxes - Federal (409.1)	262	24,174,182	10,993,493			24,174,182	10,993,493
16	IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1)	262	341,469	2,983,877			341,469	2,983,877
17	ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1)	234, 272	268,980,594	212,385,252			268,980,594	212,385,252
18	ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1)	234, 272	191,246,139	181,056,268			191,246,139	181,056,268
19	InvestmentTaxCreditAdjustments Investment Tax Credit Adj. - Net (411.4)	266	44				44
20	GainsFromDispositionOfPlant (Less) Gains from Disp. of Utility Plant (411.6)		90,042				90,042
21	LossesFromDispositionOfServiceCompanyPlant Losses from Disp. of Utility Plant (411.7)		3,831				3,831
22	GainsFromDispositionOfAllowances (Less) Gains from Disposition of Allowances (411.8)			71				71
23	LossesFromDispositionOfAllowances Losses from Disposition of Allowances (411.9)
24	AccretionExpense Accretion Expense (411.10)
25	UtilityOperatingExpenses TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)		3,256,789,914	2,533,864,373			3,256,789,914	2,533,864,373
27	NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25)		421,357,112	368,522,612			421,357,112	368,522,612
28	OtherIncomeAndDeductionsAbstract Other Income and Deductions
29	OtherIncomeAbstract Other Income
30	NonutilityOperatingIncomeAbstract Nonutilty Operating Income
31	RevenuesFromMerchandisingJobbingAndContractWork Revenues From Merchandising, Jobbing and Contract Work (415)
32	CostsAndExpensesOfMerchandisingJobbingAndContractWork (Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)
33	RevenuesFromNonutilityOperations Revenues From Nonutility Operations (417)		1,484,421	1,722,741
34	ExpensesOfNonutilityOperations (Less) Expenses of Nonutility Operations (417.1)		1,485,835	1,495,645
35	NonoperatingRentalIncome Nonoperating Rental Income (418)		404,298	521,723
36	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1)	119	556,527
37	InterestAndDividendIncome Interest and Dividend Income (419)		867,473	645,317
38	AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1)		13,922,821	10,765,939
39	MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421)		2,674,574	3,809,957
40	GainOnDispositionOfProperty Gain on Disposition of Property (421.1)		425,245	254,918
41	OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40)		18,849,524	16,224,950
42	OtherIncomeDeductionsAbstract Other Income Deductions
43	LossOnDispositionOfProperty Loss on Disposition of Property (421.2)		173,507	38,887
44	MiscellaneousAmortization Miscellaneous Amortization (425)
45	Donations Donations (426.1)		9,150,712	1,850,095
46	LifeInsurance Life Insurance (426.2)
47	Penalties Penalties (426.3)		2,778	810,653
48	ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4)		2,119,844	1,932,950
49	OtherDeductions Other Deductions (426.5)		30,869,419	9,093,938
50	OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49)		42,316,261	12,105,217
51	TaxesApplicableToOtherIncomeAndDeductionsAbstract Taxes Applic. to Other Income and Deductions
52	TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions Taxes Other Than Income Taxes (408.2)	262	109,160	107,071
53	IncomeTaxesFederal Income Taxes-Federal (409.2)	262	2,832,468	4,184,240
54	IncomeTaxesOther Income Taxes-Other (409.2)	262	102,312	134,755
55	ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2)	234, 272	2,729,102	2,827,459
56	ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions (Less) Provision for Deferred Income Taxes-Cr. (411.2)	234, 272	8,984,875	3,471,713
57	InvestmentTaxCreditAdjustmentsNonutilityOperations Investment Tax Credit Adj.-Net (411.5)		545
58	InvestmentTaxCredits (Less) Investment Tax Credits (420)
59	TaxesOnOtherIncomeAndDeductions TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)		8,877,314	4,856,178
60	NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59)		14,589,422	8,975,911
61	InterestChargesAbstract Interest Charges
62	InterestOnLongTermDebt Interest on Long-Term Debt (427)		116,037,500	123,891,875
63	AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428)		1,903,460	2,045,678
64	AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1)		1,072,349	1,147,410
65	AmortizationOfPremiumOnDebtCredit (Less) Amort. of Premium on Debt-Credit (429)
66	AmortizationOfGainOnReacquiredDebtCredit (Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67	InterestOnDebtToAssociatedCompanies Interest on Debt to Assoc. Companies (430)		2,274,951	85,844
68	OtherInterestExpense Other Interest Expense (431)		4,395,675	1,380,920
69	AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)		6,713,410	4,700,081
70	NetInterestCharges Net Interest Charges (Total of lines 62 thru 69)		118,970,524	123,851,646
71	IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70)		287,797,165	253,646,877
72	ExtraordinaryItemsAbstract Extraordinary Items
73	ExtraordinaryIncome Extraordinary Income (434)
74	ExtraordinaryDeductions (Less) Extraordinary Deductions (435)
75	NetExtraordinaryItems Net Extraordinary Items (Total of line 73 less line 74)
76	IncomeTaxesExtraordinaryItems Income Taxes-Federal and Other (409.3)	262
77	ExtraordinaryItemsAfterTaxes Extraordinary Items After Taxes (line 75 less line 76)
78	NetIncomeLoss Net Income (Total of line 71 and 77)		287,797,165	253,646,877

STATEMENT OF RETAINED EARNINGS
Do not report Lines 49-53 on the quarterly report. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b). State the purpose and amount for each reservation or appropriation of retained earnings. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order. Show dividends for each class and series of capital stock. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No.	Item (a)	Contra Primary Account Affected (b)	Current Quarter/Year Year to Date Balance (c)	Previous Quarter/Year Year to Date Balance (d)
	UnappropriatedRetainedEarningsAbstract UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1	UnappropriatedRetainedEarnings Balance-Beginning of Period		1,681,376,499	1,527,729,622
2	ChangesAbstract Changes
3	AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439)
4	AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit
9	AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439)
10	AdjustmentsToRetainedEarningsDebitAbstract Adjustments to Retained Earnings Debit
15	AdjustmentsToRetainedEarningsDebit TOTAL Debits to Retained Earnings (Acct. 439)
16	BalanceTransferredFromIncome Balance Transferred from Income (Account 433 less Account 418.1)		287,240,638	253,646,877
17	AppropriationsOfRetainedEarningsAbstract Appropriations of Retained Earnings (Acct. 436)
22	AppropriationsOfRetainedEarnings TOTAL Appropriations of Retained Earnings (Acct. 436)
23	DividendsDeclaredPreferredStockAbstract Dividends Declared-Preferred Stock (Account 437)
29	DividendsDeclaredPreferredStock TOTAL Dividends Declared-Preferred Stock (Acct. 437)
30	DividendsDeclaredCommonStockAbstract Dividends Declared-Common Stock (Account 438)
30.1	DividendsDeclaredCommonStock Common Stock		45,000,000	100,000,000
36	DividendsDeclaredCommonStock TOTAL Dividends Declared-Common Stock (Acct. 438)		45,000,000	100,000,000
37	TransfersFromUnappropriatedUndistributedSubsidiaryEarnings Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings
38	UnappropriatedRetainedEarnings Balance - End of Period (Total 1,9,15,16,22,29,36,37)		1,923,617,137	1,681,376,499
39	AppropriatedRetainedEarningsAbstract APPROPRIATED RETAINED EARNINGS (Account 215)
45	AppropriatedRetainedEarnings TOTAL Appropriated Retained Earnings (Account 215)
	AppropriatedRetainedEarningsAmortizationReserveFederalAbstract APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46	AppropriatedRetainedEarningsAmortizationReserveFederal TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)
47	AppropriatedRetainedEarningsIncludingReserveAmortization TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)
48	RetainedEarnings TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)		1,923,617,137	1,681,376,499
	UnappropriatedUndistributedSubsidiaryEarningsAbstract UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49	UnappropriatedUndistributedSubsidiaryEarnings Balance-Beginning of Year (Debit or Credit)		4,915,703	4,915,703
50	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings for Year (Credit) (Account 418.1)		556,527
51	DividendsReceived (Less) Dividends Received (Debit)
52	ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
53	UnappropriatedUndistributedSubsidiaryEarnings Balance-End of Year (Total lines 49 thru 52)		5,472,230	4,915,703

STATEMENT OF CASH FLOWS
Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.	Description (See Instructions No.1 for explanation of codes) (a)	Current Year to Date Quarter/Year (b)	Previous Year to Date Quarter/Year (c)
1	NetCashFlowFromOperatingActivitiesAbstract Net Cash Flow from Operating Activities
2	NetIncomeLoss Net Income (Line 78(c) on page 117)	287,797,165	253,646,877
3	NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income:
4	DepreciationAndDepletion Depreciation and Depletion	294,188,637	301,968,685
5	NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details)
5.1	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Amortization of Regulatory Debits and Credits (Net)	1,146,836	2,149,073
5.2	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Carrying Cost Income	272,431	1,247,083
8	DeferredIncomeTaxesNet Deferred Income Taxes (Net)	71,478,682	30,684,729
9	InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net)	501
10	NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables	65,248,794	25,728,194
11	NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory	35,401,804	7,250,265
12	NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory
13	NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses	145,903,522	91,384,382
14	NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets	29,376,236	37,168,666
15	NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities	36,547,687	7,111,275
16	AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction	13,922,821	10,765,939
17	UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies	556,527
18	OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote):
18.1	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other (provide details in footnote):	(a) 68,501,523	86,044,284
18.2	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Deferred Property Taxes (186)	19,970,195	35,319,613
18.3	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Over/Under Recovered Fuel, Net	26,735,273	15,882,589
22	NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)	689,299,442	573,640,898
24	CashFlowsFromInvestmentActivitiesAbstract Cash Flows from Investment Activities:
25	ConstructionAndAcquisitionOfPlantIncludingLandAbstract Construction and Acquisition of Plant (including land):
26	GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities Gross Additions to Utility Plant (less nuclear fuel)	894,340,919	746,563,213
27	GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel
28	GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant
29	GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant
30	AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction	13,922,821	10,765,939
31	OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote):
31.1	OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Other (provide details in footnote):
31.2	OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Acquired Assets	1,151,666	829,600
34	CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33)	881,569,764	736,626,874
36	AcquisitionOfOtherNoncurrentAssets Acquisition of Other Noncurrent Assets (d)
37	ProceedsFromDisposalOfNoncurrentAssets Proceeds from Disposal of Noncurrent Assets (d)	(b) 8,626,554	9,551,543
39	InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Investments in and Advances to Assoc. and Subsidiary Companies
40	ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies Contributions and Advances from Assoc. and Subsidiary Companies
41	DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract Disposition of Investments in (and Advances to)
42	DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
44	PurchaseOfInvestmentSecurities Purchase of Investment Securities (a)
45	ProceedsFromSalesOfInvestmentSecurities Proceeds from Sales of Investment Securities (a)
46	LoansMadeOrPurchased Loans Made or Purchased
47	CollectionsOnLoans Collections on Loans
49	NetIncreaseDecreaseInReceivablesInvestingActivities Net (Increase) Decrease in Receivables
50	NetIncreaseDecreaseInInventoryInvestingActivities Net (Increase) Decrease in Inventory
51	NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities Net (Increase) Decrease in Allowances Held for Speculation
52	NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities Net Increase (Decrease) in Payables and Accrued Expenses
53	OtherAdjustmentsToCashFlowsFromInvestmentActivities Other (provide details in footnote):
53.1	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Proceed From Contribution in Aid of Construction Advance (CIAC)	20,390,760	12,964,204
53.2	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Other (provide details in footnote):
53.3	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription (Increase) Decrease in Other Special Deposits	6,577	57,304
53.4	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Notes Receivable from Associated Companies	41,991,513	41,991,513
57	CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)	810,567,514	756,159,944
59	CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities:
60	ProceedsFromIssuanceAbstract Proceeds from Issuance of:
61	ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b)		1,050,000,000
62	ProceedsFromIssuanceOfPreferredStockFinancingActivities Preferred Stock
63	ProceedsFromIssuanceOfCommonStockFinancingActivities Common Stock
64	OtherAdjustmentsToCashFlowsFromFinancingActivities Other (provide details in footnote):
64.1	OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription Other (provide details in footnote):
64.2	OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription Long Term Issuance Costs		12,929,478
66	NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c)
67	OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote):
67.1	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Proceeds on Capital Leaseback	1,106,173	379,200
67.2	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Notes Payable to Associated Companies	172,861,738
67.3	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Capital Contributions from Parent	979,000
70	CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69)	172,988,911	1,037,449,723
72	PaymentsForRetirementAbstract Payments for Retirement of:
73	PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b)	106,388	500,102,080
74	PaymentsForRetirementOfPreferredStockFinancingActivities Preferred Stock
75	PaymentsForRetirementOfCommonStockFinancingActivities Common Stock
76	OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities Other (provide details in footnote):
76.1	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Other (provide details in footnote):
76.2	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Notes Payable to Associated Companies -Retired		259,203,806
78	NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c)
80	DividendsOnPreferredStock Dividends on Preferred Stock
81	DividendsOnCommonStock Dividends on Common Stock	45,000,000	100,000,000
83	CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)	127,882,523	178,143,836
85	NetIncreaseDecreaseInCashAndCashEquivalentsAbstract Net Increase (Decrease) in Cash and Cash Equivalents
86	NetIncreaseDecreaseInCashAndCashEquivalents Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83)	6,614,451	4,375,209
88	CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period	2,990,479	7,365,688
90	CashAndCashEquivalents Cash and Cash Equivalents at End of Period	9,604,930	2,990,479

TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
Report below the information called for concerning all non-power goods or services received from or provided to associated (affiliated) companies. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount billed to the respondent or billed to an associated/affiliated company for non-power goods and services. The good or service must be specific in nature. Respondents should not attempt to include or aggregate amounts in a nonspecific category such as "general". Where amounts billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote.
Line No.	Description of the Good or Service (a)	Name of Associated/Affiliated Company (b)	Account(s) Charged or Credited (c)	Amount Charged or Credited (d)
1	Non-power Goods or Services Provided by Affiliated
2	Administrative and General Expenses - Maintenance	(a) AEPSC	935	4,708,814
3	Audit Services	AEPSC	920, 923	908,530
4	Administrative and General Expenses - Operation	AEPSC	920-926,928,930,931	11,806,627
5	Civil & Political Activities and Other Services	AEPSC	426	2,433,040
6	Construction Services	AEPSC	107, 108	133,958,740
7	Construction Services	I&M	107, 108	619,454
8	Construction Services	OHTCo	107, 108	363,847
9	Bus Ops & Perf Assurance	AEPSC	920,923	1,420,803
10	Corp Safety & Health	AEPSC	920,923	1,680,230
11	Corporate Accounting	AEPSC	920,923	2,210,065
12	Corporate Communications	AEPSC	920,923	965,624
13	Corporate Human Resources	AEPSC	920,923	4,858,051
14	Corporate Planning & Budgeting	AEPSC	920,923	1,265,741
15	Customer Accounts Expenses	AEPSC	901-905	26,826,536
16	Customer Operations and Support	AEPSC	920,923	1,211,970
17	Customer Service and Informational Expenses	AEPSC	907,908,910	468,465
18	Distribution Expenses - Maintenance	AEPSC	590-598	6,425,879
19	Distribution Expenses - Maintenance	I&M	592-596	267,568
19
20	Non-power Goods or Services Provided for Affiliated
21	A Ray King Transmission Training Facility	AEP Texas	566	252,946
22	Administrative and General Expenses - Maintenance	OHTCo	935	534,773
23	Administrative and General Expenses - Operation	AEP T&D Services, LLC	920,921,930.2-931	523,792
24	Building and Property Leases	AEPSC	454	7,241,019
25	Building Rent	AEPSC	454	9,159,525
26	Construction Services	I&M	107,108	382,101
27	Construction Services	KPCo	(b) 107,108	459,751
28	Construction Services	OHTCo	107,108	1,108,118
29	Distribution Expenses - Maintenance	I&M	593-596,598	287,318
30	Distribution Expenses - Maintenance	KPCO	592,593,595	1,026,502
31	Fleet and Vehicle Charges	AEPSC	See Footnote	6,317,907
32	Materials and Supplies	AEP Service Corporation	154	577,832
33	Materials and Supplies	AEP T&D Services, LLC	154	1,091,513
34	Materials and Supplies	AEP Texas	154	1,190,284
35	Materials and Supplies	APCo	154	6,736,236
36	Materials and Supplies	APTCo	154	849,358
37	Materials and Supplies	I&M	154	3,317,129
38	Materials and Supplies	IMTCo	154	357,818
39	Materials and Supplies	KgPCo	154	988,740
40	Materials and Supplies	KPCo	154	1,111,360
41	Materials and Supplies	OKTCo	154	299,962
42	Distribution Expenses - Operation	AEPSC	580-584,586-588	12,434,517
43	Economic & Business Development	AEPSC	920,923	899,800
44	Factored Customer A/R Bad Debts	AEP Credit	426.5	8,402,584
45	Factored Customer A/R Expense	AEP Credit	426.5	13,166,242
46	Fuel & Storeroom Services	AEPSC	152,163	8,388,980
47	Grid Solutions	AEPSC	920,923	336,279
48	Information Technology	AEPSC	920,923	8,635,124
49	Infrastructure Ops & Support	AEPSC	920,923	1,713,065
50	Leased Transmission Lines	WPCO	565	2,738,353
51	Legal GC/Administration	AEPSC	920,923	2,587,081
52	Materials and Supplies	I&M	107,154,182,184,570,583,584,595,935	507,228
53	Operations & Performance Transformation	AEPSC	920,923	477,353
54	Other Operating Revenues	APCo	456	825,634
55	Physical & Cyber Security	AEPSC	920,923	1,309,579
56	Real Estate & Workplace Svcs	AEPSC	920,923	2,049,389
57	Regulatory Services	AEPSC	920,923	898,726
58	Research and Other Services	AEPSC	183,186,188	2,972,356
59	Steam Power Generation - Operation	AEPSC	500,501,506	391,522
60	Materials and Supplies	PSO	154	328,799
61	Materials and Supplies	SWEPCo	154	355,512
62	Materials and Supplies	WVTCo	154	4,988,694
63	Use of Jointly Owned Facility	OHTCo	454	5,153,475
64	Strategy & Transformation	AEPSC	920,923	253,352
65	Tax Services	AEPSC	920,923	924,252
66	Transmission Expenses - Maintenance	AEPSC	568-573	7,055,117
67	Transmission Expenses - Operation	AEPSC	560-567,920,923	16,935,912
68	Treasury & Risk	AEPSC	920,923	2,615,694
42

FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report

INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

Purpose

Who Must Submit

What and Where to Submit

When to Submit

Where to Send Comments on Public Reporting Burden.

GENERAL INSTRUCTIONS

EXCERPTS FROM THE LAW

GENERAL PENALTIES

FERC FINANCIAL REPORT
FERC FORM No. 1: Annual Report of
Major Electric Utilities, Licensees
and Others and Supplemental
Form 3-Q: Quarterly Financial Report