FERC Form

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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.Comprehensive Income

4.Rate Matters

5.Effects of Regulation

6.Commitments, Guarantees and Contingencies

7.Benefit Plans

8.Business Segments

9.Derivatives and Hedging

10.Fair Value Measurements

11.Income Taxes

12.Leases

13.Financing Activities

14.Related Party Transactions

15.Property, Plant and Equipment

16.Revenue from Contracts with Customers

17.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.
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.
CARES Act						Coronavirus Aid, Relief, and Economic Security Act signed into law in March 2020.
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.
IRS						Internal Revenue Service.
ITC						Investment Tax Credit.
KPCo						Kentucky Power Company, an AEP electric utility subsidiary.


MTM						Mark-to-Market.
MWh						Megawatt-hour.
OATT						Open Access Transmission Tariff.
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.
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.
ROE						Return on Equity.
RPM						Reliability Pricing Model.
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 engages in the transmission and distribution of power to approximately 1,515,000 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, 2021, OPCo had 1,694 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 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 classification of deferred purchased power as noncurrent rather than current.
·			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.
·			The classification of deferred FICA taxes as taxes accrued rather than as a noncurrent liability.

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


		2021			2020
For the Years Ended December 31,		(in millions)
Cash was Paid (Received) for:
	Interest (Net of Capitalized Amounts)	$	119.5		$	111.2
	Income Taxes (Net of Refunds)			(7.9)			(26.9)
Noncash Acquisitions Under Finance Leases				2.5			6.1
As of December 31,
Construction Expenditures Included in Current and Accrued Liabilities				97.1			76.7

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 Miscellaneous Current and Accrued Assets on the balance sheets. RECs with expected consumption beyond one year are included in Other Deferred Credits 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 cost 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 removed from plant-in-service or CWIP and charged to expense. 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.

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 amortized when refunded or when billed to customers in later months with the PUCO’s review and approval. 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”, and are 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. 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 cash tax benefit is recognized.

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 of 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	25	%
Fixed Income	59	%
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, 2021 and 2020, the fair value of securities on loan as part of the program was $137 million and $177 million, respectively. Cash and securities obtained as collateral exceeded the fair value of the securities loaned as of December 31, 2021 and 2020.

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.

Comprehensive Income (Loss)

Comprehensive income (loss) is defined as the change in equity (net assets) of a business enterprise during a period from transactions and other events and circumstances from non-owner sources. It includes all changes in equity during a period except those resulting from investments by owners and distributions to owners.

Subsequent Events

Management has evaluated the impact of events occurring after December 31, 2021 through February 24, 2022, the date that AEP’s Form 10-K was issued, and has updated such evaluation for disclosure purposes through April 14, 2022. 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. COMPREHENSIVE INCOME

Presentation of Comprehensive Income

The following tables provide the components of changes in AOCI and details of reclassifications from AOCI for the years ended December 31, 2021 and 2020. The amortization of pension and OPEB AOCI components are included in the computation of net periodic pension and OPEB costs. See Note 7 - Benefit Plans for additional information.


	Cash Flow Hedge –
For the Year Ended December 31, 2021	Interest Rate
	(in millions)
Balance in AOCI as of December 31, 2020	$	—
Change in Fair Value Recognized in AOCI	—
Amount of (Gain) Loss Reclassified from AOCI
Interest on Long-Term Debt (a)	—
Reclassifications from AOCI, before Income Tax (Expense) Benefit	—
Income Tax (Expense) Benefit	—
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit	—
Net Current Period Other Comprehensive Income (Loss)	—
Balance in AOCI as of December 31, 2021	$	—


	Cash Flow Hedge –
For the Year Ended December 31, 2020	Interest Rate
	(in millions)
Balance in AOCI as of December 31, 2019	$	—
Change in Fair Value Recognized in AOCI	—
Amount of (Gain) Loss Reclassified from AOCI
Interest on Long-Term Debt (a)	—
Reclassifications from AOCI, before Income Tax (Expense) Benefit	—
Income Tax (Expense) Benefit	—
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit	—
Net Current Period Other Comprehensive Income (Loss)	—
Balance in AOCI as of December 31, 2020	$	—

(a)Amounts reclassified to the referenced line item on the statements of income.

4. 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.

2020 Ohio Base Rate Case

In June 2020, OPCo filed a request with the PUCO for a $42 million annual increase in base rates based upon a proposed 10.15% ROE net of existing riders.

In March 2021, OPCo, the PUCO staff and various intervenors filed a joint stipulation and settlement agreement with the PUCO. The agreement includes a $68 million annual decrease in base rates based on an ROE of 9.7%. The difference between OPCo’s requested annual base rate increase and the agreed upon decrease is primarily due to a reduction in the requested ROE, the removal of proposed future energy efficiency costs and a decrease in vegetation management expenses moved to recovery in riders. Additionally, the agreement includes: (a) an increased fixed monthly residential customer charge, (b) the discontinuation of rate decoupling and (c) the continuation of the DIR with annual revenue caps of $57 million in 2021, $91 million in 2022, $116 million in 2023 and $51 million for the first five months of 2024. Annual revenue caps for the DIR can be increased if OPCo achieves certain reliability standards. In November 2021, the PUCO approved the joint stipulation and settlement agreement and rates went into effect in December 2021.

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. Management disagrees with these claims and is unable to predict the impact, if any, these disputes may have on future results of operations, financial condition and cash flows. See "OVEC" section of Note 14 for additional information on AEP and OPCo’s investment in OVEC.

FERC RTO Incentive Complaint

In February 2022, the Office of the Ohio Consumer’s Council 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 Ohio Consumer’s Council 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. If the FERC orders revenue reductions as a result of the complaint, including refunds from the date of the complaint filing, it could reduce future net income and cash flows and impact financial condition.

5. EFFECTS OF REGULATION

Regulatory assets and liabilities are comprised of the following items:


	December 31,				Remaining Recovery Period
Regulatory Assets:	2021		2020
	(in millions)

Regulatory assets pending final regulatory approval:

Regulatory Assets Currently Not Earning a Return
Storm-Related Costs	$	3.8	$	4.1
COVID-19	—		4.4
Total Regulatory Assets Pending Final Regulatory Approval	3.8		8.5

Regulatory assets approved for recovery:

Regulatory Assets Currently Earning a Return
Ohio Distribution Decoupling	41.6		46.6		2 years
Ohio Economic Development Rider	10.1		1.3		2 years
Ohio Basic Transmission Cost Rider	5.2		12.3		2 years
Total Regulatory Assets Currently Earning a Return	56.9		60.2
Regulatory Assets Currently Not Earning a Return
Unrealized Loss on Forward Commitments	92.1		110.0		11 years
Pension and OPEB Funded Status	83.3		130.7		12 years
Income Tax Assets Subject to Flow Through	62.0		62.7		30 years
Smart Grid Costs	19.3		19.2		2 years
Ohio Enhanced Service Reliability Plan	9.5		—		2 years
PJM Load Service Entity Formula Rate True-up	7.5		—		2 years
Postemployment Benefits	6.2		6.6		3 years
Distribution Investment Rider	2.1		7.4		2 years
OVEC Purchased Power	—		27.4
Other Regulatory Assets Approved for Recovery	9.4		15.0		various
Total Regulatory Assets Currently Not Earning a Return	291.4		379.0

Total Regulatory Assets Approved for Recovery	348.3		439.2

Total FERC Account 182.3 Regulatory Assets	$	352.1	$	447.7


	OPCo
	December 31,				Remaining Refund Period
	2021		2020
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 Not Paying a Return
Peak Demand Reduction/Energy Efficiency	22.5		19.9		2 years
PJM Transmission Enhancement Refund	19.6		24.5		4 years
Over-recovered Fuel Costs	15.2		7.1		11 years
OVEC Purchased Power	14.8		—		2 years
Ohio Enhanced Service Reliability Plan	—		5.7
Other Regulatory Liabilities Approved for Payment	0.4		0.7		various
Total Regulatory Liabilities Currently Not Paying a Return	72.5		57.9
Income Tax Related Regulatory Liabilities (a)
Excess ADIT Associated with Certain Depreciable Property	325.0		334.6		(b)
Excess ADIT that is Not Subject to Rate Normalization Requirements	190.8		223.9		7 years
Income Taxes Subject to Flow Through	26.8		—		30 years
Total Income Tax Related Regulatory Liabilities	542.6		558.5

Total Regulatory Liabilities Approved for Payment	615.1		616.4

Total FERC 254 Account Regulatory Liabilities	$	615.3	$	616.6

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

(b)Refunded using ARAM.

6. 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, 2021:


Contractual Commitments	Less Than 1 Year		2-3 Years		4-5 Years		After 5 Years		Total
	(in millions)
Energy and Capacity Purchase Contracts	$	34.6	$	69.1	$	65.4	$	180.0	$	349.1

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, 2021, 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, 2021, OPCo was named as a Potentially Responsible Party (PRP) for three 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, 2021, 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, 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. AEP will continue to defend against the claims. Management is unable to determine a range of potential losses that is reasonably possible of occurring.

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 United States 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 fails 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 United States 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 New York state court derivative action is stayed. The Ohio state court derivative action was stayed until February 18, 2022, and the parties to that case filed a stipulation seeking to extend the stay. The two derivative actions pending in federal court have been consolidated, and the parties to the consolidated action have filed a joint motion for the court to enter a scheduling order pursuant to which plaintiffs will file an amended complaint and the parties will then propose a briefing schedule for defendants’ motion to dismiss the amended complaint. 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 agreed that AEP and the AEP Board may defer consideration of the litigation demand until the resolution of the motion to dismiss the securities litigation. The AEP Board will act in response to the letter as appropriate. Management is unable to determine a range of potential losses that is reasonably possible of occurring.

In May 2021, AEP received a subpoena from the SEC’s Division of Enforcement seeking various documents, including documents relating to the benefits to AEP from the passage of HB 6 and documents relating to AEP’s financial processes and controls. AEP is cooperating fully with the SEC’s subpoena. Although the outcome of the SEC’s investigation cannot be predicted, management does not believe the results of this inquiry will have a material impact on our financial condition, results of operations, or cash flows.

7. 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 nonqualified pension plan. Substantially all 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 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. 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 a regulatory asset and deferred gains result in a regulatory liability.

Actuarial Assumptions for Benefit Obligations

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


	Pension Plans						OPEB
	December 31,
Assumption	2021			2020			2021		2020
Discount Rate	2.90	%		2.50	%		2.90	%	2.55	%
Interest Crediting Rate	4.00	%		4.00	%		NA		NA
Rate of Compensation Increase	5.30	%	(a)	5.25	%	(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 2021, 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	2021		2020		2021		2020
Discount Rate	2.50	%	3.25	%	2.55	%	3.30	%
Interest Crediting Rate	4.00	%	4.00	%	NA		NA
Expected Return on Plan Assets	4.75	%	5.75	%	4.75	%	5.50	%
Rate of Compensation Increase	5.30	%	5.25	%	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	2021		2020
Initial	6.25	%	6.50	%
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, 2021, 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, 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. For the year ended December 31, 2020, the pension plans had an actuarial loss primarily due to a decrease in the discount rate, partially offset by a decrease in the assumed rate used to convert account balances to annuities. For the year ended December 31, 2020, the OPEB plans had an actuarial loss primarily due to a decrease in the discount rate and an update to the health care trend assumption, partially offset by updated projected per capita claims costs due to rate negotiations for Medicare advantage premium rates.

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
	2021		2020		2021		2020
Change in Benefit Obligation	(in millions)
Benefit Obligation as of January 1,	$	510.3	$	487.8	$	126.4	$	130.2
Service Cost	11.4		9.7		0.8		0.9
Interest Cost	12.5		15.4		3.0		4.2
Actuarial (Gain) Loss	(24.1)		33.4		(15.6)		3.1
Plan Amendments	—		—		(0.6)		(1.3)
Benefit Payments	(39.4)		(36.0)		(13.6)		(15.0)
Participant Contributions	—		—		4.5		4.3
Benefit Obligation as of December 31,	$	470.7	$	510.3	$	104.9	$	126.4

Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	$	543.1	$	499.1	$	213.0	$	197.1
Actual Gain on Plan Assets	21.1		79.9		16.1		26.6
Company Contributions	—		0.1		—		—
Participant Contributions	—		—		4.5		4.3
Benefit Payments	(39.4)		(36.0)		(13.6)		(15.0)
Fair Value of Plan Assets as of December 31,	$ 524.8		$ 543.1		$ 220.0		$ 213.0

Funded Status as of December 31,	$	54.1	$	32.8	$	115.1	$	86.6


	Pension Plans				OPEB
	December 31,
	2021		2020		2021		2020
	(in millions)
Special Funds – Prepaid Benefit Costs	$	54.8	$	33.3	$	115.1	$	86.6
Accumulated Provision for Pensions and Benefits – Long-term Benefit Liability	(0.7)		(0.5)		—		—
Funded Status	$	54.1	$	32.8	$	115.1	$	86.6

Amounts Included in Regulatory Assets

The following tables show the components of the plans included in regulatory assets and the items attributable to the change in these components:


	Pension Plans				OPEB
	December 31,
	2021		2020		2021		2020
Components	(in millions)
Net Actuarial (Gain) Loss	$	118.1	$	150.0	$	(18.5)	$	3.6
Prior Service Credit	—		—		(16.3)		(22.9)

Recorded as
Regulatory Assets	$	118.1	$	150.0	$	(34.8)	$	(19.3)


	Pension Plans				OPEB
	2021		2020		2021		2020
Components	(in millions)
Actuarial Gain During the Year	$	(22.8)	$	(20.2)	$	(22.1)	$	(12.9)
Amortization of Actuarial Loss	(9.1)		(8.5)		—		(0.7)
Prior Service Credit	—		—		(0.6)		(1.3)
Amortization of Prior Service Credit	—		—		7.2		7.0
Change for the Year Ended December 31,	$	(31.9)	$	(28.7)	$	(15.5)	$	(7.9)

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,
2021		2020		2021		2020
9.8	%	9.8	%	10.8	%	10.9	%

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

Total	$	854.7	$	3,235.6	$	—	$	1,262.6	$	5,352.9	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 primarily represent accrued interest, dividend receivables and transactions pending settlement.

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

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 (b)	—		—		—		265.0		265.0		13.0	%
Subtotal – Equities	770.3		—		—		265.0		1,035.3		50.7	%

Fixed Income:
Common Collective Trust – Debt (b)	—		—		—		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 (b)	33.0		—		—		6.7		39.7		1.9	%
Other – Pending Transactions and Accrued Income (a)	—		—		—		6.0		6.0		0.3	%

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

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

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

The following table presents the classification of pension plan assets for AEP within the fair value hierarchy as of December 31, 2020:


Asset Class	Level 1		Level 2		Level 3		Other		Total		Year End Allocation
	(in millions)
Equities (a):
Domestic	$	542.3	$	—	$	—	$	—	$	542.3	9.7	%
International	676.3		—		—		—		676.3		12.2	%
Common Collective Trusts (c)	—		—		—		650.0		650.0		11.7	%
Subtotal – Equities	1,218.6		—		—		650.0		1,868.6		33.6	%

Fixed Income (a):
United States Government and Agency Securities	(1.4)		1,134.1		—		—		1,132.7		20.4	%
Corporate Debt	—		1,425.0		—		—		1,425.0		25.6	%
Foreign Debt	—		214.0		—		—		214.0		3.9	%
State and Local Government	—		56.0		—		—		56.0		1.0	%
Other – Asset Backed	—		0.8		—		—		0.8		—	%
Subtotal – Fixed Income	(1.4)		2,829.9		—		—		2,828.5		50.9	%

Infrastructure (c)	—		—		—		91.1		91.1		1.6	%
Real Estate (c)	—		—		—		231.6		231.6		4.2	%
Alternative Investments (c)	—		—		—		431.8		431.8		7.8	%
Cash and Cash Equivalents (c)	—		49.3		—		58.2		107.5		1.9	%
Other – Pending Transactions and Accrued Income (b)	—		—		—		(2.5)		(2.5)		—	%

Total	$	1,217.2	$	2,879.2	$	—	$	1,460.2	$	5,556.6	100.0	%

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

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

The following table presents the classification of OPEB plan assets for AEP within the fair value hierarchy as of December 31, 2020:


Asset Class	Level 1		Level 2		Level 3		Other		Total		Year End Allocation
	(in millions)
Equities:
Domestic	$	399.9	$	—	$	—	$	—	$	399.9	20.6	%
International	290.7		—		—		—		290.7		14.9	%
Common Collective Trusts (b)	—		—		—		264.7		264.7		13.6	%
Subtotal – Equities	690.6		—		—		264.7		955.3		49.1	%

Fixed Income:
Common Collective Trust – Debt (b)	—		—		—		186.4		186.4		9.6	%
United States Government and Agency Securities	(0.2)		199.7		—		—		199.5		10.2	%
Corporate Debt	—		248.7		—		—		248.7		12.8	%
Foreign Debt	—		34.9		—		—		34.9		1.8	%
State and Local Government	73.9		13.1		—		—		87.0		4.5	%
Subtotal – Fixed Income	73.7		496.4		—		186.4		756.5		38.9	%

Trust Owned Life Insurance:
International Equities	—		64.8		—		—		64.8		3.3	%
United States Bonds	—		135.9		—		—		135.9		7.0	%
Subtotal – Trust Owned Life Insurance	—		200.7		—		—		200.7		10.3	%

Cash and Cash Equivalents (b)	26.3		—		—		5.7		32.0		1.6	%
Other – Pending Transactions and Accrued Income (a)	—		—		—		2.2		2.2		0.1	%

Total	$	790.6	$	697.1	$	—	$	459.0	$	1,946.7	100.0	%

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

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

Accumulated Benefit Obligation

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


	December 31,
Accumulated Benefit Obligation	2021	2020
	(in millions)
Qualified Pension Plan	$ 440.0	$ 479.2
Nonqualified Pension Plans	0.3	0.2
Total	$ 440.3	$ 479.4

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,
	2021		2020
	(in millions)
Projected Benefit Obligation	$	0.7	$	0.6
Fair Value of Plan Assets	—		—
Underfunded Projected Benefit Obligation	$	(0.7)	$	(0.6)

Accumulated Benefit Obligation


	December 31,
	2021		2020
	(in millions)
Accumulated Benefit Obligation	$	0.3	$	0.2
Fair Value of Plan Assets	—		—
Underfunded Accumulated Benefit Obligation	$	(0.3)	$	(0.2)

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)
2022	$	35.1	$	13.5
2023	33.7		12.5
2024	32.9		12.9
2025	33.0		12.7
2026	32.4		12.3
Years 2027 to 2031, in Total	149.1		57.1

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,
	2021		2020		2021		2020
	(in millions)
Service Cost	$	11.4	$	9.7	$	0.8	$	0.9
Interest Cost	12.5		15.4		3.0		4.2
Expected Return on Plan Assets	(22.3)		(26.3)		(9.7)		(10.5)
Amortization of Prior Service Credit	—		—		(7.2)		(7.0)
Amortization of Net Actuarial Loss	9.1		8.5		—		0.7
Net Periodic Benefit Cost (Credit)	10.7		7.3		(13.1)		(11.7)
Capitalized Portion	(6.2)		(5.0)		(0.4)		(0.5)
Net Periodic Benefit Cost (Credit) Recognized in Expense	$	4.5	$	2.3	$	(13.5)	$	(12.2)

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, 2021 and 2020 were $7 million and $7 million, respectively.

8. BUSINESS SEGMENTS

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

9. 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

Volume

December 31,

Primary Risk Exposure

2021

2020

Unit of Measure

(in millions)

Commodity:

Power

2.7

3.0

MWhs

Heating Oil and Gasoline

1.5

1.4

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, 2021 and 2020.

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


	December 31, 2021
	Risk Management		Gross Amounts Offset		Net Amounts of Assets/Liabilities
	Contracts -		in the Statement of		Presented in the Statement
Balance Sheet Location	Commodity (a)		Financial Position (b)		of 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


	December 31, 2020
	Risk Management		Gross Amounts Offset		Net Amounts of Assets/Liabilities
	Contracts -		in the Statement of		Presented in the Statement
Balance Sheet Location	Commodity (a)		Financial Position (b)		of Financial Position (c)
	(in millions)
Derivative Instrument Assets	$	0.3	$	(0.3)	$	—
Long-Term Portion of Derivative Instrument Assets	—		—		—

Derivative Instrument Liabilities	110.3		—		110.3
Long-Term Portion of Derivative Instrument Liabilities	101.6		—		101.6

(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)	2021		2020
	(in millions)
Operation Expenses	$	0.5	$	(0.3)
Maintenance Expenses	0.6		(0.5)
Other Regulatory Assets (a)	10.0		(6.6)
Other Regulatory Liabilities (a)	—		12.4
Total Gain (Loss) on Risk Management Contracts	$	11.1	$	5.0

(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, surety bonds 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.

10. 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,
2021				2020
Book Value		Fair Value		Book Value		Fair Value
(in millions)
$	2,991.2	$	3,437.5	$	2,444.3	$	3,154.9

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, 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)	$	—	$	—	$	92.5	$	—	$	92.5


	December 31, 2020
	Level 1		Level 2		Level 3		Other		Total
Assets:	(in millions)

Derivative Instrument Assets
Risk Management Commodity Contracts (a) (b)	$	—	$	0.3	$	—	$	(0.3)	$	—

Liabilities:

Derivative Instrument Liabilities
Risk Management Commodity Contracts (a)	$	—	$	—	$	110.3	$	—	$	110.3

(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, 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)

	Derivative Instrument
Year Ended December 31, 2020	Assets (Liabilities)
	(in millions)
Balance as of December 31, 2019	$	(103.6)
Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b)	(1.6)
Settlements	8.9
Changes in Fair Value Allocated to Regulated Jurisdictions (c)	(14.0)
Balance as of December 31, 2020	$	(110.3)

(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, 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

December 31, 2020

Significant

Input/Range

Fair Value

Valuation

Unobservable

Weighted

Assets

Liabilities

Technique

Input (a)

Low

High

Average (b)

(in millions)

Energy Contracts

—

110.3

Discounted Cash Flow

Forward Market Price

16.19

46.98

28.30

(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 as of December 31, 2021 and 2020:

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)

11. INCOME TAXES

Income Tax Expense (Credit)

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


	Years Ended December 31,
	2021		2020
	(in millions)
Charged (Credited) to Operating Expenses, Net:
Current	$	8.0	$	(29.9)
Deferred	31.3		75.0
Total	39.3		45.1

Charged (Credited) to Non-Operating Income, Net:
Current	(4.3)		(2.1)
Deferred	(0.6)		2.2
Total	(4.9)		0.1
Total Income Taxes	$	34.4	$	45.2

The following is a reconciliation of the difference between the amount of federal income taxes computed by multiplying book income before income taxes by the federal statutory tax rate and the amount of income taxes reported:


	Years Ended December 31,
	2021			2020
	(in millions)
Net Income	$	253.6		$	271.4
Income Tax Expense	34.4			45.2
Pretax Income	$	288.0		$	316.6

Income Taxes on Pretax Income at Statutory Rate (21%)	$	60.5		$	66.5
Increase (Decrease) in Income Taxes Resulting from the Following Items:
Reversal of Origination Flow-Through	2.2			3.7
State and Local Income Taxes, Net	—			(1.7)
AFUDC	(2.3)			(2.6)
Tax Reform Excess ADIT Reversal	(32.6)			(27.2)
Federal Return to Provision	(1.2)			6.5
Tax Adjustments (a)	8.9			—
Other	(1.1)			—
Income Tax Expense	$	34.4		$	45.2

Effective Income Tax Rate	11.9		%	14.3		%

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

Net Deferred Tax Liability

The following table shows elements of OPCo’s net deferred tax assets (liabilities) and significant temporary differences:


	December 31,
	2021		2020
	(in millions)
Deferred Tax Assets	$	204.4	$	210.8
Deferred Tax Liabilities	(1,205.3)		(1,165.9)
Net Deferred Tax Liabilities	$ (1,000.9)		$ (955.1)

Property Related Temporary Differences	$ (1,042.0)		$ (1,016.0)
Amounts Due to Customers for Future Income Taxes	117.7		121.1
Deferred State Income Taxes	(58.8)		(40.7)
Regulatory Assets	(39.8)		(53.7)
Operating Lease Liability	17.2		19.4
All Other, Net	4.8		14.8
Net Deferred Tax Liabilities	$	(1,000.9)	$	(955.1)

AEP System Tax Allocation Agreement

OPCo and other AEP subsidiaries join in the filing of a consolidated federal income tax return. The allocation of the AEP System’s current consolidated federal income tax to the AEP System companies allocates the benefit of current tax loss of the parent company (Parent Company Loss Benefit) to the AEP System subsidiaries with taxable income reducing their current tax expense proportionately. The consolidated net operating loss (NOL) of the AEP System is allocated to each company in the consolidated group with taxable losses. 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.

Net Income Tax Operating Loss Carryforward

As of December 31, 2021, OPCO has Ohio Municipal net income tax operating loss carryforward of $76 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. In the third quarter of 2019, OPCo and other AEP subsidiaries elected to amend the 2014 through 2017 federal returns. In the first quarter of 2020, the IRS notified OPCo and other AEP subsidiaries that it was beginning an examination of these amended returns, including the net operating loss carryback to 2015 that originated in the 2017 return. As of December 31, 2021, the IRS has not issued any proposed adjustments and the IRS is limited in their proposed adjustments to the amount OPCo and other AEP

subsidiaries claimed on the amended returns. OPCo has agreed to extend the statute of limitations on the 2017 tax return to December 31, 2022 to allow time for the audit to be completed and the Congressional Joint Committee on Taxation to approve the associated refund claim.

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. The Registrants are no longer subject to state or local examinations by tax authorities for years before 2012. In addition, management is monitoring and continues to evaluate the potential impact of federal legislation and corresponding state conformity.

Uncertain Tax Positions

The reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:


	2021		2020
	(in millions)
Balance at January 1,	$	3.3	$	8.5
Increase - Tax Positions Taken During a Prior Period	—		—
Decrease - Tax Positions Taken During a Prior Period	(3.3)		(5.2)
Increase - Tax Positions Taken During the Current Year	—		—
Decrease - Tax Positions Taken During the Current Year	—		—
Increase - Settlements with Taxing Authorities	—		—
Decrease - Settlements with Taxing Authorities	—		—
Decrease - Lapse of the Applicable Statute of Limitations	—		—
Balance at December 31,	$	—	$	3.3

The total amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate is immaterial and $2.6 million for 2021 and 2020, respectively. Management believes that there will be no significant net increase or decrease in unrecognized benefits within 12 months of the reporting date.

Federal and State Tax Legislation

In March 2020, the CARES Act was signed into law. The CARES Act includes tax relief provisions including a 5-year NOL carryback from years 2018-2020. In the third quarter of 2020, AEP requested a $95 million refund of taxes paid in 2014 under the 5-year NOL carryback provision of the CARES Act. AEP carried back a NOL generated on the 2019 Federal income tax return at a 21% federal corporate income tax rate to the 2014 Federal income tax return at a 35% corporate income tax rate. As a result of the change in the corporate income tax rates between the two periods, AEP realized a tax benefit of $48 million during the third quarter of 2020 primarily at the Generation & Marketing segment. AEP received the $95 million refund in the fourth quarter of 2021.

In March 2021, the American Rescue Plan Act of 2021 (the “American Rescue Plan”) was signed into law. The American Rescue Plan was a COVID-19 relief package that addressed a variety of topics, including the non-deductibility of certain executive compensation. Specifically, the American Rescue Plan changes the officers subject to IRC Section 162(m) from the CEO, CFO and three top paid officers to the CEO, CFO and eight top paid officers beginning in 2027.

IRS Notice 2021-41 was issued in June 2021 by the IRS providing further extension of the continuity safe harbor for PTC and ITC-eligible projects and revising the facts and circumstances rules. For PTC and ITC-eligible projects for which construction began in calendar years 2016 through 2019, the continuity safe harbor is extended

to six years. Prior guidance (IRS Notice 2020-41) had only extended the safe harbor for projects beginning in 2016 and 2017 to 5 years. Furthermore, for PTC and ITC-eligible projects for which construction began in 2020, the continuity safe harbor is extended to five years. Under a facts and circumstances analysis, the continuity requirement may be satisfied under either the continuous construction test or the continuous efforts test, regardless of whether the physical work test or the five percent safe harbor is used.

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.

12. 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,
	2021		2020
	(in millions)
Operating Lease Cost	$	19.0	$	17.1
Finance Lease Cost:
Amortization of Right-of-Use Assets	4.9		4.7
Interest on Lease Liabilities	0.8		0.9
Total Lease Rental Costs (a)	$	24.7	$	22.7

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

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


	December 31,
	2021		2020
Weighted-Average Remaining Lease Term (years):
Operating Leases	6.69		7.44
Finance Leases	5.54		5.9
Weighted-Average Discount Rate:
Operating Leases	3.56	%	3.60	%
Finance Leases	4.19	%	4.25	%


	Year Ended December 31,
	2021		2020
	(in millions)
Cash paid for amounts included in the measurement of lease liabilities:
Operating Cash Flows from Operating Leases	$	19.0	$	16.9
Operating Cash Flows from Finance Leases	5.7		5.6

Non-cash Acquisitions Under Operating Leases	$	4.2	$	18.1

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


	December 31,
	2021		2020
	(in millions)
Property, Plant and Equipment Under Finance Leases:
Utility Plant (a)	$	19.3	$	21.6
Net Property, Plant and Equipment Under Finance Leases	$	19.3	$	21.6

Obligations Under Finance Leases:
Noncurrent	$	14.9	$	16.9
Current	4.4		4.7
Total Obligations Under Finance Leases	$	19.3	$	21.6

(a) Includes $13 million and $10 million of accumulated provision for depreciation and amortization for the years ended December 31, 2021 and 2020, respectively.


	December 31,
	2021		2020
	(in millions)
Property, Plant and Equipment Under Operating Leases:
Utility Plant (a)	$	71.9	$	81.7
Nonutility Plant	12.4		12.4
Accumulated Provision for Depreciation and Amortization - Nonutility Plant	(3.2)		(2.1)
Net Property, Plant and Equipment Under Operating Leases	$	81.1	$	92.0

Obligations Under Operating Leases:
Noncurrent	$	68.6	$	79.5
Current	13.1		13.1
Total Obligations Under Operating Leases	$	81.7	$	92.6

(a) Includes $28 million and $18 million of accumulated provision for depreciation and amortization for the years ended December 31, 2021 and 2020, respectively.

Future minimum lease payments consisted of the following as of December 31, 2021:


	Finance Leases		Operating Leases
	(in millions)
2022	$	5.1	$	16.2
2023	4.4		15.2
2024	3.7		13.8
2025	2.5		12.1
2026	2.0		11.0
After 2026	4.0		24.2
Total Future Minimum Lease Payments	21.7		92.5
Less: Imputed Interest	2.4		10.8
Estimated Present Value of Future Minimum Lease Payments	$	19.3	$	81.7

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, 2021, 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, 2021 and December 31, 2020, respectively.

13. 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,
Company	Maturity	December 31, 2021	2021	2020	2021		2020
OPCo
Senior Unsecured Notes	2021-2051	3.87%	1.63%-6.60%	2.60%-6.60%	$	3,000.0	$	2,450.0
Other Long-term Debt	2028	1.15%	1.15%	1.15%	0.7		0.8
Unamortized Discount, Net					(9.5)		(6.5)
Total Long-term Debt Outstanding					$	2,991.2	$	2,444.3

As of December 31, 2021, long-term debt was payable as follows:


	(in millions)
2022	$	0.1
2023	0.1
2024	0.1
2025	0.1
2026	0.1
After 2026	3,000.2
Principal Amount	3,000.7
Unamortized Discount, Net	(9.5)
Total Long-term Debt	$	2,991.2

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 restriction that prohibits the payment of dividends out of capital accounts without regulatory approval; payment of dividends is allowed out of retained earnings only.

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, 2021 and 2020 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)
2021	$	259.2	$	622.9	$	61.6	$	127.2	$	42.0	$	500.0
2020	353.9		32.8		182.4		25.2		259.2		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 Rate		Interest Rate
	for Funds		for Funds		for Funds		for Funds		for Funds		for Funds
	Borrowed from		Borrowed from		Loaned to the		Loaned to the		Borrowed from		Loaned to the
Years ended	the Utility		the Utility		Utility Money		Utility Money		the Utility		Utility Money
December 31,	Money Pool		Money Pool		Pool		Pool		Money Pool		Pool
	(in millions)
2021	0.48	%	0.03	%	0.48	%	0.02	%	0.27	%	0.14	%
2020	2.70	%	0.27	%	2.08	%	2.05	%	0.99	%	2.06	%

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, 2021 and 2020.

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.

AEP Credit has a receivables securitization agreement that provides a commitment of $750 million from bank conduits to purchase receivables and was amended in September 2021 to include a $125 million and a $625 million facility, which expire in September 2023 and 2024, respectively.

The amount of accounts receivable and accrued utility revenues under the sale of receivables agreement as of December 31, 2021 and 2020 were $393 million and $399 million, respectively.

The fees paid to AEP Credit for customer accounts receivable sold were $8 million and $24 million for the years ended December 31, 2021 and 2020, respectively. In 2020, an increase in allowance for doubtful accounts was recognized in response to the anticipated impact of COVID-19 on the collectability of accounts receivable, which caused an increase in fees paid by OPCo. In 2021, due to higher than expected collections of accounts receivables, allowance for doubtful accounts was adjusted resulting in the issuance of credits to offset the higher fees previously paid and to lower subsequent fees paid.

The proceeds on the sale of receivables to AEP Credit were $2.5 billion and $2.4 billion for the years ended December 31, 2021 and 2020, respectively.

14. RELATED PARTY TRANSACTIONS

For other related party transactions, also see “AEP System Tax Allocation Agreement” section of Note 11 in addition to “Corporate Borrowing Program – AEP System” and “Securitized Accounts Receivables – AEP Credit” sections of Note 13.

Affiliated Revenues and Purchases

The following table shows the revenues derived from net transmission agreement sales and other revenues for the years ended December 31, 2021 and 2020:


	Years Ended December 31,
Related Party Revenues	2021	2020
	(in millions)
Transmission Agreement and Transmission Coordination Agreement Sales	$ (1.1)	$ 16.6
Other Revenues	25.9	24.9

The following table shows the purchased power expenses incurred for purchases from affiliates for the years December 31, 2021 and 2020:


		Years Ended December 31,
Related Party Purchases		2021	2020
		(in millions)
Auction Purchases from AEPEP (a)		$ 26.6	$ 51.0
Auction Purchases from AEP Energy (a)		25.3	58.7
Auction Purchases from AEPSC (a)		—	10.0
(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, 2021 and 2020 related to the TA were $509 million and $417 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, 2021 and 2020, OPCo billed AEPTCo $5 million and $5 million, respectively.

OVEC

AEP and several nonaffiliated utility companies jointly own OVEC. As of December 31, 2021, the ownership and investment in OVEC were as follows:


	December 31, 2021
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, 2021 and 2020, OVEC’s outstanding indebtedness was approximately $1.1 billion and $1.3 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 6 for additional information.

Purchased Power from OVEC

OPCo paid $133 million and $121 million for power purchased from OVEC for the years ended December 31, 2021 and 2020, 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,
	2021	2020
	(in millions)
Sales	$ 9.2	$ 7.0
Purchases	1.4	1.2

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

Sempra Renewables LLC PPAs

In April 2019, AEP acquired Sempra Renewables LLC and its ownership interests in 724 MWs of wind generation. The operating wind generation portfolio includes seven wind farms. Prior to the acquisition, two wind farms had existing PPAs with I&M, OPCo and SWEPCo. One of the joint venture wind farms has PPAs with I&M and OPCo for a portion of its energy production. The OPCo portion totaled $20 million and $23 million of purchased electricity for the years ended December 31, 2021 and 2020, respectively.

Intercompany Billings

OPCo and other AEP subsidiaries perform 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 $235 million and $233 million for the years ended December 31, 2021 and 2020, respectively.

15. 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)
2021	2.3	2.9	6.1
2020	2.3	3.1	5.0

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

OPCo records ARO in accordance with the accounting guidance for “Asset Retirement and Environmental Obligations” for asbestos removal. 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 its 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.

The following is a reconciliation of the 2021 and 2020 aggregate carrying amounts of ARO:


Year	ARO at January 1,		Accretion Expense		Liabilities Settled		ARO at December 31,
	(in millions)
2021	$	1.9	$	0.1	$	(0.1)	$	1.9
2020	1.8		0.1		—		1.9

16. 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,
	2021		2020
	(in millions)
Retail Revenues:
Residential Revenues	$	1,587.9	$	1,523.3
Commercial Revenues	722.7		682.0
Industrial Revenues (a)	286.3		270.0
Other Retail Revenues	12.6		13.1
Total Retail Revenues	2,609.5		2,488.4

Wholesale Revenues:
Transmission Revenues (a)	74.9		67.1
Total Wholesale Revenues	74.9		67.1

Other Revenues from Contracts with Customers (a)	148.3		105.9

Total Revenues from Contracts with Customers	2,832.7		2,661.4

Other Revenues:
Alternative Revenues (a)	42.6		65.9
Other Revenues (a)	27.1		22.7
Total Other Revenues	69.7		88.6

Total Operating Revenues	$	2,902.4	$	2,750.0

(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 purchase, sell, 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 encompasses a time frame greater than a year, where the performance obligation within 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.

OPCo 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.

Fixed Performance Obligations

The following table represents the remaining fixed performance obligations satisfied over time as of December 31, 2021. Fixed performance obligations primarily include wholesale transmission services, electricity sales for fixed amounts of energy and stand ready services into PJM’s RPM market. The amounts shown in the table below include affiliated and nonaffiliated revenues.


2022		2023-2024		2025-2026		After 2026		Total
(in millions)
$	78.3	$	—	$	—	$	—	$	78.3

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, 2021 and 2020.

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, 2021 and 2020.

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, 2021 and 2020. 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 $52 million and $46 million, as of December 31, 2021 and 2020.

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, 2021 and 2020.

17. 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, 2021 and 2020, as required by FERC Order No. 784:

Operation

Maintenance

Project

Functional

Project

Project Costs

Expenses

Name

Classification

Location

Account

Amount

Account

Amount

Account

Amount (a)

(dollars in millions)

Year Ended December 31, 2021

Citizens Station

Distribution

Bluffton, OH

363

5.1

—

Year Ended December 31, 2020

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:

05/19/2022

Year/Period of Report

End of:

2021

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			40,836				40,836
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	271,363,314	271,352,661
5	Balance of Account 219 at End of Preceding Quarter/Year			30,183				30,183
6	Balance of Account 219 at Beginning of Current Year			30,183				30,183
7	Current Quarter/Year to Date Reclassifications from Account 219 to Net Income			10,653				10,653
8	Current Quarter/Year to Date Changes in Fair Value
9	Total (lines 7 and 8)			10,653				10,653	253,646,878	253,636,225
10	Balance of Account 219 at End of Current Quarter/Year			19,530				19,530

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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)	9,247,374,554	9,247,374,554
4	UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases	91,206,605	91,206,605
5	UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold
6	UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified	765,653,275.00	765,653,275.00
7	UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified
8	UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7)	10,104,234,434	10,104,234,434
9	UtilityPlantLeasedToOthers Leased to Others
10	UtilityPlantHeldForFutureUse Held for Future Use	4,808,307	4,808,307
11	ConstructionWorkInProgress Construction Work in Progress	367,273,503	367,273,503
12	UtilityPlantAcquisitionAdjustment Acquisition Adjustments	636,577.00	636,577.00
13	UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12)	10,476,952,821	10,476,952,821
14	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion	2,913,414,961	2,913,414,961
15	UtilityPlantNet Net Utility Plant (13 less 14)	7,563,537,860	7,563,537,860
16	DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17	AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service:
18	DepreciationUtilityPlantInService Depreciation	2,793,337,717	2,793,337,717
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	119,424,313	119,424,313
22	DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21)	2,912,762,030	2,912,762,030
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	16,353	16,353
29	AmortizationUtilityPlantHeldForFutureUse Amortization
30	DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29)	16,353	16,353
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)	2,913,414,961	2,913,414,961

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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	210,317,826	52,577,700	19,484,100			243,411,426
5	TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)	210,327,269	52,577,700	19,484,100			243,420,870
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	122,729,464	3,808,735	43,268			126,494,931
48.1	(351) Energy Storage Equipment - Transmission
49	(352) Structures and Improvements	105,881,371	17,884,732	1,206,155			122,559,948
50	(353) Station Equipment	1,458,493,294	79,210,334	14,046,113			1,523,657,515
51	(354) Towers and Fixtures	195,759,555	24,823	582,957		187,508	195,388,929
52	(355) Poles and Fixtures	460,947,889	21,354,286	9,686,607		187,508	472,428,060
53	(356) Overhead Conductors and Devices	436,411,492	68,036,395	5,275,411			499,172,475
54	(357) Underground Conduit	15,732,294	4,182				15,736,476
55	(358) Underground Conductors and Devices	33,372,879	1,492,678	63,219			34,802,338
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)	2,829,331,359	191,816,164	30,903,730			2,990,243,792
59	4. Distribution Plant
60	(360) Land and Land Rights	73,792,779	11,236,517	14			85,029,283
61	(361) Structures and Improvements	50,764,860	5,585,328	318,598			56,031,590
62	(362) Station Equipment	964,943,080	78,619,602	7,250,954		6,557	1,036,305,172
63	(363) Energy Storage Equipment – Distribution	5,117,366					5,117,366
64	(364) Poles, Towers, and Fixtures	843,169,295	71,171,383	14,279,079			900,061,600
65	(365) Overhead Conductors and Devices	1,002,196,957	120,416,174	17,927,180			1,104,685,951
66	(366) Underground Conduit	389,592,614	37,178,033	64,801			426,705,846
67	(367) Underground Conductors and Devices	770,468,112	34,179,828	6,449,151			798,198,789
68	(368) Line Transformers	884,103,678	44,656,268	14,771,446			913,988,500
69	(369) Services	353,958,435	15,096,153	2,333,995			366,720,593
70	(370) Meters	264,917,296	10,487,953	3,864,665			271,540,584
71	(371) Installations on Customer Premises	60,329,941	3,653,464	3,879,377			60,104,028
72	(372) Leased Property on Customer Premises	103,067					103,067
73	(373) Street Lighting and Signal Systems	42,559,206	2,041,957	886,569			43,714,593
74	(374) Asset Retirement Costs for Distribution Plant
75	TOTAL Distribution Plant (Enter Total of lines 60 thru 74)	5,706,016,685	434,322,660	72,025,828		6,557	6,068,306,961
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	23,656,260	4,776,625	35,935			28,396,950
87	(390) Structures and Improvements	339,045,606	33,859,198	1,756,226			371,148,578
88	(391) Office Furniture and Equipment	24,058,797	1,269,052	28,673			25,299,177
89	(392) Transportation Equipment	489,630					489,630
90	(393) Stores Equipment	1,171,768	30,378	678			1,201,468
91	(394) Tools, Shop and Garage Equipment	53,571,255	2,587,622	543,032			55,615,846
92	(395) Laboratory Equipment	315,718	154,628				470,346
93	(396) Power Operated Equipment	2,894					2,894
94	(397) Communication Equipment	201,299,364	21,382,034	614,766		6,557	222,073,189
95	(398) Miscellaneous Equipment	4,919,072	869,272	53,085			5,735,259
96	SUBTOTAL (Enter Total of lines 86 thru 95)	648,530,365	64,928,810	3,032,395		6,557	710,433,336
97	(399) Other Tangible Property
98	(399.1) Asset Retirement Costs for General Plant	771,672		148,803			622,869
99	TOTAL General Plant (Enter Total of lines 96, 97, and 98)	649,302,037	64,928,810	3,181,198		6,557	711,056,206
100	TOTAL (Accounts 101 and 106)	9,394,977,351	743,645,334	125,594,856			10,013,027,829
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)	9,394,977,351	743,645,334	125,594,856			10,013,027,829

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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	469,402.85
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	12/31/2022	252,571.59
6	Giles 138/13.2 KV Substation (0383)	08/01/2009	12/31/2022	699,996.90
7	Shanahan Substation (0277)	11/01/2010	12/31/2027	251,639.62
8	Items under $250,000			2,439,203.90
21	Other Property:
22	Items under $250,000			23,007.00
47	TOTAL			4,808,307

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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	AMI IT Work	4,454,809
2	AMI Web Portal	7,126,104
3	Astor - Replace UG TFXR Cables	1,771,227
4	Astor - Rp Feeder Exit Cables	1,313,578
5	Bixby - UG Feeder Exits	3,903,642
6	Cambridge Service Center (New)	10,635,782
7	Chillicothe District CB Repl	1,157,500
8	CIS-Common Deployment-OP D	1,866,375
9	Columbus Southwest SC Constr	4,513,905
10	Corp Prgrm Billing - OPCO Tran	1,555,571
11	Crooksville-N.Newark Opco-T CI	2,138,913
12	D/OP/Capital Blanket - OHPCo	7,574,900
13	DACR Control	1,371,874
14	DACR Distribution Line	7,434,268
15	DACR Telecomm	1,180,257
16	DeCliff_LaRue OP-T CI	1,844,812
17	E. Broad-Astor OPCO	1,002,603
18	Ed-Ci-Opco-D Ast Imp	28,848,449
19	Ed-Ci-Opco-D Cust Serv	2,946,517
20	Fifth Av D-Sta Retire & Instal	1,949,886
21	Grandview Warehouse (New)	1,391,198
22	Groves 3 Duct & MH Renewal	4,584,144
23	Hayden Sta - Dist Station	3,003,644
24	Hess F-5420 UG D-Line	2,848,425
25	Marion East Duct & MH Renewal	1,362,116
26	Marion South Duct & MH Renewal	2,139,194
27	Mifflin D&MH Renew McCutcheon	1,796,745
28	Minford Battery Installation	3,526,117
29	Multi Ph OH line rebld or relo	1,631,180
30	New Albany TCC Remodel Area B	5,550,127
31	Ohio Power Trans Work	1,816,621
32	Ohio Power Transmission work	10,031,123
33	Ohio Power Transmission work	1,388,443
34	Ohio Power Transmission work	4,674,809
35	Ohio PowerCo -Transmission CI	2,440,829
36	OHPCo T-BlnktProj Under $3M	3,699,430
37	OPCO D work New repla	3,121,601
38	OPCo Distr Pre Eng Parent	12,307,318
39	OPCo Major Eq/Spares-Distr	2,883,676
40	OPCo T Supplemental Work	12,215,196
41	OPCO T work New repla	3,452,604
42	OPCo Trans Pre Eng Parent	8,821,637
43	OPCo-D Service Restoration Blk	2,313,933
44	OPCo-D Small Cap Adds Blkt	6,479,781
45	OPCO-D Telecom	6,164,076
46	OPCO-D work	1,596,760
47	OPCO-T CI Work	1,045,708
48	OPCO-T Glencoe-Somerton	2,105,389
49	OPCO-T Work CI	1,112,463
50	OP-D	2,382,116
51	OP-T	1,128,823
52	OP-T - Supplemental	1,513,673
53	OP-T Supplemental	2,027,647
54	OSU F-7705 D-Line UG	2,022,677
55	Parsons - New 13kV Feeder	1,533,916
56	Parsons F-5705 UG Exit	1,115,311
57	Reaver Substation - D station	6,238,179
58	Salerno Dist. Station Work	1,455,530
59	Shannon- D-line UG exit-F-8907	1,453,145
60	SS-CI-OPCo-D GEN PLT	2,920,474
61	SS-CI-OPCo-T GEN PLT	9,271,061
62	Stuart-Seaman Opco-T CI	15,409,753
63	T/OH/Ohio Power Trans work	1,872,286
64	T/OP/Capital Blanket - OHPCo	5,889,599
65	T/OP/NERC Physical Security	38,544,340
66	T/OP/Ohio Power Trans Work	1,491,415
67	Trans station Renew-Refurb OH	1,732,008
68	URD Cable Rehab Replacement	1,560,808
69	WestNet Cable Repl PILC Elec	1,274,966
70	Other Minor Projects under $1,000,000	59,973,759
43	Total	367,273,503

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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	2,702,062,103	2,702,038,283	23,820
2	Depreciation Provisions for Year, Charged to
3	DepreciationExpenseExcludingAdjustments (403) Depreciation Expense	253,282,153	253,282,153
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):	29,462	(a) 29,124	(b) 337
10	DepreciationProvision TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)	253,311,615	253,311,278	337
11	Net Charges for Plant Retired:
12	BookCostOfRetiredPlant Book Cost of Plant Retired	106,008,726	105,993,427	15,299
13	CostOfRemovalOfPlant Cost of Removal	64,762,767	(c) 64,761,555	1,212
14	SalvageValueOfRetiredPlant Salvage (Credit)	8,238,338	(d) 8,229,632	8,707
15	NetChargesForRetiredPlant TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)	162,533,155	162,525,351	7,804
16	OtherAdjustmentsToAccumulatedDepreciation Other Debit or Cr. Items (Describe, details in footnote):
17.1	Other Debit or Cr. Items (Describe, details in footnote):	513,507	(e) 513,507
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)	2,793,354,070	2,793,337,717	16,353
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	895,366,919	895,344,939	21,980
26	AccumulatedDepreciationDistribution Distribution	1,778,399,304	1,778,404,931	5,627
27	AccumulatedDepreciationRegionalTransmissionAndMarketOperation Regional Transmission and Market Operation
28	AccumulatedDepreciationGeneral General	119,587,847	119,587,847
29	AccumulatedProvisionForDepreciationOfElectricUtilityPlant TOTAL (Enter Total of lines 20 thru 28)	2,793,354,070	2,793,337,717	16,353

FOOTNOTE DATA

(a) Concept: OtherAccounts

Depreciation expense on asbestos ARO (OAJ143) $29,124

(b) Concept: OtherAccounts

Depreciation expense on account 105, Held for Future Use classified to account 421 $337

Includes $8,875,640 of removal cost in retirement work in progress (RWIP).

(d) Concept: SalvageValueOfRetiredPlant

Includes ($4,767,584)of salvage in retirement work in progress (RWIP).

(e) Concept: OtherAdjustmentsToAccumulatedDepreciation


Reclass the gain on closure of ARO liability and loss on retirement of ARO asset for the Portsmouth Service Center to 1080013			$55,757
To record the accumulated depreciation for the acquisition of North Intertie Station			($662,131)
Defer ARO Deprec&Accretion Exp			$140,242
Record gain on Racine Hydro Assets			($47,375)
TOTAL			($513,507)

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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: Limited Partnership Interest	11/22/2013		1,210,876			1,438,892
2	REV1 FUND I, LLC Limited Partnership Interest	09/30/2016		474,551			561,885
3	REV1 Fund II Limited Partnership Interest	07/15/2021					28,776
42	Total Cost of Account 123.1 $		Total	1,685,427			2,029,553

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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)	55,529,297	70,251,610	Electric
6	Assigned to - Operations and Maintenance
7	Production Plant (Estimated)
8	Transmission Plant (Estimated)	3,844,429	1,017,815	Electric
9	Distribution Plant (Estimated)	7,214,309	2,723,345	Electric
10	Regional Transmission and Market Operation Plant (Estimated)
11	Assigned to - Other (provide details in footnote)	(a) 296,555	(b) 142,085	Electric
12	TOTAL Account 154 (Enter Total of lines 5 thru 11)	66,884,590	74,134,855
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	66,884,590	74,134,855

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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 Martinsville-Wilmington 69kV	430	186
3	AE1-093 ELK 138KV	521	186	700	186
4	AE2-136 MUSKINGUM RIVER-W MILLERSPORT 345KV	535	186	710	186
5	AF1-029 HAVILAND-N VAN WERT 69KV	7,224	186	7,331	186
6	AF1-047 MARK CENTER 69KV	1,447	186	1,744	186
7	AF1-051 Gavin 765KV	370	186	253	186
8	AF1-062 Jug Street 138KV	13,376	186	14,382	186
9	AF1-076 Southwest Lima 138kV	23,608	186	24,131	186
10	AF1-077 Southwest-Lima 138kV	907	186	811	186
11	AF1-085 SOUTHWEST LIMA-WEST MOULTON 138KV	8,522	186	5,501	186
12	AF1-113 Gristmill 345kV	11,683	186	11,536	186
13	AF1-117 ATLANTA-STUART 345KV	1,958	186	1,742	186
14	AF1-144 HAYDEN 345KV	13,986	186	13,437	186
15	AF1-164 Southwest Lima 345kV	5,075	186	5,177	186
16	AF1-227 Marysville-East Lima 345kV	40,217	186	33,515	186
17	AF1-275 COLE 345KV	2,737	186	2,216	186
18	AF1-283 STUART-CLINTON 345KV	238	186	238	186
19	AF1-285 GUNN ROAD 345KV	2,942	186	2,942	186
20	AF2-014 Maddox Creek 345kV	16,785	186	14,138	186
21	AF2-059 Southwest Lima-West Moulton 138kV	1,665	186	1,665	186
22	AF2-124 Kyger Creek-Pierce 138V	2,185	186	1,980	186
23	AF2-124 Kyger Creek-Pierce	1,509	186	1,509	186
24	AF2-127 Lockwood Road 138kV	220	186	220	186
25	AF2-137 Marysville-Sorenson 765kV	22,546	186	20,266	186
26	AF2-149 Sharp Road 69kV	589	186	589	186
27	AF2-198 Heath 138kV	504	186	504	186
28	AF2-209 South Hicksville-Sowers 138kV	14,023	186	12,835	186
29	AF2-376 Timber Switch 138kV	1,236	186	1,143	186
30	AF2-440 Hillsboro-Middleboro 138kV (1)	3,110	186	3,110	186
31	AF2-440 Hillsboro-Middleboro 138kV (2)	1,256	186	1,256	186
32	AG1-003 Marysville-Sorenson 765KV	619	186	558	186
33	AG1-004 Marysville-Sorenson 765KV	608	186	554	186
34	AG1-013 Marysville-Sorenson 765KV	648	186	785	186
35	AG1-042 Hayden 345kV	1,516	186	1,313	186
36	AG1-076 Fostoria Central 138kV (1)	59	186	100	186
37	AG1-076 Fostoria Central 138kV (2)	312	186	232	186
38	AG1-163 West Millersport 138kV	3,501	186	2,912	186
39	AG1-218 Marysville-Tangy 345kV	1,473	186	2,120	186
40	AG1-218 Marysville-Tangy 345kV	1,040	186	973	186
41	AG1-358 Howard-Melmore 138kV	906	186	1,363	186
42	AG1-369 Logtown 138kV	526	186	789	186
43	AG1-369 Logtown 138kV	562	186	505	186
44	AG1-380 Corwin 138KV	705	186	925	186
45	AG1-410 RP Mone-Maddox 345kV	771	186	1,154	186
46	AG1-411 RP Mone-Maddox 345kV	548	186	802	186
47	AG1-456 Hillsboro-Wildcat 138kV	640	186	975	186
48	AG1-456 Hillsboro-Wildcat 138kV	642	186	536	186
49	AG1-554 South Kenton 138kV	904	186	1,404	186
50	AG1-554 South Kenton 138kV	940	186	874	186
51	AG1-562 Marysville-Gunn Road 345kV	485	186	702	186
52	AG2-003 West Millersport 138kV	1,257	186	1,604	186
53	AG2-006 Centerburg-Conesville 138kV	1,563	186	1,901	186
54	AG2-031 East Canton-Robertsville 69kV	2,733	186	3,807	186
55	AG2-033 Southwest Lima-West Moulton 138kV	984	186	1,433	186
56	AG2-082 Nottingham 138kV	1,126	186	1,108	186
57	AG2-104 Marysville-Flatlick 765KV	1,725	186	1,705	186
58	AG2-105 Marysville-Flatlick 765kV	1,522	186	1,504	186
59	AG2-106 Marysville-Flatlick 765KV	630	186	616	186
60	AG2-107 Marysville-Flatlick 765KV	623	186	609	186
61	AG2-110 Marysville-Tangy 345KV	1,059	186	1,051	186
62	AG2-148 S Berwick-Galion 345kV	361	186	347	186
63	AG2-175 Van Wert-Delphos 69kV	1,677	186	1,625	186
64	AG2-194 Pierce-Kyger Creek 345kV	1,533	186	1,490	186
65	AG2-218 La Rue 69kV	1,730	186	1,684	186
66	AG2-383 Conesville 138kV	3,512	186	2,828	186
67	AG2-444 Bixby-Biers Run 345kV	1,078	186	2,296	186
68	AG2-445 Adkins-Atlanta 345kV	719	186	711	186
69	AG2-452 SW Lima-Shelby 345kV	272	186
70	AG2-470 Fostoria-Lemoyne 345k	658	186	644	186
71	AG2-503 Adams 138kV	906	186	896	186
72	AG2-547 New Liberty-Boutwell 138kV	1,541	186	1,505	186
73	AG2-548 Corwin-Elk 138kV	1,024	186	998	186
74	AH1-015 Academia 138kV	991	186	967	186
75	AH1-032 West Millersport 138kV	555	186	541	186
76	First Energy - London-Beatty System Impact Study	4,896	186
77	PJM - #AC1-194	8,178	186	8,269	186
78	PJM - #AC2-016	18	186
79	PJM - #AC2-029	4,861	186	5,289	186
80	PJM - #AC2-055	13,386	186	17,026	186
81	PJM - #AC2-055	11	186
82	PJM - #AC2-060	19,975	186
83	PJM - #AC2-060	36	186
84	PJM - #AC2-061	17	186
85	PJM - #AD1-015	7,697	186	10,291	186
86	PJM - #AD1-070	11,378	186	20,308	186
87	PJM - #AD1-106	12,786	186	14,804	186
88	PJM - #AD1-106	19	186
89	PJM - #AD1-130	10,185	186	8,297	186
90	PJM - #AD2-014 STEUBENVILLE-TIDD 138KV	8	186
91	PJM - #AD2-016 BIERS RUN-CIRCLEVILLE 138KV	20	186
92	PJM - #AD2-067 CENTERBURG 138KV	17,230	186	17,462	186
93	PJM - #AD2-078 N HAVERHILL 69KV	9	186
94	PJM - #AD2-092 - 093 - 096 MARYSVILLE 345KV	7	186
95	PJM - #AD2-136 MELMORE TAP 138KV	182	186
96	PJM - #AD2-162 BIERS RUN-CIRCLEVILLE 138KV	13,010	186	5,892	186
97	PJM - #AD2-162 BIERS RUN-CIRCLEVILLE 138KV	18	186
98	PJM - #AD2-189 KAMMER-VASSELL 765KV	137	186	156	186
99	PJM - #AD2-191 MELMORE 138KV	96	186
100	PJM - #AE1-040 GREENFIELD 69KV	9	186
101	PJM - #AE1-090 HARDIN SWITCH 345KV	104	186	398	186
102	PJM - #AE1-091 WEST NEWTON-LYNN 138KV	11,414	186	12,602	186
103	PJM - #AE1-146 EBERSOLE 2-FOSTORIA CENTRAL 138KV	18,489	186	18,607	186
104	PJM - #AE1-245 HAVILAND 138KV	623	186
105	PJM - #AE1-245 HAVILAND 138KV	1,094	186	1,107	186
106	PJM - #AE2-048 MUSKINGUM-W MILLERSPORT 345KV	88	186
107	PJM - #AE2-072 EAST LEIPSIC-RICHLAND 138KV	181	186
108	PJM - #AE2-073 CENTERBURG 138KV	11	186
109	PJM - #AE2-073 CENTERBURG 138KV	100	186
110	PJM - #AE2-136 MUSKINGUM RIVER-W MILLERSPORT 345KV	9	186
111	PJM - #AE2-136 MUSKINGUM RIVER-W MILLERSPORT 345KV	148	186
112	PJM - #AE2-148 BEATTY-GREENE 345KV	785	186
113	PJM - #AE2-174 SENECA 138KV	52	186
114	PJM - #AE2-174 SENECA 138KV	707	186	682	186
115	PJM - #AE2-176 GROTON 138KV	12	186
116	PJM - #AE2-214 COLE 345KV	192	186
117	PJM - #AE2-290 NOTTINGHAM 138KV	540	186
118	PJM - #AE2-290 NOTTINGHAM 138KV	225	186
119	PJM - #AE2-298 HAVILAND-CONVOY 69KV	116	186
120	PJM - #AE2-298 HAVILAND-CONVOY 69KV	282	186
121	PJM - #AE2-302 EAST BEAVER-LICK 138KV	142	186
122	PJM - #AE2-319 ATLANTA 69KV	10	186
123	PJM - #AE2-320 ATLANTA 69KV	10	186
124	PJM - #AE2-322 MARK CENTER 69KV	73	186
125	PJM - #AE2-327 BIERS RUN-CIRCLEVILLE 138KV	34	186
126	PJM - #AF1-029 HAVILAND-N VAN WERT 69KV	49	186
127	PJM - #AF1-029 HAVILAND-N VAN WERT 69KV	459	186
128	PJM - #AF1-047 MARK CENTER 69KV	337	186
129	PJM - #AF1-051 GAVIN 765KV	196	186
130	PJM - #AF1-062 JUG STREET 138KV	289	186
131	PJM - #AF1-063 LOCKWOOD ROAD 138KV	174	186
132	PJM - #AF1-076 SOUTHWEST-LIMA 138KV	260	186
133	PJM - #AF1-077 SOUTHWEST-LIMA 138KV	246	186
134	PJM - #AF1-085 SOUTHWEST LIMA-WEST MOULTON 138KV	163	186
135	PJM - #AF1-113 GRISTMILL 345KV	168	186
136	PJM - #AF1-117 ATLANTA-STUART 345KV	162	186
137	PJM - #AF1-144 HAYDEN 345KV	63	186
138	PJM - #AF1-144 HAYDEN 345KV	321	186
139	PJM - #AF1-164 SOUTHWEST LIMA 345KV	130	186
140	PJM - #AF1-227 SOUTHWEST LIMA 345KV	7	186
141	PJM - #AF1-228 BEATTY-GREENE 345KV	26,277	186	25,585	186
142	PJM - #AF1-228 BEATTY-GREENE 345KV	27	186
143	PJM - #AF1-229 GALION-SOUTH BERWICK 345KV	12,693	186	11,290	186
144	PJM - #AF1-229 GALION-SOUTH BERWICK 345KV	69	186
145	PJM - #AF1-229 GALION-SOUTH BERWICK 345KV	96	186
146	PJM - #AF1-230 CHATFIELD 138KV	317	186
147	PJM - #AF1-275 COLE 345KV	40	186
148	PJM - #AF1-275 COLE 345KV	381	186
149	PJM - #AF1-285 GUNN ROAD 345KV	46	186
150	PJM - #AF1-285 GUNN ROAD 345KV	33	186
151	PJM - #AF1-308 WAVERLY 138KV	68	186
152	PJM - #AF2-014 MADDOX CREEK 345KV	222	186
153	PJM - #AF2-014 MADDOX CREEK 345KV	1,495	186	1,637	186
154	PJM - #AF2-048 RIO - LICK 138KV	130	186
155	PJM - #AF2-048 RIO - LICK 138KV	8,227	186	9,179	186
156	PJM - #AF2-059 SOUTHWEST LIMA-WEST MOULTON 138KV	133	186
157	PJM - #AF2-103 HAVILAND 138KV	107	186
158	PJM - #AF2-122 KIRK 138KV	193	186
159	PJM - #AF2-122 KIRK 138KV	2,164	186	2,378	186
160	PJM - #AF2-124 DOE 530-PIERCE 138KV	441	186
161	PJM - #AF2-127 LOCKWOOD ROAD 138KV	155	186
162	PJM - #AF2-127 LOCKWOOD ROAD 138KV	349	186	349	186
163	PJM - #AF2-137 MARYSVILLE-SORENSON 765KV	170	186
164	PJM - #AF2-137 MARYSVILLE-SORENSON 765KV	8,561	186	9,682	186
165	PJM - #AF2-149 BLACKJACK ROAD-MARTINSBURG 69KV	360	186
166	PJM - #AF2-149 SHARP ROAD 69KV	1,692	186	1,692	186
167	PJM - #AF2-186 SOUTH CECIL 69KV	310	186	503	186
168	PJM - #AF2-186 SOUTH CECIL 69KV
169	PJM - #AF2-198 HEATH-NORTH NEWARK 138KV	206	186
170	PJM - #AF2-198 HEATH-NORTH NEWARK 138KV	1,067	186	1,067	186
171	PJM - #AF2-209 S HICKSVILLE-SOWERS 138KV
172	PJM - #AF2-217 HYATT-MARYSVILLE 345KV	64	186
173	PJM - #AF2-223 MARYSVILLE 345KV	184	186
174	PJM - #AF2-223 MARYSVILLE 345KV	750	186	750	186
175	PJM - #AF2-371 HARRISON-GOOD HOPE 138KV	587	186	587	186
176	PJM - #AF2-371 HARRISON-POSTON 138KV	233	186
177	PJM - #AF2-375 FOSTORIA CENTRAL 345KV	209	186
178	PJM - #AF2-375 FOSTORIA CENTRAL 345KV	866	186	866	186
179	PJM - #AF2-376 TIMBER SWITCH 138KV	121	186
180	PJM - #AF2-376 TIMBER SWITCH 138KV	295	186	295	186
181	PJM - #AF2-377 LOGTOWN 138KV	145	186
182	PJM - #AF2-377 LOGTOWN 138KV	545	186	545	186
183	PJM - #AF2-377 Logtown 138KV	2,035	186	1,447	186
184	PJM - #AF2-395 FLATLICK 765KV	128	186
185	PJM - #AF2-395 FLATLICK 765KV	569	186	350	186
186	PJM - #AG1-003 MARYSVILLE-SORENSON 765KV	439	186	649	186
187	PJM - #AG1-004 MARYSVILLE-SORENSON 765KV	969	186	1,509	186
188	PJM - #AG1-024 CENTERBURG 138KV	1,577	186	2,300	186
189	PJM - #AG1-025 SOUTHWEST LIMA-WEST MOULTON 138KV	323	186	332	186
190	PJM - #AG1-034 CENTERBURG-CONESVILLE 138KV	1,591	186	2,101	186
191	PJM - #AG1-042 HAYDEN 345KV	2,314	186	2,808	186
192	PJM - #AG1-125 MARYSVILLE-FLATLICK 765KV	1,631	186	2,065	186
193	PJM - #AG1-126 MARYSVILLE-FLATLICK 765KV	1,100	186	1,408	186
194	PJM - #AG1-161 CONESVILLE 138KV	1,441	186	2,085	186
195	PJM - #AG1-162 CONESVILLE 138KV	1,413	186	1,785	186
196	PJM - #AG1-163 WEST MILLERSPORT 138KV	838	186	1,231	186
197	PJM - #AG1-239 BLUE BELL-SOUTH EAST CANTON 138KV	376	186	493	186
198	PJM - #AG1-326 CIRCLEVILLE-BIERS RUN 138KV	1,129	186	1,592	186
199	PJM - #AG1-351 HARRISON-GOOD HOPE 138KV	1,348	186	1,908	186
200	PJM - AD1-073 Buckskin 69kV	1,363	186	1,838	186
201	PJM - AD1-101 Continental 69kV	59,425	186	58,109	186
202	PJM - AD1-119 Payne 69kV	75,751	186	80,146	186
203	PJM - AD2-016 Biers Run - Circleville 138kV	162	186	711	186
204	PJM - AD2-086 Marysville - E Lima 345kV	380	186	882	186
205	PJM - AD2-091 Hardin Tap Facility Study	104	186	166	186
206	PJM - AD2-092 Marysville 345kV	2,135	186	3,412	186
207	PJM - AD2-093 Marysville 345kV	799	186	785	186
208	PJM - AD2-096 Marysville 345kV	563	186	920	186
209	PJM - AE1-102 - Maddox Creek-Blue Creek Wind R60 34.5kV	814	186	814	186
210	PJM - AF1-206 FAYETTE-LYONS 138KV	66	186	66	186
211	PJM - AF1-206 FAYETTE-LYONS 138KV	66	186
212	PJM - AF1-282 STUART-CLINTON 345KV	5	186
213	PJM - AF1-283 STUART-CLINTON 345KV	9	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:

05/19/2022

Year/Period of Report

End of:

2021

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	12,325,577	26,988,503	566	34,105,200	5,208,880
3	COVID-19 Deferred Expense	4,410,725	552,992	182, 426	4,963,717
4	PJM 2020 Transmission DeferralAmortization period: Jan 2022-Dec 2022		7,532,766			7,532,766
5	FERC Formula Rates Under Recvr	2,937,028	4,658,376	242, 234, 253, 456, 146	3,395,226	4,200,178
6	Smart City Rider (SCR) Case No. 16-1852-EL-SSO Case No. 16-1853-EL-AAM	3,598,736	5,811,887	456, 908	8,434,893	975,730
7	SFAS 112 Post-Employment Benefits- Case No. 08-917-EL-SSO	6,648,799		228, 242	487,166	6,161,633
8	EDR Deferral	1,271,601	11,284,839	440, 442, 444, 445, 447	2,473,060	10,083,380
9	Deferred Storm Expense	4,077,349	5,529,937	593	5,819,370	3,787,916
10	Under-Recovery of Excess Deferred Federal Income Tx- Case No. 18-1007-EL-UNC- Case No. 18-1451-EL-ATA	824,465	1,123,984	407	1,698,864	249,585
11	Rate Case Expenses - Ohio 2020	73,803				73,803
12	Under Recovered ESRP Cost - OH		10,447,741	254, 593	909,952	9,537,789
13	SFAS 106 Medicare Subsidy - Amortization Period: 01/2013 to 12/2024	4,128,814		926	1,032,204	3,096,610
14	SFAS 109 Flow-through Deferred Federal Inc Tx (FIT)	59,397,310	14,202,622	282/283	14,362,447	59,237,485
15	SFAS 109 Flow-through Deferred State Inc Tx (SIT)	3,286,201	287,169	283	821,059	2,752,311
16	Pilot Throughput Balancing Adjust Rider (PTBAR) Carrying Charges (Distribution Decoupling	732,884	1,682,618	442	1,574,193	841,309
17	Unrealized Loss on Forward Commitments	110,332,688	16,475,106	244, 254	34,242,193	92,565,601
18	Pilot Throughput Balancing Adjustment Rider (PTBAR) Under-Recovery (Distribution Decoupling Revenue	15,871,326	29,152,703	182, 442	20,721,566	24,302,463
19	Unrealized Loss on Forward Commitments - Netting of Trading Activities between Regulated Assets / Liabilities	345,033	1,028,926	244, 254	1,147,322	463,429
20	GridSMART Phase 2 Under-Recovery - Case No. 13-1939-EL-RDR	19,167,742	6,037,532	403	5,910,361	19,294,913
21	Under-Recovery Ohio Valley Electric Corporation (OVEC) Purchased Power Agreement (PPA) - Case No. 14-1693-	27,400,514	1,758,382	555	29,158,896
22	Distribution Deferred Assets - Partnership With Ohio (PWO) - Case No. 16-1852-EL-SSO - Case No. 16-1853-	166,667	500,000	426	666,667
23	SFAS 158 Employers' Accounting for Defined Benefit	130,739,080	156,696,840	129, 165, 228	204,148,832	83,287,088
24	GreenHat Settlement Regulatory Deferral	5,981		232, 566	5,981
25	ACRR Costs - OH	3,244,429	5,491,006	254, 555	8,735,435
26	Under-Recovery Distribution Investment Rider (DIR)Case No. 16-1852-EL-SSO Case No. 16-1853-EL-AAM	7,368,738	9,614,569	254, 440, 442, 444, 403	14,857,299	2,126,008
27	Under-Recovery Distribution Decoupling Revenue Program (Pilot Throughput Balancing Adjustment Rider	29,152,703	16,310,290	407, 442, 440	29,411,567	16,051,426
28	Bad Debt Rider Under-Recovery Case No. 20-585		1,925,194	426, 182	1,220,359	704,835
29	Distribution Decoupling Revenue Program Carrying Charges	872,173	1,259,966	407, 421, 442, 440	1,695,502	436,637
44	TOTAL	447,749,840	336,353,948		431,999,331	352,104,457

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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	315,882,907	357,042,916	408,107	321,723,303	351,202,520
2	Agency Fees - Factored A/R	7,975,878	50,714,768	142	51,010,526	7,680,120
3	Unamortized Credit Line Fees	407,894	1,313,235	146,431	627,756	1,093,372
4	Deferred Expenses - Misc.	63,655	124,586	142, 143, 152, 565	181,518	6,723
5	Def Lease Assets - Non Taxable	81,104	843,368	142,143	649,409	275,062
6	Transource PJM LSE Over/Under Deferral		3,453,253	565	3,036,475	416,778
47	Miscellaneous Work in Progress	1,878,170				2,490,433
48	Deferred Regulatroy Comm. Expenses (See pages 350 - 351)
49	TOTAL	326,289,608				363,165,008

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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	18,567,883	23,336,485
3	EXCESS ADFIT	121,101,283	111,844,494
4	BOOK OPERATING LEASE - LIAB	19,438,380	17,163,477
5	INT EXP CAPITALIZED FOR TAX	34,910,648	37,143,358
6	ACCRD SFAS 106 PST RETIRE EXP	10,328,397	12,124,667
7	Other	95,580,005	92,956,299
8	TOTAL Electric (Enter Total of lines 2 thru 7)	88,109,792	84,406,848
9	Gas
15	Other
16	TOTAL Gas (Enter Total of lines 10 thru 15)
17.1	Other (Specify) Nonutility, SFAS 109, 87 & 133	122,690,343	119,950,603
17	Other (Specify)
18	TOTAL (Acct 190) (Total of lines 8, 16 and 17)	210,800,135	204,357,451

Notes

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

2022-05-19

Year/Period of Report

End of:

2021

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
16	MiscellaneousPaidInCapital Ending Balance Amount	4,971,195
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	838,781,212

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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 04/01/2030 Per PUCO Case No. 19-402-EL-AIS		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	(a) 5.375% Unsecured Notes Series M Due 10/2021		500,000,000		3,682,837		2,065,000	09/04/2009	10/01/2021	09/04/2009	10/01/2021		20,156,250
22	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
23	(b) 1.625% Unsecured Notes Series Q Due 1/2031		450,000,000		3,749,956		706,500	01/07/2021	01/15/2031	01/07/2021	01/15/2031	450,000,000	7,190,625
24	(c) 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	5,220,000
25	Groveport Service Center Facility Lease:
26	Groveport Facilty Lease		1,138,364					05/01/2013	04/30/2028	05/01/2013	04/30/2028	748,198
27	Subtotal		3,501,138,364		32,153,017		15,202,500					3,000,748,198	123,891,875
33	TOTAL		3,501,138,364									3,000,748,198	123,891,875

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

FOOTNOTE DATA

(a) Concept: ClassAndSeriesOfObligationCouponRateDescription

The $500M 5.375% fixed rate Series M Senior Unsecured Note issued in 09/04/2009 was matured in 10/01/2021. All issuance expenses and discounts are fully amortized.

(b) 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.

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:

05/19/2022

Year/Period of Report

End of:

2021

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)	253,646,878
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	24,008,742
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:

05/19/2022

Year/Period of Report

End of:

2021

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			6,828,625	0	6,809,253	7,855,420		7,836,048	0	10,993,493			4,184,240
2	Subtotal Federal Tax				6,828,625	0	6,809,253	7,855,420		7,836,048	0	10,993,493			4,184,240
3	State Tax 2014	State Tax	IL	2014	8,731	0				8,731	0
4	State Tax 2016	State Tax	IL	2016	1	0				1	0
5	State Tax 2017	State Tax	IL	2017	1,337	0				1,337	0
6	State Tax 2018	State Tax	IL	2018	210,013	0				210,013	0
7	State Tax 2019	State Tax	IL	2019	197,109	0				197,109	0
8	State Tax 2020	State Tax	IL	2020	43,051	0	3,978			47,029	0				3,978
9	State Tax 2021	State Tax	IL	2021	0	0	54,707			54,707	0	54,707
10	State Tax 2017	State Tax	KY	2017	57,645	0				57,645	0
11	State Tax 2018	State Tax	KY	2018	13,750	0				13,750	0
12	State Tax 2019	State Tax	KY	2019	6,814	0				6,814	0
13	State Tax 2020	State Tax	KY	2020	7,295	0	568			7,863	0				568
14	State Tax 2021	State Tax	KY	2021	0	0	7,785			7,785	0	7,785
15	State Tax 2017	State Tax	MI	2017	6,008	0				6,008	0
16	State Tax 2018	State Tax	MI	2018	8,148	0				8,148	0
17	State Tax 2019	State Tax	MI	2019	623	0				623	0
18	State Tax 2020	State Tax	MI	2020	344	0				344	0
19	State Tax 2017	State Tax	WV	2017	23,273	0				23,273	0
20	State Tax 2018	State Tax	WV	2018	28,658	0				28,658	0
21	State Tax 2019	State Tax	WV	2019	54,946	0				54,946	0
22	State Tax 2020	State Tax	WV	2020	29,517	0	2,954			32,471	0				2,954
23	State Tax 2021	State Tax	WV	2021	0	0	22,634			22,634	0	22,634
24	State Tax 2019	State Tax	MULTI	2019	1,904,877	0				1,904,877	0
25	State Tax 2021	State Tax	MULTI	2021	0	0				0	0	3,196,258			3,196,258
26	State Tax 2021	State Tax	OH	2021	0	0				0		127,254			127,254
27	Subtotal State Tax				2,170,206	0	77,626			2,247,832	0	2,983,878			3,061,504
28	Local Tax 2017	Local Tax	OH	2017	2,900,290	0				2,900,290	0
29	Local Tax 2018	Local Tax	OH	2018	2,888,066	0				2,888,066	0
30	Local Tax 2019	Local Tax	OH	2019	4,253,111	0				4,253,111	0
31	Local Tax 2020	Local Tax	OH	2020	192,209	0	127,254			319,463	0				127,254
32	Local Tax 2021	Local Tax	OH	2021	0	0	127,255			127,255	0				127,255
33	Subtotal Local Tax				4,457,544	0	1			4,457,543	0				1
34	Property Tax 2019	Property Tax	OH	2019	293,357,055	0	1,103,259	292,253,796		0	0	1,098,421			4,838
35	Property Tax 2020	Property Tax	OH	2020	315,240,773	0	7,193,019	1,497,209		320,936,583	0	321,694,576			314,501,557
36	Property Tax 2021	Property Tax	OH	2021	0	0	350,991,901	4,473		350,987,428	0	988,999			350,002,902
37	Property Tax 2019	Property Tax	WV	2019	459,919	0		459,919		0	0	452,975			452,975
38	Property Tax 2020	Property Tax	WV	2020	829,174	0	1,302	413,936		413,936	0	407,585			408,887
39	Property Tax 2021	Property Tax	WV	2021	0	0	806,263			806,263	0				806,263
40	Subtotal Property Tax				609,886,921	0	357,886,622	294,629,333		673,144,210	0	322,445,714			35,440,908
41	UNEMPLOYMENT 2021	Unemployment Tax			12,424	0	83,251	78,957		16,718	0	39,949			43,302
42	STATE UNEMPLOYMENT 2021	Unemployment Tax	IL
43	STATE UNEMPLOYMENT 2021	Unemployment Tax	OH		24,859	0	284,000	286,407		22,452	0	142,298			141,702
44	STATE UNEMPLOYMENT 2021	Unemployment Tax	WV		0	0				0	0	8			8
45	Subtotal Unemployment Tax				37,283	0	367,251	365,364		39,170	0	182,255			184,996
46	Sales & Use Tax 2020	Sales And Use Tax	OH	2020	271,279	163,031	99,533	8,715		0	0	2			99,531
47	Sales & Use Tax 2021	Sales And Use Tax	OH	2021	0	0	1,634,440	1,316,795		417,645	100,000	867			1,635,307
48	Sales & Use Tax 2020	Sales And Use Tax	WV	2020	33,140	0	27,660	5,480		0	0				27,660
49	Sales & Use Tax 2021	Sales And Use Tax	WV	2021	0	0	31,369	25,779		5,590	0	10			31,359
50	Subtotal Sales And Use Tax				304,419	163,031	1,538,616	1,356,769		423,235	100,000	859			1,539,475
51	Excise Tax 2020	Excise Tax	OH	2020	12,157,146	0		12,157,146		0	0
52	Excise Tax 2021	Excise Tax	OH	2021	0	0	145,214,490	132,797,820		12,416,670	0	145,213,370			1,120
53	Excise Tax 2019	Excise Tax	OH	2019	18	0		18		0	0
54	Subtotal Excise Tax				12,157,164	0	145,214,490	144,954,984		12,416,670	0	145,213,370			1,120
55	Franchise Tax	Franchise Tax	KY	2017	1,376	0				1,376	0
56	Franchise Tax	Franchise Tax	KY	2018	3,030	0				3,030	0
57	Franchise Tax	Franchise Tax	KY	2019	2,302	0				2,302	0
58	Franchise Tax	Franchise Tax	UT	2017	100	0				100	0
59	Franchise Tax	Franchise Tax	KY	2020	2,302	0	561			1,741	0	561
60	Subtotal Franchise Tax				8,910	0	561			8,349	0	561
61	Other State Tax 2020	Other State Tax	OH	2020	1,805,400	0	157,895	1,647,505		0	0	157,895
62	Other State Tax 2021	Other State Tax	OH	2021	0	0	6,929,883	5,270,583		1,659,300	0	6,929,883
63	Other State Tax	Other State Tax			3,196,258		3,196,258			0	0				3,196,258
64	Subtotal Other State Tax				5,001,658	0	3,575,730	6,918,088		1,659,300	0	6,771,988			3,196,258
65	Other License and Fees Tax	Other License And Fees Tax	WV		26	0				26	0
66	Subtotal Other License And Fees Tax				26	0				26	0
67	FICA 2021	Payroll Tax			1,917,784	0	12,624,751	15,367,595	2,386,726	1,561,666	0	5,830,997			6,793,754
68	2360104 FICA	Payroll Tax			2,741,613	0			2,741,613	0	0
69	2360105 FICA CARES ACT	Payroll Tax			2,741,613	0			354,633	3,096,246	0
70	Subtotal Payroll Tax				7,401,010	0	12,624,751	15,367,595	254	4,657,912	0	5,830,997			6,793,754
71	Other Taxes & Fees 2021	Other Taxes and Fees	OH		0	0	5,277,878	5,277,878		0	0				5,277,878
72	Subtotal Other Taxes And Fees				0	0	5,277,878	5,277,878		0	0				5,277,878
40	TOTAL				625,681,376	163,031	533,371,657	461,014,591	254	697,975,157	100,000	488,452,519			44,919,138

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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			512	1 Year
6	State DITC		411.1		411.4
7	30				411.4
8	TOTAL Electric (Enter Total of lines 2 thru 7)	512						512
9	Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10										`
47	OTHER TOTAL
48	GRAND TOTAL	512						512

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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	20,952,741	142, 232	20,952,741	20,614,654	20,614,654
2	Deferred Rev - Pole Attachments	2,098,998	454, 172	8,773,374	8,847,273	2,172,897
3	Deferred Rev- Bonus Lease Curr	101,161	456	75,871		25,290
4	Deferred Rev- Bonus Lease NC	25,290	456	25,290
5	SFAS 106 - OPEB
6	Other Deferred Credits	3,467,084	142, 186, 143, 146, 232	3,490,440	2,114,851	2,091,495
7	Customer Choice Collateral Deposit	9,083,000	232, 561	10,410,471	7,333,000	6,005,529
8	Contr In Aid of Constr Advance	1,802,320	107, 108	1,802,320	5,443,337	5,443,337
9	Fiber Opt Lines Sold Deferred Rev- Amortization period - 1/2005 to 12/2024	259,023	451	119,857		139,166
10	ABD - Sharyland Deferred Revenue	527,351	142, 454, 186	527,351	543,171	543,171
11	Def Revenue GPDC2 Lease-Affil	490,845			283,028	773,873
12	QUAL OF SVC PENALTIES - LT	1,453,880	232, 234, 242, 426	1,041,210		412,670
47	TOTAL	40,261,693		47,218,925	45,179,314	38,222,082

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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	1,384,449,744	121,278,035	91,149,570					190		1,414,578,209
3	Gas
4	Other (Specify)
5	Total (Total of lines 2 thru 4)	1,384,449,744	121,278,035	91,149,570							1,414,578,209
6	Non Utility	455,539									455,539
7	SFAS 109/FIN 48	361,888,342					1823/254	33,255,927	1823/254	40,144,830	354,999,439
9	TOTAL Account 282 (Total of Lines 5 thru 8)	1,023,016,941	121,278,035	91,149,570				33,255,927		40,144,830	1,060,034,309
10	Classification of TOTAL
11	Federal Income Tax	1,023,016,941	121,278,035	91,149,570				33,255,927		40,144,830	1,060,034,309
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:

05/19/2022

Year/Period of Report

End of:

2021

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	32,231,766	56,439	1,431,583							30,856,622
4	CAPITALIZED SOFTWARE COST-BOOK	27,433,001	4,774,425	53,385							32,154,041
5	REG ASSET-UND/REC DIST RECOUP REV PROG	6,122,068	2,794,378	5,545,646							3,370,800
6	DEFD TAX GAIN - SEC I REG ASSET	5,090,980									5,090,980
7	REG ASSET-SFAS 158 - PENSIONS	31,415,667		6,711,260							24,704,407
8	Other	51,750,289	56,745,679	52,862,044	330,342	456,805					55,507,461
9	TOTAL Electric (Total of lines 3 thru 8)	154,043,771	64,370,921	66,603,918	330,342	456,805					151,684,311
10	Gas
11
12
13
14
15
16
17	TOTAL Gas (Total of lines 11 thru 16)
18	TOTAL Other	11,207,389				16,126	1823/254	4,975,992	1823/254	9,773,217	6,426,290
19	TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)	142,836,382	64,370,921	66,603,918	330,342	472,931		4,975,992		9,773,217	145,258,021
20	Classification of TOTAL
21	Federal Income Tax	91,527,162	55,507,242	63,742,017	330,342	472,931		3,676,422		7,207,425	86,680,801
22	State Income Tax	51,309,220	8,863,679	2,861,901				1,299,570		2,565,792	58,577,220
23	Local Income Tax
NOTES

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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	345,032	175	1,028,926	1,147,323	463,429
2	Unrealized Gain on Forward Commitments - Nettingof Trading Activities between Regulated Assets / Liabilities	345,032	182	1,147,323	1,028,926	463,429
3	Over-Recovery Alternative Energy Rider (AER) Costs - Ohio - Case No. 16-1852-EL-SSO - Case No. 16-1853-EL-AAM	6,047,620	182,557	22,217,995	16,170,375
4	Ohio Rate Stabilization Plan (RSP) - Low Income Customer / Economic Recovery- Docket No. 04-169-EL-UNC	304,207				304,207
5	DAPIR Over Recovery	272,010	182	272,010
6	Over Rcvrd Fuel Cost - LT - OH				15,220,828	15,220,828
7	PJM Transmission Enhancement Regulatory Liability	24,543,257	142	4,916,651		19,626,606
8	SFAS 109 Flow-Through Deferred Fed Inc Tax (FIT) Excess Deferred FIT - OCI	558,474,909	190/282/283	43,518,301	29,931,867	544,888,475
9	Over-Recovery Monongahela Power Litigation Termination - Case No. 05-765-EL-UNC	215,649				215,649
10	Over-Recovery Energy Efficiency / Peak Demand Reduction Rider (EE / PDR) - Case No. 16-1852-EL-SSO - Case No. 16-1853-EL-AAM	17,367,580	908	762,900	3,956,710	20,561,390
11	Deferred SIT		190/282/283	2,307,075		2,307,075
12	EE-PDR CHP Program Liability	2,535,000	908	563,945		1,971,055
13	Over Recovery OVEC PPA				14,807,910	14,807,910
14	Over-Recovery Enhanced Service Reliability Plan (ESRP) Costs - Ohio - Case No. 16-1852-EL-SSO, Case No. 16-1853-EL-AAM	5,701,783	182,593	6,078,581	376,798
15	Over-Recovery Fuel Costs - Ohio- Case No. 16-1852-EL-SSO- Case No. 16-1853-EL-AAM	344,704	182,254	689,407	344,703
16	Over-Recovery Fixed Costs Rider (FCR) - Ohio - Case No. 12-3254-EL-UNC	757,018	182,254	757,018
41	TOTAL	616,563,737		84,260,132	82,985,440	615,289,045

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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	1,586,465,519	1,552,633,296	14,546,502	14,354,676	1,314,084	1,306,551
3	CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales
4	CommercialSalesAbstract Small (or Comm.) (See Instr. 4)	724,889,271	683,478,311	15,036,325	13,932,433	185,446	182,934
5	IndustrialSalesAbstract Large (or Ind.) (See Instr. 4)	289,668,862	270,872,136	14,321,447	13,347,404	9,333	9,482
6	PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting	12,581,570	13,013,051	111,154	112,711	2,556	2,576
7	OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities	55,569	49,768	581	543	25	25
8	SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways
9	InterdepartmentalSalesAbstract (448) Interdepartmental Sales
10	SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers	(a) 2,613,660,791	2,520,046,562	44,016,009	41,747,767	1,511,444	1,501,568
11	SalesForResaleAbstract (447) Sales for Resale	108,891,211	67,076,416	2,521,794	2,409,628	3	4
12	SalesOfElectricityAbstract TOTAL Sales of Electricity	2,722,552,002	2,587,122,978	46,537,803	44,157,396	1,511,447	1,501,572
13	ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds
14	RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds	2,722,552,002	2,587,122,978	46,537,803	44,157,396	1,511,447	1,501,572
15	OtherOperatingRevenuesAbstract Other Operating Revenues
16	ForfeitedDiscounts (450) Forfeited Discounts	2,104,608	1,501,083
17	MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues	(b) 8,927,879	5,810,460
18	SalesOfWaterAndWaterPower (453) Sales of Water and Water Power
19	RentFromElectricProperty (454) Rent from Electric Property	49,621,575	47,017,785
20	InterdepartmentalRents (455) Interdepartmental Rents
21	OtherElectricRevenue (456) Other Electric Revenues	(c) 43,183,430	24,438,714
22	RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others	75,997,493	84,095,687
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	179,834,983	162,863,730
27	ElectricOperatingRevenues TOTAL Electric Operating Revenues	2,902,386,985	2,749,986,708
Line12, column (b) includes $ 11,297,517 of unbilled revenues.
Line12, column (d) includes 167,080 MWH relating to unbilled revenues

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

FOOTNOTE DATA

(a) Concept: SalesToUltimateConsumers


Details of Unmetered Sales
	Revenue	MWH	Average Customer
Residential	4,185,716.00	17,778.00	27,165.00
Commercial	9,484,000.00	46,916.00	16,249.00
Industrial	683,735.00	4,548.00	822.00
Public Street Lighting	12,451.00	64.00	22.00
Total	14,365,902.00	69,306.00	44,258.00

Total Sales to Ultimate Consumers include $1,270,426,580 of operating revenues for distribution service provided to Open Access Customers. Megawatt hours delivered to Open Access Customers were 33,397,419 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 2021	YTD 2020
Associated Business Development Revenues	(4,936,579.52)	(3,735,385.00)
Oth Elect Rev - Nonaffiliated	(767,563.00)	(535,780.00)
Oth Elect Rev - Affiliated	—	(26,401.00)
All Other (under $250,000 each)	(101,329.89)	(101,161.00)
Oth Elect Rev - DSM Program	(86,985.00)	(190,354.00)
LGR Rider Revenue	(37,290,972.64)	(19,849,633.00)
Amort of Defer Equity Inc	0.00	—
	(43,183,430.00)	(24,438,714.00)

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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	13	1,507			0.1159
2	OAD-AL Area Lighting	4,516	881,628			0.1952
3	OAD-GS-1		5
4	OAD-RR Residential Regular	32,843	2,378,217	1,849	17,763	0.0724
5	OAD-RR-1 Residential Low Usage	3,031,672	243,937,356	284,391	10,660	0.0805
6	OAD-RS Residential Service	3,000,929	237,862,305	268,846	11,162	0.0793
7	OAD-RSDM	86	8,957	11	7,818	0.1042
8	OL Outdoor Lighting	17,778	4,185,716			0.2354
9	RLM Res Opt Demand Rate	2,514	300,047	52	48,346	0.1194
10	RR Residential Regular	3,763,283	480,852,680	306,244	12,289	0.1278
11	RR-1 Residential Low Usage	435,208	65,523,394	89,612	4,857	0.1506
12	RS Residential Service	4,330,101	558,025,553	362,540	11,944	0.1289
13	RS-CPP Res Exp Critical Peak Pric	463	59,240	38	12,184	0.1279
14	RS-ES Res Energy Storage	3,118	389,253	193	16,155	0.1248
15	RS-TOD Gen Svc-Time of Day	790	96,501	59	13,390	0.1222
16	RS-TOD2 Res Exper-Time of Day	2,257	311,309	245	9,212	0.1379
17	RS-TOU	21	3,267	4	5,250	0.1556
18	Ohio Riders		441,431
19	Misc Adjustment		58,364
41	TOTAL Billed Residential Sales	14,625,592	1,594,317,140	1,314,084	11,130	0.1090
42	TOTAL Unbilled Rev. (See Instr. 6)	79,090	7,851,621			0.0993
43	TOTAL	14,546,502	1,586,465,519	1,314,084	11,130	0.1091

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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	2,689	358,847	107	25,131	0.1334
2	Net Estimated Billings	74,391	941,025			0.0126
3	GS	475,353	54,062,650	8,617	55,165	0.1137
4	GS-1 Gen Svc Fixed	313,888	49,273,080	59,896	5,241	0.1570
5	GS-2 Gen Svc Low	482,010	50,811,263	7,484	64,405	0.1054
6	GS-TOD2 Gen Exper Low-Time of	732	90,037	27	27,111	0.1230
7	GS-3 Gen Svc Medium	472,931	40,842,268	1,221	387,331	0.0864
8	GS-4 Gen Svc Large	7,458	846,290	2	3,729,000	0.1135
9	GS-TOD Gen Svc-Time of Day	14,391	1,525,507	366	39,320	0.1060
10	OAD-AL Area Lighting	33,605	4,929,533			0.1467
11	OAD-EHG Electric Heating General	8,991	658,626	220	40,868	0.0733
12	OAD-EHS	394	12,951	1	394,000	0.0329
13	OAD-GS	4,008,328	114,232,898	15,793	253,804	0.0285
14	OAD-GS-1 Gen Svc Fixed	434,611	40,917,641	64,366	6,752	0.0941
15	OAD-GS-2 Gen Svc Low	2,225,539	125,410,626	19,206	115,877	0.0564
16	OAD-GS-3 Gen Svc Medium	6,415,302	228,067,529	8,024	799,514	0.0356
17	OAD-GS-4 Gen Svc Large	51,328	568,202	1	51,328,000	0.0111
18	OAD-RS	4	378			0.0945
19	OAD-SL	1,021	24,873	1	1,021,000	0.0244
20	OAD-SS School Service	24,903	1,237,456	103	241,777	0.0497
21	OL Outdoor Lighting	46,916	9,484,000			0.2021
22	RS Residential Service	12	1,553	1	12,000	0.1294
23	SL Street Lighting	17	1,569	2	8,500	0.0923
24	SS School Service	691	71,400	8	86,375	0.1033
25	Ohio Riders		2,955,255
26	Misc Adjustment		21,166
41	TOTAL Billed Small or Commercial	15,095,505	727,304,291	185,446	81,401	0.0482
42	TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)	59,180	2,415,020			0.0408
43	TOTAL Small or Commercial	15,036,325	724,889,271	185,446	81,401	0.0482

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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	98	10,434	2	49,000	0.1065
2	Net Estimated Billings	278,378	7,038,961	1	278,378,000	0.0253
3	GS	2,881,943	8,636,486	521	5,531,560	0.0030
4	GS-1 Gen Svc Fixed	8,996	1,713,783	2,508	3,587	0.1905
5	GS-2 Gen Svc Low	136,006	5,952,935	246	552,870	0.0438
6	GS-3 Gen Svc Medium	177,173	9,323,407	118	1,501,466	0.0526
7	GS-4 Gen Svc Large	218	92,622	1	218,000	0.4249
8	GS-TOD Gen Svc-Time of Day	623	68,532	11	56,636	0.1100
9	OAD-AL Area Lighting	3,290	380,607			0.1157
10	OAD-EHG Electric Heating General	532	44,250	10	53,200	0.0832
11	OAD-GS	2,034,389	53,170,721	962	2,114,749	0.0261
12	OAD-GS-1 Gen Svc Fixed	11,606	1,344,945	2,371	4,895	0.1159
13	OAD-GS-2 Gen Svc Low	759,473	38,366,520	1,684	450,993	0.0505
14	OAD-GS-3 Gen Svc Medium	4,116,799	118,957,333	868	4,742,856	0.0289
15	OAD-GS-4 Gen Svc Large	3,935,731	39,515,436	30	131,191,033	0.0100
16	OL Outdoor Lighting	4,548	683,735			0.1503
17	Ohio Riders		3,392,702
18	Misc Adjustment		1,965,061
41	TOTAL Billed Large (or Ind.) Sales	14,349,803	290,658,470	9,333	1,537,534	0.0203
42	TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)	28,356	989,608			0.0349
43	TOTAL Large (or Ind.)	14,321,447	289,668,862	9,333	1,537,534	0.0202

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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	65	7,326	2	32,500	0.1127
2	GS-1 Gen Svc Fixed	1,188	170,691	173	6,867	0.1437
3	OAD-AL Area Lighting	149	20,700			0.1389
4	OAD-GS	1,608	73,272	12	134,000	0.0456
5	OAD-GS-1 Gen Svc Fixed	10,031	901,662	1,140	8,799	0.0899
6	OAD-GS-2 Gen Svc Low	1,766	94,055	24	73,583	0.0533
7	OAD-GS-3 Gen Svc Medium	1,249	49,108	3	416,333	0.0393
8	OAD-SL Street Lighting	80,790	8,655,822	748	108,008	0.1071
9	OL Outdoor Lighting	64	12,451			0.1945
10	SL Street Lighting	14,699	2,609,767	454	32,377	0.1775
11	Ohio Riders		28,148
12	Misc Adjustment		71
41	TOTAL Billed Public Street and Highway Lighting	111,609	12,622,931	2,556	43,665	0.1131
42	TOTAL Unbilled Rev. (See Instr. 6)	455	41,361			0.0909
43	TOTAL	111,154	12,581,570	2,556	43,665	0.1132

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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	407	44,201	15	27,133	0.1086
2	SPECIAL - Street Lighting	173	11,109	10	17,300	0.0642
3	Ohio Riders		171
4	Misc Adjustment		5
41	TOTAL Billed Other Sales to Public Authorities	580	55,476	25	23,200	0.0956
42	TOTAL Unbilled Rev. (See Instr. 6)	1	93			0.0930
43	TOTAL	581	55,569	25	23,200	0.0956

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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	44,183,089	2,624,958,308	1,511,444	29,232	0.0594
42	TOTAL Unbilled Rev. (See Instr. 6) - All Accounts	167,080	11,297,517			0.0676
43	TOTAL - All Accounts	44,016,009	2,613,660,791	1,511,444	29,232	0.0594

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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		49		49
2	(a) OHIO ECONOMIC DEVELOPMENT RIDER	OS	(b) NOTE 1				0			1,697	1,697
3	PJM INTERCONNECTION	OS	NOTE 1				2,513,454	3,759,271	104,459,915	1	108,219,185
4	OHIO EDISON - 217	RQ	OPCO-99				1,552	47,699	75,937		123,636
5	OHIO EDISON - 244	RQ	OPCO-99				6,788	224,201	322,541		546,742
15	Subtotal - RQ						8,340	271,900	398,429		670,329
16	Subtotal-Non-RQ						2,513,454	3,759,271	104,459,915	1,696	108,220,882
17	Total						2,521,794	4,031,171	104,858,344	1,696	108,891,211

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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	23
67	OtherPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 62 thru 67)	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)	23
75	OtherPowerSuplyExpensesAbstract E. Other Power Supply Expenses
76	PurchasedPower (555) Purchased Power	697,709,821	639,856,830
76.1	PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations	0
77	SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching
78	OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses	40,290,714	34,247,116
79	OtherPowerSupplyExpense TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)	738,000,535	674,103,946
80	PowerProductionExpenses TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)	738,000,558	674,103,946
81	TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES
82	TransmissionExpensesOperationAbstract Operation
83	OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering	11,004,767	9,701,585
85	LoadDispatchReliability (561.1) Load Dispatch-Reliability
86	LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System	350,630	362,340
87	LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling
88	SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services	109,603	240,437
89	ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development	498,427	328,782
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	1,367,156	1,259,451
93.1	OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment
94	OverheadLineExpense (563) Overhead Lines Expenses	75,697	329,841
95	UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses	125	218
96	TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others	532,406,631	436,095,187
97	MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses	12,824,524	43,056,218
98	RentsTransmissionElectricExpense (567) Rents	190,109	229,651
99	TransmissionOperationExpense TOTAL Operation (Enter Total of Lines 83 thru 98)	558,827,669	405,491,274
100	TransmissionMaintenanceAbstract Maintenance
101	MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering	65,921	60,974
102	MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures	54,523	13,961
103	MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware	(a) 25,207	20,377
104	MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software	423,077	519,384
105	MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment	148,379	127,552
106	MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant
107	MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment	5,858,529	6,361,037
107.1	MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment
108	MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines	19,442,375	19,766,914
109	MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines	197,501	190,909
110	MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant	99,413	128,449
111	TransmissionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 101 thru 110)	26,314,925	27,189,557
112	TransmissionExpenses TOTAL Transmission Expenses (Total of Lines 99 and 111)	585,142,594	432,680,831
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	2,378	2,080
122	RentsRegionalMarketExpenses (575.8) Rents
123	RegionalMarketOperationExpense Total Operation (Lines 115 thru 122)	2,378	2,080
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)	2,378	2,080
132	DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES
133	DistributionExpensesOperationAbstract Operation
134	OperationSupervisionAndEngineeringDistributionExpense (580) Operation Supervision and Engineering	9,050,350	6,967,921
135	LoadDispatching (581) Load Dispatching	12	4,368
136	StationExpensesDistribution (582) Station Expenses	3,096,339	2,977,678
137	OverheadLineExpenses (583) Overhead Line Expenses	3,611,180	3,722,623
138	UndergroundLineExpenses (584) Underground Line Expenses	9,229,481	9,006,425
138.1	OperationOfEnergyStorageEquipmentDistribution (584.1) Operation of Energy Storage Equipment
139	StreetLightingAndSignalSystemExpenses (585) Street Lighting and Signal System Expenses	235,014	291,276
140	MeterExpenses (586) Meter Expenses	4,235,740	3,804,247
141	CustomerInstallationsExpenses (587) Customer Installations Expenses	103,421	283,471
142	MiscellaneousDistributionExpenses (588) Miscellaneous Expenses	35,031,349	53,674,211
143	RentsDistributionExpense (589) Rents	6,793,933	6,818,368
144	DistributionOperationExpensesElectric TOTAL Operation (Enter Total of Lines 134 thru 143)	71,179,977	86,983,646
145	DistributionExpensesMaintenanceAbstract Maintenance
146	MaintenanceSupervisionAndEngineering (590) Maintenance Supervision and Engineering	255,920	297,096
147	MaintenanceOfStructuresDistributionExpense (591) Maintenance of Structures	49,364	25,214
148	MaintenanceOfStationEquipment (592) Maintenance of Station Equipment	5,027,807	5,304,361
148.1	MaintenanceOfEnergyStorageEquipment (592.2) Maintenance of Energy Storage Equipment
149	MaintenanceOfOverheadLines (593) Maintenance of Overhead Lines	95,807,118	66,073,978
150	MaintenanceOfUndergroundLines (594) Maintenance of Underground Lines	8,131,446	6,199,222
151	MaintenanceOfLineTransformers (595) Maintenance of Line Transformers	1,923,940	2,303,004
152	MaintenanceOfStreetLightingAndSignalSystems (596) Maintenance of Street Lighting and Signal Systems	601,015	668,761
153	MaintenanceOfMeters (597) Maintenance of Meters	648,095	706,511
154	MaintenanceOfMiscellaneousDistributionPlant (598) Maintenance of Miscellaneous Distribution Plant	4,224,301	4,195,561
155	DistributionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 146 thru 154)	116,669,006	85,773,708
156	DistributionExpenses TOTAL Distribution Expenses (Total of Lines 144 and 155)	187,848,983	172,757,354
157	CustomerAccountsExpensesAbstract 5. CUSTOMER ACCOUNTS EXPENSES
158	CustomerAccountsExpensesOperationsAbstract Operation
159	SupervisionCustomerAccountExpenses (901) Supervision	1,464,289	1,432,205
160	MeterReadingExpenses (902) Meter Reading Expenses	2,867,976	3,274,817
161	CustomerRecordsAndCollectionExpenses (903) Customer Records and Collection Expenses	37,201,919	35,962,208
162	UncollectibleAccounts (904) Uncollectible Accounts	60,887,781	117,687,180
163	MiscellaneousCustomerAccountsExpenses (905) Miscellaneous Customer Accounts Expenses	225,126	259,007
164	CustomerAccountExpenses TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)	102,647,090	158,615,417
165	CustomerServiceAndInformationalExpensesAbstract 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166	CustomerServiceAndInformationalExpensesOperationAbstract Operation
167	SupervisionCustomerServiceAndInformationExpenses (907) Supervision	2,989,542	5,923,181
168	CustomerAssistanceExpenses (908) Customer Assistance Expenses	11,041,804	58,331,124
169	InformationalAndInstructionalAdvertisingExpenses (909) Informational and Instructional Expenses
170	MiscellaneousCustomerServiceAndInformationalExpenses (910) Miscellaneous Customer Service and Informational Expenses	166,546	116,931
171	CustomerServiceAndInformationExpenses TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)	14,197,893	64,371,236
172	SalesExpenseAbstract 7. SALES EXPENSES
173	SalesExpenseOperationAbstract Operation
174	SupervisionSalesExpense (911) Supervision	13,484	1,921,483
175	DemonstratingAndSellingExpenses (912) Demonstrating and Selling Expenses	262,626	373,039
176	AdvertisingExpenses (913) Advertising Expenses
177	MiscellaneousSalesExpenses (916) Miscellaneous Sales Expenses
178	SalesExpenses TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)	276,110	2,294,522
179	AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
180	AdministrativeAndGeneralExpensesOperationAbstract Operation
181	AdministrativeAndGeneralSalaries (920) Administrative and General Salaries	38,571,139	38,834,628
182	OfficeSuppliesAndExpenses (921) Office Supplies and Expenses	3,904,455	3,494,798
183	AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit	8,065,432	9,043,722
184	OutsideServicesEmployed (923) Outside Services Employed	7,931,184	5,834,205
185	PropertyInsurance (924) Property Insurance	2,538,539	2,422,229
186	InjuriesAndDamages (925) Injuries and Damages	5,596,546	5,865,536
187	EmployeePensionsAndBenefits (926) Employee Pensions and Benefits	3,559,093	4,804,298
188	FranchiseRequirements (927) Franchise Requirements
189	RegulatoryCommissionExpenses (928) Regulatory Commission Expenses	7,158,756	1,942,710
190	DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr.
191	GeneralAdvertisingExpenses (930.1) General Advertising Expenses	577,555	1,439,170
192	MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses	3,034,742	3,359,174
193	RentsAdministrativeAndGeneralExpense (931) Rents	1,859,189	1,818,664
194	AdministrativeAndGeneralOperationExpense TOTAL Operation (Enter Total of Lines 181 thru 193)	66,665,766	60,771,690
195	AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance
196	MaintenanceOfGeneralPlant (935) Maintenance of General Plant	15,183,811	14,101,566
197	AdministrativeAndGeneralExpenses TOTAL Administrative & General Expenses (Total of Lines 194 and 196)	81,849,577	74,873,256
198	OperationsAndMaintenanceExpensesElectric TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)	1,709,965,184	1,579,698,642

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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					601,780					26,619,458		26,619,458
2	(b) AEPSC AS AGENT FOR AEP OPCO'S	OS					73					2,064		2,064
3	AXPO U.S. LLC	OS					54,534					2,530,168		2,530,168
4	B.P. ENERGY COMPANY	OS					2,549,789					109,376,030		109,376,030
5	(c) BLUESTAR ENERGY SERVICES, INC.	OS					684,957					25,321,972		25,321,972
6	CONOCO INC.	OS					85,137					3,126,110		3,126,110
7	CONSTELLATION NEWENERGY, INC.	OS					793,003					36,825,090		36,825,090
8	DTE ENERGY TRADING INC.	OS					182,449					7,291,715		7,291,715
9	DXT COMMODITIES N AMERICA LLC	OS					54,534					2,530,168		2,530,168
10	DYNEGY MARKETING & TRADE	OS					1,298,078					57,238,071		57,238,071
11	ENEL TRADING NORTH AMERICA LLC	OS					400,371					17,877,461		17,877,461
12	ENERGY HARBOR, LLC	OS					1,636,007					76,219,138		76,219,138
13	EXELON GENERATION - POWER TEAM	OS					1,459,357					60,036,186		60,036,186
14	FIRSTENERGY TRADING SERVICES	OS					255,913					11,983,989		11,983,989
15	FOWLER RIDGE II WIND FARM LLC	OS					203,373					5,856,398		5,856,398
16	HARTREE PARTNERS, LP	OS					291,411					13,532,003		13,532,003
17	NEXTERA ENERGY POWER MKTG LLC	OS					298,138					11,970,515		11,970,515
18	NORTHERN STATES POWER COMPANY	OS					85,490					3,967,470		3,967,470
19	(d) OHIO AUCTION COST RECONCILIATION RIDER	OS					0					4,708,451		4,708,451
20	(e) OVEC POWER SCHEDULING	OS					2,005,691				77,623,202	97,621,873		175,245,074
21	PAULDING WIND FARM II, LLC	OS					302,768					7,881,256		7,881,256
22	PJM INTERCONNECTION	OS					32,707					17,212,829		17,212,829
23	R L DOWNS	OS					0					1,219		1,219
24	TRANSALTA ENERGY MARKETING US	OS					248,703					11,008,824		11,008,824
25	VITOL INC.	OS					213,111					8,717,815		8,717,815
26	WYANDOT SOLAR LLC	OS					13,171					630,348		630,348
15	TOTAL						13,750,545	0	0	0	77,623,202	620,086,620	0	697,709,821

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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

10,716,786

PJM Network Integ Trans Serv

Various

FNO

PJM OATT

Various

46,493,665

PJM Trans Enhancement Rev

Various

FNO

PJM OATT

Various

8,416,594

PJM Trans Enhancement Rev Whlsle

Various

FNO

PJM OATT

Various

258,687

PJM Network Integ Rev - Affil

Various

FNO

PJM OATT

Various

995,981

PJM Point to Point Trans Service

Various

LFP

PJM OATT

Various

9,088,772

PJM Trans Owner Admin Revenue

Various

OLF

PJM OATT

Various

37,746

PJM Trans Owner Serv Rev Whlsle

Various

OLF

PJM OATT

Various

166,528

PJM Trans Distribution & Metering

Various

PJM OATT

Various

(b)

1,345,553

PJM Power Factor Credit Rev Nonaff

Various

PJM OATT

Various

(c)

877,691

TOTAL

73,978,523

204,274

2,223,244

75,997,493

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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) 2,729,101	2,729,101
2	PJM-Enhancements	OS					(b) 59,912,068	59,912,068
3	PJM-NITS	OS					(c) 464,567,611	464,567,611
4	PJM-Trans Owner Serv	OS					(d) 5,197,851	5,197,851
	TOTAL		0	0	0	0	532,406,631	532,406,631

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:

05/19/2022

Year/Period of Report

End of:

2021

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	2,342
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)	294,828
7	Associated Business Development	2,003,207
8	Utility Corp Borrowing Program Shared Costs	38,969
9	Corporate Contributions & Memberships	614,075
10	PJM Capacity Market Non-Performance Insurance	57
11	Ohio Broadband Initiative	19,004
12	Energy Efficiency/Peak Demand Reduction Program
13	Miscellaneous	62,261
46	MiscellaneousGeneralExpenses TOTAL	3,034,742

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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			43,438,904		43,438,904
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	65,699,730				65,699,730
8	Distribution Plant	179,242,741				179,242,741
9	Regional Transmission and Market Operation
10	General Plant	13,164,237		423,073		13,587,310
11	Common Plant-Electric
12	TOTAL	258,106,708		43,861,977		301,968,685

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	114,694	55 years	5	2.02	R3
14	352.15	323	55 years	5	2.02	R3
15	353	1,479,633	43 years	30	2.29	R1
16	353.15	12,459	43 years	30	2.29	R1
17	353.16	22,520	43 years	30	2.29	R1
18	354	3,702	60 years		1.88	R4
19	354.15	21,597	60 years		1.88	R4
20	354 - All Other	170,109	60 years		1.88	R4
21	355	209,214	39 years	4	3.52	R1
22	355.15	1,901	39 years	4	3.52	R1
23	355 - All Other	258,094	39 years	4	3.52	R1
24	356	149,121	44 years	4	1.91	R4
25	356.15	17,475	44 years	4	1.91	R4
26	356.16	139	44 years	4	1.91	R4
27	356 - All Other	329,140	44 years	4	1.91	R4
28	357	465	50 years	1	2.26	R2
29	357 - All Other	15,271	50 years	1	2.26	R2
30	358	1,198	50 years	16	3.27	R2
31	358 - All Other	33,424	50 years	16	3.27	R2
32	358.16	29	50 years	16	3.27	R2
33	TOTAL TRANSMISSION	2,840,508
34	DISTRIBUTION
35	361	55,724	70 years	22	1.74	R2
36	362	1,008,190	55 years	13	2.05	L0
37	362.16	20,214	55 years	13	2.05	L0
38	363	5,117	15 years		6.67	SQ
39	364	893,752	38 years	87	4.92	R0.5
40	365	1,095,098	32 years	18	3.69	L0
41	366	426,830	60 years		1.67	R3
42	367	794,981	50 years	13	2.26	R1.5
43	368	911,966	32 years	16	3.63	L0
44	369	365,348	43 years	34	3.12	R0.5
45	370	91,119	11 years	8	9.82	L1.5
46	370.16	180,379	15 years	8	7.2	S0.5
47	371	59,795	15 years	28	8.53	L0
48	371 - AMI	95	15 years	28	8.53	L0
49	372	103	44 years		2.27	R0.5

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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	235,745		235,745		Electric	928	235,745
2	and review process for long-term forecasts.
3	2018 AEP Ohio Solar Filing		186	186		Electric	928	186
4	AEP Ohio Electric Security Plan III		33,671	33,671		Electric	928	33,671
5	Ohio Distribution Investment Rider		70,029	70,029		Electric	928	70,029
6	Ohio SEET Filings		16,167	16,167		Electric	928	16,167
7	FERC Formula Rate Filing		23,409	23,409		Electric	928	23,409
8	Alternative Energy Rider
9	AEP Ohio Purchased Fuel Adjustment Audit		13,290	13,290		Electric	928	13,290
10	Miscellaneous Items - < $25K		506,801	506,801		Electric	928	506,801
11	AEP Ohio 2020 Base Rate Case		858,423	858,423	73,803	Electric	928	858,423				73,803
12	AEP Ohio Grid Smart Rider		101,293	101,293		Electric	928	101,293
13	2021 Quadrennial SEET Filing		21,864	21,864		Electric	928	21,864
14	State Commission Fees		5,277,878	5,277,878		Electric	928	5,277,878
46	TOTAL	235,745	6,923,011	7,158,756	73,803			7,158,756				73,803

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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	17,048		566	17,048
4	A.(3) Distribution	1 items under $50,000	14,663		588	14,663
5	A.(6)Other	1 items under $50,000	31		566,588	31
6		Corporate Technology Prog Mgmt	83,260		566,588	83,260
7	(f) AMI Test Bed Development	1 item under $50,000	2,863		588	2,863
8	(g) DTC Walnut Maintenance	1 item under $50,000	2,844		566,588	2,844
9	A (7) TOTAL COSTS INCURRED INTERNALLY		120,710			120,710
10	ELECTRIC UTILITY RESEARCH, DEVELOPMENT &
11	DEMONSTRATION PERFORMED EXTERNALLY
12	B. Memberships	6 Items under $50,000		122,426	566,588	122,426
13	B.(1) Electric Power Research Institute	EPRI Research Portfolio		625,483	566,588	625,483
14		Electric Transportation		193,544	588	193,544
15		IT - EPRI Annual Research Port		75,810	566,588	75,810
16		Low Carbon Resource Initiative		127,473	566,588	127,473
17		T Line Robots - Reclass		288,388	566,588	288,388
18		6 items under $50,000		2,265	566,588	2,265
19	B. (4) Substation Equipment Management	1 items under $50,000		4	566	4
20	B(5) TOTAL COSTS INCURRED EXTERNALLY			1,435,393		1,435,393

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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	10,512
4	SalariesAndWagesElectricOperationTransmission Transmission	112,029
5	SalariesAndWagesElectricOperationRegionalMarket Regional Market
6	SalariesAndWagesElectricOperationDistribution Distribution	20,701,193
7	SalariesAndWagesElectricOperationCustomerAccounts Customer Accounts	8,420,762
8	SalariesAndWagesElectricOperationCustomerServiceAndInformational Customer Service and Informational	5,137,865
9	SalariesAndWagesElectricOperationSales Sales	23,581
10	SalariesAndWagesElectricOperationAdministrativeAndGeneral Administrative and General	161,076
11	SalariesAndWagesElectricOperation TOTAL Operation (Enter Total of lines 3 thru 10)	34,567,018
12	SalariesAndWagesElectricMaintenanceAbstract Maintenance
13	SalariesAndWagesElectricMaintenanceProduction Production
14	SalariesAndWagesElectricMaintenanceTransmission Transmission	38,700
15	SalariesAndWagesElectricMaintenanceRegionalMarket Regional Market
16	SalariesAndWagesElectricMaintenanceDistribution Distribution	32,301,425
17	SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral Administrative and General	4,947,389
18	SalariesAndWagesElectricMaintenance TOTAL Maintenance (Total of lines 13 thru 17)	37,287,514
19	SalariesAndWagesElectricOperationAndMaintenanceAbstract Total Operation and Maintenance
20	SalariesAndWagesElectricProduction Production (Enter Total of lines 3 and 13)	10,512
21	SalariesAndWagesElectricTransmission Transmission (Enter Total of lines 4 and 14)	150,729
22	SalariesAndWagesElectricRegionalMarket Regional Market (Enter Total of Lines 5 and 15)
23	SalariesAndWagesElectricDistribution Distribution (Enter Total of lines 6 and 16)	53,002,618
24	SalariesAndWagesElectricCustomerAccounts Customer Accounts (Transcribe from line 7)	8,420,762
25	SalariesAndWagesElectricCustomerServiceAndInformational Customer Service and Informational (Transcribe from line 8)	5,137,865
26	SalariesAndWagesElectricSales Sales (Transcribe from line 9)	23,581
27	SalariesAndWagesElectricAdministrativeAndGeneral Administrative and General (Enter Total of lines 10 and 17)	5,108,465
28	SalariesAndWagesElectricOperationAndMaintenance TOTAL Oper. and Maint. (Total of lines 20 thru 27)	71,854,532	5,194,075	77,048,607
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)	71,854,532	5,194,075	77,048,607
66	SalariesAndWagesUtilityPlantAbstract Utility Plant
67	SalariesAndWagesUtilityPlantConstructionAbstract Construction (By Utility Departments)
68	SalariesAndWagesUtilityPlantConstructionElectricPlant Electric Plant	76,034,666	5,496,239	81,530,905
69	SalariesAndWagesUtilityPlantConstructionGasPlant Gas Plant
70	SalariesAndWagesUtilityPlantConstructionOther Other (provide details in footnote):
71	SalariesAndWagesUtilityPlantConstruction TOTAL Construction (Total of lines 68 thru 70)	76,034,666	5,496,239	81,530,905
72	SalariesAndWagesPlantRemovalAbstract Plant Removal (By Utility Departments)
73	SalariesAndWagesPlantRemovalElectricPlant Electric Plant	12,837,312	927,957	13,765,269
74	SalariesAndWagesPlantRemovalGasPlant Gas Plant
75	SalariesAndWagesPlantRemovalOther Other (provide details in footnote):
76	SalariesAndWagesPlantRemoval TOTAL Plant Removal (Total of lines 73 thru 75)	12,837,312	927,957	13,765,269
77	SalariesAndWagesOtherAccountsAbstract Other Accounts (Specify, provide details in footnote):
78	SalariesAndWagesOtherAccountsDescription Other Accounts (Specify, provide details in footnote):
79	SalariesAndWagesOtherAccountsDescription 163 - Stores Expense Undistributed	6,345,073	6,345,073
80	SalariesAndWagesOtherAccountsDescription 184 - Clearing Accounts	5,273,198	5,273,198
81	SalariesAndWagesOtherAccountsDescription 185 - ODD Temporary Facilities	389,327		389,327
82	SalariesAndWagesOtherAccountsDescription 186 - Misc Deferred Debits	3,309,883		3,309,883
83	SalariesAndWagesOtherAccountsDescription 188 - Research & Development	2,257		2,257
84	SalariesAndWagesOtherAccountsDescription 421 - Misc Nonoperating Income
85	SalariesAndWagesOtherAccountsDescription 426 - Political Activities	137		137
86	SalariesAndWagesOtherAccountsDescription
87	SalariesAndWagesOtherAccountsDescription
88	SalariesAndWagesOtherAccountsDescription
89	SalariesAndWagesOtherAccountsDescription
90	SalariesAndWagesOtherAccountsDescription
91	SalariesAndWagesOtherAccountsDescription
92	SalariesAndWagesOtherAccountsDescription
93	SalariesAndWagesOtherAccountsDescription
94	SalariesAndWagesOtherAccountsDescription
95	SalariesAndWagesOtherAccounts TOTAL Other Accounts	15,315,361	11,618,271	3,697,090
96	SalariesAndWagesGeneralExpense TOTAL SALARIES AND WAGES	176,041,871		176,041,871

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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)				5,317
2.1	Net Purchases (Account 555.1)
3	Net Sales (Account 447)				108,218,595
4	Transmission Rights
5	Ancillary Services				17,814,768
6	Other Items (list separately)
7	Transmission Purchase Expense				1
8	Meter Corrections				626,156
9	Transmission Losses
10	Operating Reserves				29,533
46	TOTAL				91,005,766

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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:

2022-05-19

Year/Period of Report

End of:

2021

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)	44,016,009
3	Steam		23	Requirements Sales for Resale (See instruction 4, page 311.)	8,340
4	Nuclear		24	Non-Requirements Sales for Resale (See instruction 4, page 311.)	2,513,454
5	Hydro-Conventional		25	Energy Furnished Without Charge	(a) 33,397,420
6	Hydro-Pumped Storage		26	Energy Used by the Company (Electric Dept Only, Excluding Station Use)
7	Other		27	Total Energy Losses	610,162
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	13,750,545
10	Purchases (other than for Energy Storage)	13,750,545
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)	13,750,545

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

2022-05-19

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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	1,464,397	274,416	2,548	17	19
30	February	1,498,935	268,314	2,524	10	19
31	March	1,315,453	253,026	2,099	4	20
32	April	1,013,533	212,933	1,976	2	9
33	May	977,350	163,909	2,712	25	18
34	June	1,071,130	209,233	2,468	20	19
35	July	1,145,245	253,111	2,375	25	19
36	August	1,249,605	248,578	2,597	22	18
37	September	1,039,461	249,862	2,233	19	20
38	October	817,823	140,294	1,942	14	18
39	November	888,518	134,850	1,815	23	21
40	December	1,269,095	198,779	2,328	23	9
41	Total	13,750,545	2,607,305

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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:

05/19/2022

Year/Period of Report

End of:

2021

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	0010 FOSTORIA	PEMBERVILLE	138.00	138.00	3	18.49	0.00	2	336.4 ACS
65	0010 FOSTORIA	PEMBERVILLE	138.00	138.00	3	0.06	0.00	1	477 ACSR
66	0010 FOSTORIA	PEMBERVILLE	138.00	138.00	1	0.00	0.00	1	556.5 ACS
67	0011 PHILO	RUTLAND	138.00	138.00	3	65.70	0.00	2	397.5 ACS
68	0016 SOUTH POINT	TURNER	138.00	138.00	3	0.48	0.00	2	397.5 ACS
69	0018 PHILO	TORREY	138.00	138.00	3	69.32	0.00	1	1033.5 AC
70	0018 PHILO	TORREY	138.00	138.00	1	0.04	0.00	1	397.5 KCM
71	0018 PHILO	TORREY	138.00	138.00	1	1.37	0.00	1	397.5 KCM
72	0019 CROOKSVILLE	WEST LANCASTER	138.00	138.00	3	30.57	0.00	2	397.5 ACS
73	0019 CROOKSVILLE	WEST LANCASTER	138.00	138.00	1	0.13	0.00	2	397.5 ACS
74	0020 PHILO	CANTON	138.00	138.00	3	73.10	0.00	1	1033.5 AC
75	0020 PHILO	CANTON	138.00	138.00	1	0.95	0.00	1	336.4 KCM
76	0025 TIDD	WAGENHALS	138.00	138.00	1	0.02	0.00	1	1033.5 KCM
77	0025 TIDD	WAGENHALS	138.00	138.00	3	52.82	0.00	1	1033.5 AC
78	0025 TIDD	WAGENHALS	138.00	138.00	1	0.62	0.00	1	556.5 KCM
79	0028 PORTSMOUTH	TRENTON NO. 2	138.00	138.00	1	50.02	0.00	1	477 ACSR
80	0028 PORTSMOUTH	TRENTON NO. 2	138.00	138.00	3	0.24	0.00	1	477 ACSR
81	0028 PORTSMOUTH	TRENTON NO. 2	138.00	138.00	3	0.45	0.00	2	6X477 ACS
82	0028 PORTSMOUTH	TRENTON NO. 2	138.00	138.00	1	0.38	0.00	2	6X477 KCM
83	0032 TRENTON	MUNCIE	138.00	138.00	3	24.62	0.00	1	397.5 ACS
84	0033 RUTLAND	SPORN	138.00	138.00	3	4.81	0.00	2	397.5 ACS
85	0034 SPORN	SOUTH POINT	138.00	138.00	3	8.91	0.00	1	397.5 ACS
86	0034 SPORN	SOUTH POINT	138.00	138.00	3	40.41	0.00	2	397.5 ACS
87	0034 SPORN	SOUTH POINT	138.00	138.00	1	0.79	0.00	1	397.5 KCM
88	0036 SPORN	PORTSMOUTH	138.00	138.00	1	0.20	0.00	1	477 KCM
89	0036 SPORN	PORTSMOUTH	138.00	138.00	3	0.00	0.00	1	477 ACSR
90	0036 SPORN	PORTSMOUTH	138.00	138.00	3	48.39	0.00	2	477 ACSR
91	0036 SPORN	PORTSMOUTH	138.00	138.00	1	0.26	0.00	1	1033.5 KCM
92	0037 HILLSBORO	MAYSVILLE	138.00	138.00	1	0.07	0.00	1	556.5 ACSR
93	0037 HILLSBORO	MAYSVILLE	138.00	138.00	2	33.54	0.00	1	477 ACSR
94	0038 CROOKSVILLE	NORTH NEWARK	138.00	138.00	1	30.67	0.00	1	397.5 ACS
95	0038 CROOKSVILLE	NORTH NEWARK	138.00	138.00	3	0.58	0.00	2	397.5 ACS
96	0039 WEST LANCASTER	SOUTH BALTIMORE	138.00	138.00	1	5.75	0.00	1	397.5 ACS
97	0039 WEST LANCASTER	SOUTH BALTIMORE	138.00	138.00	2	4.07	0.00	1	397.5 ACS
98	0041 NORTH NEWARK	WEST MT. VERNON	138.00	138.00	1	18.95	0.00	1	477 ACSR
99	0041 NORTH NEWARK	WEST MT. VERNON	138.00	138.00	3	2.81	0.00	2	477 ACSR
100	0042 SOUTH BALTIMORE	NORTH NEWARK	138.00	138.00	1	20.50	0.00	1	397.5 ACS
101	0042 SOUTH BALTIMORE	NORTH NEWARK	138.00	138.00	1	0.54	0.00	1	397.5 ACS
102	0042 SOUTH BALTIMORE	NORTH NEWARK	138.00	138.00	3	0.05	0.00	1	397.5 ACS
103	0042 SOUTH BALTIMORE	NORTH NEWARK	138.00	138.00	3	0.08	0.00	2	795 ACSR
104	0043 BELLEFONTE EXT.		138.00	138.00	3	2.80	0.00	2	397.5 ACS
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	40.06	0.00	2	397.5 ACS
113	0050 EAST LIMA	LIMA	138.00	138.00	3	4.43	0.00	2	397.5 ACS
114	0055 TORREY	WOOSTER	138.00	138.00	1	26.39	0.00	1	556.5 ACS
115	0055 TORREY	WOOSTER	138.00	138.00	3	2.30	0.00	1	556.5 ACS
116	0056 WEST MT. VERNON	SOUTH KENTON	138.00	138.00	2	27.26	0.00	1	477 ACSR
117	0057 SOUTH KENTON	STERLING	138.00	138.00	3	0.09	0.00	1	336.4 ACS
118	0057 SOUTH KENTON	STERLING	138.00	138.00	2	24.28	0.00	1	477 KCM
119	0058 SOUTH POINT	PORTSMOUTH	138.00	138.00	3	0.04	0.00	1	397.5 ACS
120	0058 SOUTH POINT	PORTSMOUTH	138.00	138.00	3	33.17	0.00	2	397.5 ACS
121	0058 SOUTH POINT	PORTSMOUTH	138.00	138.00	1	1.40	0.00	2	397.5 KCM
122	0059 PHILO	CROOKSVILLE	138.00	138.00	3	15.37	0.00	2	336.4 ACS
123	0060 LIMA	STERLING	138.00	138.00	1	0.00	0.00	1	4/0 CU.
124	0060 LIMA	STERLING	138.00	138.00	3	0.00	0.00	1	795 ACSR
125	0061 EAST LIMA	WEST LIMA	138.00	138.00	1	0.15	0.00	2	556.5 ACS
126	0061 EAST LIMA	WEST LIMA	138.00	138.00	3	11.19	0.00	2	556.5 ACS
127	0061 EAST LIMA	WEST LIMA	138.00	138.00	3	1.05	0.00	3	556.5 ACS
128	0063 TORREY	MASSILLON	138.00	138.00	3	0.29	0.00	2	1033.5 AC
129	0066 WAGENHALS	WEST CANTON	138.00	138.00	3	9.16	0.00	1	556.5 ACS
130	0066 WAGENHALS	WEST CANTON	138.00	138.00	3	0.85	0.00	2	795 ACSR
131	0067 TORREY	AKRON	138.00	138.00	3	0.28	0.00	1	556.5 ACS
132	0069 TIDD	SOUTH CADIZ	138.00	138.00	1	11.09	0.00	1	477 ACSR
133	0069 TIDD	SOUTH CADIZ	138.00	138.00	1	0.05	0.00	1	1033.5 ACSR
134	0071 AKRON	CANTON	138.00	138.00	3	3.75	0.00	1	200 CU
135	0072 TIDD	WEIRTON NO. 2	138.00	138.00	1	7.78	0.00	1	556.5 ACS
136	0072 TIDD	WEIRTON NO. 2	138.00	138.00	3	0.38	0.00	1	556.5 ACS
137	0073 WEIRTON	SOUTH TORONTO	69.00	138.00	3	0.48	0.00	2	219.9 ACS
138	0073 WEIRTON	SOUTH TORONTO	138.00	138.00	3	0.14	0.00	1	556.5 ACS
139	0075 SPORN	KAISER NO. 1	138.00	138.00	3	4.25	0.00	2	795 ACSR
140	0076 LUCASVILLE	SARGENTS	138.00	138.00	1	11.31	0.00	1	636 ACSR
141	0076 LUCASVILLE	SARGENTS	138.00	138.00	1	0.57	0.00	1	636 KCM
142	0078 TIDD	WINDSOR JCT.	138.00	138.00	3	3.77	0.00	1	1780 ACSR
143	0080 NEWCOMERSTOWN	SOUTH COSHOCTON	138.00	138.00	1	13.12	0.00	1	336.4 ACS
144	0080 NEWCOMERSTOWN	SOUTH COSHOCTON	138.00	138.00	3	1.21	0.00	0	336.4 ACS
145	0081 FORD MOTOR EXT		138.00	138.00	3	0.25	0.00	2	397.5 ACS
146	0086 SPORN	KAISER NO. 2	138.00	138.00	3	5.67	0.00	2	795 ACSR
147	0087 WINDSOR JUNCTION	TILTONVILLE	138.00	138.00	3	3.81	0.00	1	556.5 ACS
148	0087 WINDSOR JUNCTION	TILTONVILLE	138.00	138.00	3	0.30	0.00	2	556.5 ACS
149	0089 WEST PHILO EXT. NO. 1		138.00	138.00	1	0.05	0.00	1	397.5 ACS
150	0090 WEST PHILO EXT. NO. 1		138.00	138.00	1	0.13	0.00	1	397.5 ACS
151	0091 KAMMER	OHIO FERRO ALLOYS	138.00	138.00	1	2.45	0.00	1	556.5 ACS
152	0091 KAMMER	OHIO FERRO ALLOYS (WV)	138.00	138.00	3	0.71	0.00	1	556.5 ACS
153	0095 PORTSMOUTH	TRENTON NO. 1	138.00	138.00	1	26.24	0.00	1	477 ACSR
154	0095 PORTSMOUTH	TRENTON NO. 1	138.00	138.00	1	0.25	0.00	1	477 KCM
155	0095 PORTSMOUTH	TRENTON NO. 1	138.00	138.00	3	1.04	0.00	1	477 ACSR
156	0095 PORTSMOUTH	TRENTON NO. 1	138.00	138.00	3	0.24	0.00	2	477 ACSR
157	0096 THIVENER	BUCKEYE CO-OP	138.00	138.00	1	4.94	0.00	1	219.9 ACS
158	0096 THIVENER	BUCKEYE CO-OP	138.00	138.00	1	1.22	0.00	1	219.9 KCM
159	0097 MERCERVILLE	APPLE GROVE	138.00	138.00	3	5.11	0.00	2	397.5 ACS
160	0098 MILLWOOD EXT.		138.00	138.00	1	0.10	0.00	1	500 CU.
161	0101 THIVENER EXT.		138.00	138.00	1	0.09	0.00	1	219.9 ACS
162	0102 MEIGS EXT. NO. 1		138.00	138.00	1	0.10	0.00	1	219.9 ACS
163	0103 MEIGS EXT NO. 2		138.00	138.00	1	0.10	0.00	1	219.9 ACS
164	0103 MEIGS EXT NO. 2		138.00	138.00	3	0.07	0.00	1	556.5 ACS
165	0108 OHIO CENTRAL	NORTH NEWARK	138.00	138.00	3	0.33	0.00	2	397.5 ACS
166	0108 OHIO CENTRAL	NORTH NEWARK	138.00	138.00	1	21.30	0.00	1	556.5 ACS
167	0110 NORTH STRASBURG EXT		138.00	138.00	1	0.06	0.00	1	1033.5 AC
168	0111 NORTH STRASBURG EXT		138.00	138.00	1	0.06	0.00	1	1033.5 AC
169	0112 ZANESVILLE EXT.		138.00	138.00	3	6.48	0.00	2	336.4 ACS
170	0113 HOWARD	BUCYRUS CENTER	138.00	138.00	3	16.30	0.00	1	556.5 ACS
171	0113 HOWARD	BUCYRUS CENTER	138.00	138.00	3	0.27	0.00	2	556.5 ACS
172	0114 SOUTH PEMBERVILLE	FREEMONT	138.00	138.00	1	14.18	0.00	1	556.5 ACS
173	0114 SOUTH PEMBERVILLE	FREEMONT	138.00	138.00	3	1.29	0.00	2	556.5 ACS
174	0118 SOUTH COSHOCTON	WOOSTER	138.00	138.00	2	39.51	0.00	1	477 ACSR
175	0120 OHIO CENTRAL	COSHOCTON JCT.	138.00	138.00	3	0.20	0.00	1	556.5 ACS
176	0120 OHIO CENTRAL	COSHOCTON JCT.	138.00	138.00	3	14.34	0.00	2	636 ACSR
177	0120 OHIO CENTRAL	COSHOCTON JCT.	138.00	138.00	1	0.18	0.00	1	636 KCM
178	0122 KAMMER	ORMET NO. 1	138.00	138.00	3	1.71	0.00	2	1033.5 AC
179	0123 FINDLAY CENTER EXT.		138.00	138.00	3	6.87	0.00	1	556.5 ACS
180	0125 TIDD	WEIRTON NO. 1	138.00	138.00	3	0.41	0.00	2	556.5 ACS
181	0126 ARROYO	EAST LIVERPOOL	138.00	138.00	3	0.15	0.00	1	556.5 ACS
182	0128 TIDD	NATRIUM	138.00	138.00	3	0.36	0.00	1	556.5 ACS
183	0129 HOWARD	FOSTORIA	138.00	138.00	3	44.54	0.00	2	397.5 ACSR
184	0129 HOWARD	FOSTORIA	138.00	138.00	1	0.17	0.00	2	397.5 ACSR
185	0129 HOWARD	FOSTORIA	138.00	138.00	1	0.10	0.00	2	959.6 ACSR/TW
186	0130 EAST WHEELERSB	TEXAS EASTERN	138.00	138.00	1	2.00	0.00	1	4/0 ACSR
187	0131 KAMMER	ORMET NO. 2	138.00	138.00	3	1.55	0.00	2	1033.5 AC
188	0133 SUNNYSIDE	WAGENHALS NO. 1	138.00	138.00	3	1.62	0.00	1	1033.5 AC
189	0133 SUNNYSIDE	WAGENHALS NO. 1	138.00	138.00	1	2.05	0.00	1	397.5 ACS
190	0134 TIDD	WHEELING STEEL	138.00	138.00	3	5.12	0.00	2	556.5 ACS
191	0141 MILLBROOK	SILOAM	138.00	138.00	3	1.60	0.00	2	556.5 ACS
192	0141 MILLBROOK	SILOAM	138.00	138.00	1	0.05	0.00	1	954 ACSR
193	0143 ZANESVILLE	OHIO CENTRAL	138.00	138.00	1	10.51	0.00	1	556.5 ACS
194	0143 ZANESVILLE	OHIO CENTRAL	138.00	138.00	3	2.32	0.00	1	556.5 ACS
195	0144 TORREY	TIMKEN	138.00	138.00	1	0.80	0.00	1	1033.5 AC
196	0144 TORREY	TIMKEN	138.00	138.00	3	0.86	0.00	1	1033.5 AC
197	0145 CANTON CENTRAL	TIMKEN	138.00	138.00	1	0.74	0.00	1	1033.5 AC
198	0145 CANTON CENTRAL	TIMKEN	138.00	138.00	3	5.52	0.00	1	636 ACSR
199	0146 EAST LIMA	WESTMINSTER	138.00	138.00	3	8.38	0.00	2	636 ACSR
200	0147 SUNNYSIDE	WAGENHALS NO. 2	138.00	138.00	1	2.03	0.00	1	397.5 ACS
201	0149 CANTON CENTRAL	WAGENHALS	138.00	138.00	3	2.02	0.00	2	1033.5 AC
202	0151 SOUTH CANTON	TORREY	138.00	138.00	3	1.26	0.00	1	1780 ACSR
203	0151 SOUTH CANTON	TORREY	138.00	138.00	3	1.60	0.00	2	556.5 ACS
204	0152 MALAGA	SPEIDEL	69.00	138.00	1	11.99	0.00	1	556.5 ACS
205	0153 BRIDGEVILLE EXT.		138.00	138.00	1	1.88	0.00	1	336.4 ACS
206	0142 MELMORE	TIFFIN CENTER	138.00	138.00		0.00	0.00	0
207	0158 ROBINSON PARK	RICHLAND	138.00	138.00	2	14.94	0.00	1	636 ACSR
208	0159 EAST LIMA	RICHLAND	138.00	138.00	2	27.74	0.00	1	636 ACSR
209	0164 FOSTORIA CENTRAL	FOSTORIA	138.00	138.00	3	0.08	0.00	1	1033.5 AC
210	0164 FOSTORIA CENTRAL	FOSTORIA	138.00	138.00	3	1.48	0.00	2	1033.5 AC
211	0169 SOUTH CALDWELL	SOUTH CUMBERLAND	138.00	138.00	1	10.83	0.00	1	556.5 ACSR
212	0170 HANGING ROCK EXT.		138.00	138.00	3	4.33	0.00	1	636 ACSR
213	0174 CANTON CENTRAL	BLUEBELL	138.00	138.00	1	0.25	0.00	1	795 ACSR
214	0174 CANTON CENTRAL	BLUEBELL	138.00	138.00	3	0.11	0.00	0	795 ACSR
215	0175 CANTON CENTRAL	CLOVERDALE	138.00	138.00	1	0.38	0.00	1	795 ACSR
216	0176 TIDD	STEUBENVILLE	138.00	138.00	3	7.30	0.00	1	795 ACSR
217	0177 SOUTHWEST LIMA	STERLING	138.00	138.00	3	5.21	0.00	2	1590 ACSR
218	0177 SOUTHWEST LIMA	STERLING	138.00	138.00	1	0.05	0.00	1	556.5 ACS
219	0178 SOUTHWEST LIMA	WEST LIMA	138.00	138.00	3	0.88	0.00	2	556.5 ACS
220	0180 OHIO CENTRAL EXT NO. 1		138.00	138.00	1	0.46	0.00	1	556.5 ACS
221	0181 OHIO CENTRAL EXT NO. 2		138.00	138.00	1	0.45	0.00	1	556.6 ACS
222	0182 SOUTH CANTON	WEST CANTON	138.00	138.00	1	5.20	0.00	2	795 ACSR
223	0182 SOUTH CANTON	WEST CANTON	138.00	138.00	1	0.13	0.00	2	664.8 KCM
224	0182 SOUTH CANTON	WEST CANTON	138.00	138.00	3	2.59	0.00	1	795 ACSR
225	0182 SOUTH CANTON	WEST CANTON	138.00	138.00	3	1.45	0.00	2	795 ACSR
226	0182 SOUTH CANTON	WEST CANTON	138.00	138.00	3	0.68	0.00	2	664.8 KCM
227	0183 KAMMER	WEST BELLAIRE	138.00	138.00	3	12.93	0.00	1	1033.5 AC
228	0183 KAMMER	WEST BELLAIRE	69.00	138.00	3	0.33	0.00	2	954 ACSR
229	0186 EAST ZANESVILLE EXT.		138.00	138.00	1	0.04	0.00	1	556.5 ACS
230	0187 WEST BELLAIRE	BRUES	138.00	138.00	3	4.26	0.00	1	556.5 ACS
231	0188 WEST BELLAIRE	TILTONVILLE	138.00	138.00	1	11.30	0.00	1	795 ACSR
232	0188 WEST BELLAIRE	TILTONVILLE	138.00	138.00	3	0.50	0.00	1	795 ACSR
233	0189 CROOKSVILLE TIE		138.00	138.00	1	0.20	0.00	1	556.5 ACS
234	0190 SOUTHWEST LIMA	WEST MOULTON	138.00	138.00	1	13.33	0.00	1	636 ACSR
235	0196 FREMONT CENTER	FREMONT	138.00	138.00	1	3.12	0.00	1	795 ACSR
236	0196 FREMONT CENTER	FREMONT	138.00	138.00	3	2.68	0.00	1	795 ACSR
237	0198 N. PROCTORVILLE	EAST HUNTINGTON	138.00	138.00	3	3.86	0.00	1	795 ACSR
238	0198 N. PROCTORVILLE	EAST HUNTINGTON	34.00	138.00	3	0.08	0.00	2	795 ACSR
239	0200 CAMPBELL ROAD	MIDWEST CO-OP	138.00	138.00	1	0.15	0.00	1	336.4 ACS
240	0201 N. PROCTORVILLE	SOUTH POINT	138.00	138.00	3	0.04	0.00	1	795 ACSR
241	0201 N. PROCTORVILLE	SOUTH POINT	138.00	138.00	3	10.83	0.00	2	795 ACSR
242	0202 MUSKINGUM	WOLF CREEK	138.00	138.00	1	0.00	0.00	1	556.5 ACS
243	0202 MUSKINGUM	WOLF CREEK	138.00	138.00	3	0.00	0.00	1	636 ACSR
244	0202 MUSKINGUM	WOLF CREEK	138.00	138.00	3	0.76	0.00	1	1233.6 ACSR
245	0203 SWITZER EXT. NO. 1		138.00	138.00	1	0.00	0.00	1	556.5 ACS
246	0204 SWITZER EXT. NO. 2		138.00	138.00	1	0.00	0.00	1	556.5 ACS
247	0210 BUCKLEY ROAD EXT.		138.00	138.00	1	2.75	0.00	1	795 ACSR
248	0213 WINDSOR EXT. NO. 2		0.00	138.00	1	0.11	0.00	1
249	0221 DARRAH	NORTH PROCTORVILLE	138.00	138.00	3	3.51	0.00	1	1033.5 AC
250	0223 DEXTER	MEIGS NO. 2	138.00	138.00	1	5.53	0.00	1	556.5 ACS
251	0224 NORTH RUTLAND	MEIGS NO. 1	138.00	138.00	1	3.84	0.00	1	556.5 ACS
252	0225 Amity	Academia	138.00	138.00	1	0.20	0.00	1	556.5 ACSR
253	0225 AMITY	ACADEMIA	138.00	138.00	3	0.14	0.00	1	556.5 ACS
254	0225 AMITY	ACADEMIA	138.00	138.00	3	6.33	0.00	2	795 ACSR
255	0226 ACADEMIA	WEST MT. VERNON	138.00	138.00	3	0.15	0.00	2	556.5 ACS
256	0226 ACADEMIA	WEST MT. VERNON	138.00	138.00	3	5.95	0.00	1	795 ACSR
257	0229 CANNELVILLE	GURNSEY MUSKINGUM C	138.00	138.00	1	0.11	0.00	1	336.4 ACS
258	0230 FAIRCREST EXT.		138.00	138.00	1	0.04	0.00	1	1033.5 AC
259	0235 WEST MILLERSPORT	HEATH	138.00	138.00	1	8.95	0.00	1	795 ACSR
260	0235 WEST MILLERSPORT	HEATH	138.00	138.00	3	3.06	0.00	1	795 ACSR
261	0238 NORTH PROCTORVILLE	EXTENSION	138.00	138.00	3	3.54	0.00	1	556.5 ACS
262	0240 NORTH CROWN CITY EXT		138.00	138.00	1	0.24	0.00	1	556.5 ACS
263	0241 NORTH CROWN CITY EXT		138.00	138.00	1	0.24	0.00	1	556.5 ACS
264	0242 HEATH EXT. NO. 2		138.00	138.00	3	1.29	0.00	1	795 ACSR
265	0243 HEATH EXT. NO. 1		138.00	138.00	3	1.29	0.00	1	556.5 ACS
266	0244 EAST SIDE EXT.		138.00	138.00	1	0.24	0.00	2	795 ACSR
267	0244 EAST SIDE EXT.		138.00	138.00	3	0.08	0.00	2	795 ACSR
268	0245 SOUTHEAST CANTON	SUNNYSIDE	138.00	138.00	3	2.31	0.00	2	1033.5 AC
269	0247 SOUTHEAST CANTON	WACO	138.00	138.00	3	2.12	0.00	2	1033.5 AC
270	0252 WEST DOVER EXT. NO.		138.00	138.00	1	0.10	0.00	1	1033.5 AC
271	0253 WEST DOVER EXT. NO.		138.00	138.00	1	0.09	0.00	1	1033.5 AC
272	0254 BUCKEYE CO-OP EXT. A		138.00	138.00	1	0.21	0.00	1	556.5 ACS
273	0257 GREENLAWN EXT.		138.00	138.00	1	0.97	0.00	2	795 ACSR
274	0257 GREENLAWN EXT.		138.00	138.00	3	0.12	0.00	0	795 ACSR
275	0260 EAST PROCTORVILLE EXT.		138.00	138.00	3	0.13	0.00	2	1033.5 AC
276	0264 FREMONT	SANDUSKY BAY	69.00	138.00	1	11.88	0.00	1	795 ACSR
277	0264 FREMONT	SANDUSKY BAY	69.00	138.00	3	0.25	0.00	0	795 ACSR
278	0265 WEST DOVER	SUGARCREEK	138.00	138.00	1	4.07	0.00	1	795 ACSR
279	0267 NORTH PORTSMOUTH	CENTRAL PORTSMOUTH	138.00	138.00	1	6.04	0.00	1	795 ACSR
280	0273 BUCKLEY ROAD	FREMONT CENTER	69.00	138.00	1	0.90	0.00	2	556.5 ACS
281	0274 WAYVIEW	HOOVER NORTH	69.00	138.00	3	0.02	0.00	1	795 ACSR
282	0274 WAYVIEW	HOOVER NORTH	69.00	138.00	3	1.04	0.00	2	795 ACSR
283	0275 WEST CANTON JCT.	WAYVIEW	138.00	138.00	1	1.11	0.00	1	795 ACSR
284	0275 WEST CANTON JCT.	WAYVIEW	138.00	138.00	1	1.80	0.00	2	795 ACSR
285	0275 WEST CANTON JCT.	WAYVIEW	138.00	138.00	3	1.89	0.00	1	795 ACSR
286	0276 BELDEN VILLAGE EXT.		138.00	138.00	1	1.51	0.00	1	795 ACSR
287	0280 EAST AMSTERDAM	CARROLL CO-OP	69.00	138.00	1	7.98	0.00	1	795 ACSR
288	0282 SOUTH POINT TIE		138.00	138.00	1	0.09	0.00	1	795 ACSR
289	0286 WEST CANTON TIE		138.00	138.00	1	0.16	0.00	2	795 ACSR
290	0289 OHIO CENTRAL EXT. NO.		138.00	138.00	1	0.27	0.00	1	636 ACSR
291	0290 SOUTH CANTON EXT. NO.		138.00	138.00	3	0.71	0.00	2	1033.5 AC
292	0294 SOUTH CANTON EXT. NO.		138.00	138.00	3	0.31	0.00	2	1033.5 AC
293	0295 BROADACRE EXT.		138.00	138.00	1	0.04	0.00	2	1780 ACSR
294	0307 WEST VAN WERT	DELPHOS CENTER	69.00	138.00	1	1.70	0.00	1	795 ACSR
295	0313 BUCKEYE COOP EXT. W		138.00	138.00	1	0.85	0.00	1	556.5 ACS
296	0316 ORDANANCE JCT. EXT.		138.00	138.00	1	0.10	0.00	2	1590 ACSR
297	0317 GUERNSEY	MUSKINGUM CO-OP EXT.	138.00	138.00	1	0.12	0.00	1	556.5 ACS
298	0318 BUCKEYE CO-OP EXT. M		138.00	138.00	1	0.15	0.00	1	556.5 ACS
299	0320 HEDDING ROAD	MORROW CO-OP	138.00	138.00	1	0.09	0.00	1	795 ACSR
300	0324 WEST MILLERSPORT	SOUTH CENTRAL POWER	138.00	138.00	1	0.20	0.00	1	556.5 ACS
301	0325 SHELBY MUNICIPAL EXT.		138.00	138.00	3	0.53	0.00	1	336.4 ACS
302	0326 BLOOMFIELD	GUERNSEY MUSKINGUM C	138.00	138.00	1	0.41	0.00	1	336.4 ACS
303	0327 NORTH CENTRAL CO-OP		138.00	138.00	1	0.45	0.00	1	336.4 ACS
304	0328 NORTH CHESIRE	EXTENSION NO. 2	138.00	138.00		0.00	0.00	0
305	0329 TYCOON EXT.		138.00	138.00	1	0.29	0.00	1	556.5 ACS
306	0331 LICKING CO-OP EXT.		138.00	138.00	1	0.04	0.00	1	336.4 ACS
307	0331 Licking Co-Op Extension	Bladensburg	138.00	138.00	1	0.04	0.00	1	795 ACSR
308	0333 ASHLEY EXT		69.00	138.00	1	0.62	0.00	1	336.4 ACS
309	0334 NORTH CHESHIRE	EXTENTION NO. 1	138.00	138.00	3	0.38	0.00	2	1033.5 AC
310	0336 SHUFFEL ROAD	TIMKEN RESEARCH	69.00	138.00	3	0.66	0.00	1	795 ACSR
311	0337 TIMKEN, RICHVILLE EX		138.00	138.00	1	1.11	0.00	2	1033.5 AC
312	0338 CONESVILLE COAL PREP		138.00	138.00	1	0.63	0.00	1	1033.5 AC
313	0339 A.G.A. GAS EXT.		138.00	138.00	1	0.16	0.00	1	336.4 ACS
314	0342 EAST WOOSTER EXT. NO.		138.00	138.00	3	5.15	0.00	2	556.5 ACS
315	0343 EAST WOOSTER EXT.		138.00	138.00	1	0.18	0.00	1	795 ACSR
316	0343 EAST WOOSTER EXT.		138.00	138.00	1	0.43	0.00	2	795 ACSR
317	0344 WAGENHALS	LTV STEEL NO. 1	138.00	138.00	3	0.65	0.00	1	1033.5 AC
318	0345 WAGENHALS	LTV STEEL NO. 2	138.00	138.00	3	0.68	0.00	1	1033.5 AC
319	0346 FOSTORIA TIE		138.00	138.00	1	0.02	0.00	1	336.4 ACS
320	0347 FOSTORIA CENTRAL EXT.		138.00	138.00	3	0.10	0.00	2	1033.5 AC
321	0348 FOSTORIA CENTRAL EXT.		138.00	138.00	3	0.10	0.00	1	1033.5 AC
322	0349 FOSTORIA POWER EXT.		138.00	138.00	3	0.10	0.00	3	336.4 ACS
323	0350 HANCOCK WOOD CO-OP		138.00	138.00	1	0.03	0.00	1	556.5 ACS
324	0351 EAST LEIPSIC EXT		138.00	138.00	1	6.57	0.00	2	795 ACSR
325	0352 BUCKEYE CO-OP EXT		138.00	138.00	1	0.09	0.00	1	336.4 ACS
326	0353 STERLING	FOUNDRY PARK	138.00	138.00	1	0.99	0.00	1	795 ACSR
327	0354 GAVIN EXT. NO. 1		138.00	138.00	3	3.10	0.00	2	1033.5 AC
328	0355 GAVIN EXT. NO. 2		138.00	138.00	3	2.97	0.00	2	1033.5 AC
329	0358 LICKING REC. EXT. A		138.00	138.00	1	0.21	0.00	2	556.5 ACS
330	0359 BUCKHORN	HOLMES	138.00	138.00	1	0.98	0.00	1	336.4 ACS
331	0360 ADAMS RUAL ELECTRICK	EMERALD	138.00	138.00	1	0.75	0.00	1	556.5 ACSR
332	0361 RILEY CREEK	PAULDING PUTNAM	138.00	138.00	3	1.20	0.00	1	336.4 ACS
333	0363 MEIGS NO. 2	WILKESVILLE	138.00	138.00		1.60	0.00	1
334	0364 NORTH CENTRAL CO-OP		138.00	138.00		1.84	0.00	1	556.5 ACS
335	0368 BALL HOLLOW	WASHINGTON CO-OP	138.00	138.00		0.05	0.00	1	556.5 ACS
336	0371 SPENCER RIDGE	BUCKINGHAM COAL	138.00	138.00	1	0.12	0.00	1	4/0 ACSR
337	0370 BUCKEYE CO-OP EXT		138.00	138.00	3	0.10	0.00	2	397.5 ACS
338	0372 NORTH BELLVILLE LOOP		138.00	138.00	1	0.11	0.00	2	556.5 ACS
339	0375 HANTHORN RD	G.O. ETHANOL	0.00	138.00	3	0.34	0.00	1	556.5 ACS
340	0376 WARNER EXTENSION	SUNNYSIDE-TORREY	138.00	138.00	1	0.30	0.00	1	397.5 ACS
341	0377 YELLOWBUSH		138.00	138.00	3	0.04	0.00	1	795 ACSR
342	0380 TIDD 345KV	138KV AUTO TRANS B BUS TIE	138.00	138.00	2	0.01	0.00	1	1590 ACSS
343	0381 Anguin Extension		138.00	138.00	1	0.84	0.00	2	795 ACSS
344	LINES < 132KV					2,085.22
345	Columbus Southern Power Co	Columbus Southern Power Co
346	9032 BEATTY	HAYDEN	345.00	345.00	1	0.00	0.00	1	2-954 ACSR
347	9032 BEATTY	HAYDEN	345.00	345.00	3	16.84	0.00	1	2-954 ACSR
348	9032 BEATTY	HAYDEN	345.00	345.00	1	0.44	0.00	1	2-954 ACSR
349	9034 CONESVILLE	CORRIDOR	345.00	345.00	3	54.00	0.00	1	2-1272 ACSR
350	C633 POINT N	STR. 96-1	345.00	345.00	1,3	4.24	0.00	1	2-954 ACSR
351	C633B KIRK	CORRIDOR	345.00	345.00	2	11.96	0.00	2	2-954 ACSR
352	9037 HAYDEN	HYATT	345.00	345.00	3	12.00	0.00	1	2-954 ACSR
353	9038 HAYDEN	ROBERTS	345.00	345.00	1	5.58	0.00	1	2-954 ACSR
354	9039 POINT Z	CORRIDOR	345.00	345.00	2	12.44	0.00	1	2-954 ACSR
355	C613 KIRK EXT #1 (NORTH)		345.00	345.00	2	0.25	0.00	1	636 ACSR 26/7
356	C614 KIRK EXT #2 (SOUTH)		345.00	345.00	3	0.25	0.00	1	636 ACSR 26/7
357	8790 DAVIDSON	DUBLIN	138.00	138.00	4	3.15	0.00	1	2000 CU KCM
358	C710 DUBLIN	SAWMILL	138.00	138.00	1	6.40	0.00	1	636 ACSR 26/7
359	C795 KIMBERLY EXTENSION		138.00	138.00	1	0.56	0.00	2	636 ACSR 26/7
360	C796 DON MARQUIS LOOP #1		138.00	138.00	1	6.60	0.00	1	1033.5 KCM
361	C798 DON MARQUIS LOOP #2		138.00	138.00	1	0.65	0.00	1	1033.5 KCM
362	C799 GREIF EXTENSION		138.00	138.00	4	0.66	0.00	2	2000 kcm CU
363	C800 LICK	JACKSON	138.00	138.00	1	1.09	0.00	0
364	C850 WILLOW ISLAND	MILL CREEK	138.00	138.00	1	9.14	0.00	1	954 ACSR 45/7
365	C851 MILL CREEK	RIVERVIEW	138.00	138.00	1	10.38	0.00	1	954 ACSR 45/7
366	C851 MILL CREEK	RIVERVIEW	138.00	138.00	1	0.14	0.00	1	1033.5 ACSR
367	C852 RIVERVIEW	CORNER	138.00	138.00	1	7.09	0.00	1	954 ACSR 45/7
368	C853 CORNER	SHELL	138.00	138.00	1	2.13	0.00	1	336.4 ACSR 26/7
369	C854 PARKERSBURG	CORNER	138.00	138.00	1	0.02	0.00	1	336.4 ACSR
370	C854 PARKERSBURG	CORNER	138.00	138.00	2	1.25	0.00	1	336.4 ACSR
371	C855 MUSKINGUM	CORNER	138.00	138.00	1	15.79	0.00	1	556.5 ACSR 26/7
372	C856 BELMONT	RIVERVIEW	138.00	138.00	1	0.86	0.00	1	954 ACSR 45/7
373	C857 WASHINGTON	CORNER	138.00	138.00	1	6.51	0.00	1	954 ACSR 45/7
374	C858 RIVERVIEW	ELKEM METALS	138.00	138.00	1	0.80	0.00	1	954 ACSR 45/7
375	C976 Pine Ridge	Buckeye Co-Op	69.00	138.00	1	0.07	0.00	1	1033 ACSR
376	9006 GREENE	BEATTY	345.00	345.00	3	19.72	0.00	1	2-1024 ACAR
377	9006 GREENE	BEATTY	345.00	345.00	2	0.10	0.00	1	2-1024 ACAR
378	9007 MARQUIS	POINT X	345.00	345.00	1	0.39	0.00	1	2-954 KCM
379	9007 Don Marquis	Point X	345.00	345.00	2	0.18	0.00	1	2-983 ACAR
380	9007 MARQUIS	POINT X	345.00	345.00	3	45.43	0.00	1	2-983 ACAR
381	9010 STUART	POINT O	345.00	345.00	3	15.19	0.00	1	2-983 ACAR
382	9049 KILLEN-POINT O	MARQUIS	345.00	345.00	3	32.00	0.00	1	2-983 ACAR
383	9742 POINT Y	BEATTY	345.00	345.00	3	15.00	4.00	1	2-983 ACAR
384	9031 BEATTY	BIXBY	345.00	345.00	3	13.20	0.00	1	2-954 ACSR
385	9042 STUART	POINT Y	345.00	345.00	3	75.00	0.00	1	2-954 ACSR
386	9043 CONESVILLE	TOWER 71	345.00	345.00	2	42.76	0.00	1	2-954 ACSR
387	9043 TOWER 71	BIXBY	345.00	345.00	3	0.00	15.00	1	2-954 ACSR
388	9043 CONESVILLE	BIXBY	345.00	345.00	1	50.80	0.00	1	2-954 ACSR
389	9043 CONESVILLE	BIXBY	345.00	345.00	3	3.00	0.00	1	2-954 ACSR
390	9707 TOWER 27	BIXBY	345.00	345.00	3	0.00	9.00	1	2-954 ACSR
391	9707 TOWER 27	BIXBY	345.00	345.00	3	17.44	9.00	1	2-954 ACSR
392	9040 CONESVILLE	POINT Z	345.00	345.00	3	57.00	0.00	1	2-954 ACSR
393	9740 POINT Z	HYATT	345.00	345.00	3	9.00	0.00	1	2-954 ACSR
394	9740 POINT Z	HYATT	345.00	345.00	1	2.00	0.00	1	2-954 ACSR
395	C633A BIXBY	CORRIDOR (BIXBY-POINT N)	345.00	345.00	3	14.88	0.00	1	2-954 ACSR
396	8001 ROBERTS	BETHEL	138.00	138.00	1	0.00	0.00	2	636 ACSR
397	8001 ROBERTS	BETHEL	138.00	138.00	3	5.00	0.00	2	636 ACSR
398	8002 ROBERTS	KENNY	138.00	138.00	4	3.00	0.00	1	2500 ALUM
399	C789 BEAVER 138KV EXTENSION		138.00	138.00		0.00	0.00	0	0
400	8004 BETHEL	LINWORTH	138.00	138.00	3	0.00	3.00	1	636 ACSR
401	8004 BETHEL	LINWORTH	138.00	138.00	1	2.00	0.00	1	636 AA
402	8005 PICWAY	HARRISON	138.00	138.00	3	1.00	0.00	1	636 ACSR
403	8008 GROVES	BEXLEY	138.00	138.00	1	0.00	0.00	1	636 ACSR
404	8009 BEXLEY	ST. CLAIR	138.00	138.00	1	4.00	0.00	1	636 AA
405	8010 BIXBY	LSII	138.00	138.00	1	1.00	2.00	1	636 ACSR
406	8010 BIXBY	LSII	138.00	138.00	2	2.00	0.00	1	636 ACSR
407	8010 BIXBY	LSII	138.00	138.00	3	0.00	0.00	1	636 ACSR
408	8011 BIXBY	W. LANCASTER	138.00	138.00	2	0.00	0.00	1	4/O CWC
409	8011 BIXBY	W. LANCASTER	138.00	138.00	2	0.00	0.00	1	954 ACSR
410	8011 BIXBY	W. LANCASTER	138.00	138.00	2	0.00	0.00	1	636 ACSR
411	8015 LSII	MARION	138.00	138.00	1	2.17	0.00	1	636 ACSR
412	8015 LSII	MARION	138.00	138.00	3	3.00	0.00	1	636 ACSR
413	8016 MARION	CANAL	138.00	138.00	4	4.00	0.00	1	600 CU PIPT
414	8017 ST CLAIR	CLINTON	138.00	138.00	4	4.00	0.00	1	600 CU PIPT
415	8018 HARRISON	MARION	138.00	138.00	2	7.00	0.00	1	636 ACSR
416	8018 HARRISON	MARION	138.00	138.00	3	0.00	3.00	1	636 ACSR
417	8019 BIXBY	GROVES-ASTOR	138.00	138.00	1	8.42	0.00	1	636 AAA
418	8021 BEATTY	WILSON (EAST)	138.00	138.00	3	7.00	1.00	1	636 ACSR
419	8022 BEATTY	WILSON (WEST)	138.00	138.00	3	0.00	1.00	2	636 ACSR
420	8022 BEATTY	WILSON (WEST)	138.00	138.00	3	0.00	9.00	1	636 ACSR
421	8023 WAVERLY	SARGENTS	138.00	138.00	2	16.00	0.00	1	636 ACSR
422	8024 WAVERLY	ADAMS-SEAMAN	138.00	138.00	2	7.90	0.00	1	336 ACSR
423	8024 WAVERLY	ADAMS-SEAMAN	138.00	138.00	1	0.10	0.00	1	336.4 KCM
424	8024 WAVERLY	ADAMS-SEAMAN	138.00	138.00	1	0.14	0.00	1	1236.4 KCM
425	8025 CIRCLEVILLE	SCIPPO	138.00	138.00	2	0.96	0.00	1	336.4 ACSR
426	8025 CIRCLEVILLE	SCIPPO	138.00	138.00	1	0.62	0.00	1	336.4 KCM
427	8027 WAVERLY	LICK	138.00	138.00	2	16.00	0.00	1	636 ACSR
428	8027 WAVERLY	LICK	138.00	138.00	3	11.00	0.00	1	636 ACSR
429	8028 MORSE	GENOA-KARL	138.00	138.00	3	4.00	0.00	1	1272 ACSR
430	8028 MORSE	GENOA-KARL	138.00	138.00	1	4.94	0.00	1	636 ACSR
431	8028 MORSE	GENOA-KARL	138.00	138.00	2	2.00	0.00	1	600 CU PIPT
432	8029 OSU	HESS	138.00	138.00	4	1.00	0.00	1	636 ACSR
433	8030 WILSON	FIFTH-HESS	138.00	138.00	3	3.00	0.00	1	600 CU PIPT
434	8030 WILSON	FIFTH-HESS	138.00	138.00	4	2.00	0.00	1	636 ACSR
435	8031 WILSON	ROBERTS	138.00	138.00	3	5.00	0.00	1	636 ACSR
436	8031 WILSON	ROBERTS	138.00	138.00	1	0.00	0.00	1	636 ACSR
437	8031 WILSON	ROBERTS	138.00	138.00	1	1.00	0.00	2	636 ACSR
438	8032 BIXBY	BUCKEYE STEEL	138.00	138.00	3	3.00	1.00	1	636 ACSR
439	8032 BIXBY	BUCKEYE STEEL	138.00	138.00	2	2.00	0.00	1	636 AA
440	8032 BIXBY	BUCKEYE STEEL	138.00	138.00	1	1.17	0.00	1	1250 CU PIPT
441	8033 GAY	VINE	138.00	138.00	4	2.00	0.00	1	954 ACSR
442	8034 EAST BROAD	GAHANNA	138.00	138.00	1	0.03	1.03	1	636 AA
443	8034 EAST BROAD	GAHANNA	138.00	138.00	2	1.00	0.00	1	336.4 ACSR
444	8034 EAST BROAD	GAHANNA	138.00	138.00	2	3.00	0.00	1	636 ACSR
445	8035 HYATT	SAWMILL	138.00	138.00	1	5.43	0.00	2	1590 ACSR
446	8036 GAHANNA	MORSE	138.00	138.00	2	5.00	0.00	1	636 ACSR
447	8036 GAHANNA	MORSE	138.00	138.00	2	0.00	0.00	1	1272 ACSR
448	8037 CORRIDOR	MORSE-BLENDON	138.00	138.00	3	0.00	7.00	1	1272 ACSR
449	8037 CORRIDOR	MORSE-BLENDON	138.00	138.00	1	1.00	0.00	2	1272 ACSR
450	8038 CORRIDOR	MORSE	138.00	138.00	3	7.00	0.00	1	1272 ACSR
451	8039 KIRK	EAST BROAD	138.00	138.00	3	10.00	0.00	1	1272 ACSR
452	8040 KIRK	EAST BROAD	138.00	138.00	3	0.00	10.00	1	600 CU PIPT
453	8041 CANAL	MOUND	138.00	138.00	4	2.00	0.00	1	1272 ACSR
454	8043 CONESVILLE	TRENT	138.00	138.00	3	52.00	0.00	1	1272 ACSR
455	8043 CONESVILLE	TRENT	138.00	138.00	1	0.00	0.00	1	1272 ACSR
456	8044 TRENT	DELAWARE	138.00	138.00	3	12.61	0.00	1	1272 ACSR
457	8044 TRENT	DELAWARE	138.00	138.00	1	0.05	0.00	1	1272 ACSR
458	8046 ST. CLAIR	MIFFLIN STELZER	138.00	138.00	1	7.00	0.00	1	636 AA
459	8047 KENNY	KARL	138.00	138.00	3	1.00	0.00	1	1272 ACSR
460	8047 KENNY	KARL	138.00	138.00	3	3.00	0.00	1	336.4 ACSR
461	8047 KENNY	KARL	138.00	138.00	4	3.00	0.00	1	2500 ALUM
462	MORSE	CLINTON	138.00	138.00	3	0.00	5.00	1	1272 ACSR
463	MORSE	CLINTON	138.00	138.00	3	0.00	3.00	1	636 ACSR
464	8048 MORSE	HUNTLEY-CLINTON	138.00	138.00	3	3.00	0.00	1	636 AA
465	8049 BIXBY	GROVES	138.00	138.00	3	3.00	0.00	2	636 ACSR
466	8049 BIXBY	GROVES	138.00	138.00	1	1.00	0.00	2	636 ACSR
467	8049 BIXBY	GROVES	138.00	138.00	3	0.00	0.00	1	1272 ACSR
468	8049 BIXBY	GROVES	138.00	138.00	1	0.00	0.00	1	336.4 ACSR
469	8051 POSTON	STROUDS RUN-CROOKSVILLE	138.00	138.00	1	0.00	0.00	1	1272 KCM
470	8051 POSTON	STROUDS RUN-CROOKSVILLE	138.00	138.00	2	7.23	0.00	1	636 ACSR
471	8053 BEATTY	CANAL	138.00	138.00	1	11.28	2.00	2	636 AAC
472	8053 BEATTY	CANAL	138.00	138.00	1	0.08	0.00	2	795 KCM
473	8055 CONESVILLE	OHIO CENTRAL	138.00	138.00	2	12.00	0.00	1	636 ACSR
474	8056 EAST BROAD	ASTOR	138.00	138.00	1	2.92	0.00	1	636 AA
475	8056 EAST BRAOD	ASTOR	138.00	138.00	1	0.10	0.00	2	795 KCM
476	8057 HARRISON	BEATTY	138.00	138.00	1,3	8.57	0.12	1	336.4 ACSR
477	8058 HARRISON	S CENTRAL REA	138.00	138.00	1	0.00	0.00	1	636 AA
478	8060 BEATTY	MCCOMB	138.00	138.00	1	2.00	3.00	1	636 AA
479	8061 MORSE	STELZER	138.00	138.00	4	2.00	0.00	1	2500 CU PIPT
480	8061 MORSE	STELZER	138.00	138.00	1	2.00	0.00	1	636 AA
481	8062 HUNTLEY	LINWORTH	138.00	138.00	1	3.32	1.00	1	636 ACSR
482	8065 HYATT	GENOA	138.00	138.00	1	5.03	9.00	1	636 ACSR
483	8066 BUCKEYE STEEL	GAY	138.00	138.00	1	3.00	0.00	1	636 AA
484	8066 BUCKEYE STEEL	GAY	138.00	138.00	4	1.00	0.00	1	1259 CU PIPT
485	8067 POSTON	ELLIOT-DEXTER	138.00	138.00	1	0.00	0.00	1	1272 KCM
486	8067 POSTON	ELLIOT-DEXTER	138.00	138.00	2	4.03	0.00	1	636 ACSR
487	8068 HYATT	HUNTLEY	138.00	138.00	1	12.00	0.00	1	636 ACSR
488	8069 LICK	ADDISON	138.00	138.00	2	29.00	0.00	1	336.4 ACSR
489	8069 LICK	ADDISON	138.00	138.00	1	0.00	0.00	1	336.4 ACSR
490	8070 SCIPPO	SCIOTO TRAIL - DUPONT	138.00	138.00	1	1.00	0.00	1	636 ACSR
491	8070 SCIPPO	SCIOTO TRAIL - DUPONT	138.00	138.00	2	0.00	1.00	1	636 ACSR
492	8070 SCIPPO	SCIOTO TRAIL - DUPONT	138.00	138.00	2	1.00	0.00	1	336 ACSR
493	8072 SAWMILL	BETHEL	138.00	138.00	1	0.00	0.00	1	636 ACSR
494	8072 SAWMILL	BETHEL	138.00	138.00	3	2.40	0.00	1	636 ACSR
495	8074 SCIPPO	HARGUS	138.00	138.00	1	1.00	0.00	1	636 ACSR
496	8075 MOUND	ST. CLAIR	138.00	138.00	4	2.00	0.00	1	600 CU PIPT
497	8077 WAVERLY	MULBERRY ROSS	138.00	138.00	1	2.00	0.00	1	636 ACSR
498	8077 WAVERLY	MULBERRY ROSS	138.00	138.00	1	2.14	0.00	1	636 ACSR
499	8078 MCCOMB	SULLIVANT-GAY	138.00	138.00	1	8.90	0.00	2	636 ACSR
500	8079 MULBERRY	ROSS	138.00	138.00	1	0.00	2.00	1	636 ACSR
501	8079 MULBERRY	ROSS	138.00	138.00	2	3.00	0.00	1	636 ACSR
502	8079 MULBERRY	ROSS	138.00	138.00	1	1.00	0.00	1	636 ACSR
503	8080 EAST BROAD	BEXLEY	138.00	138.00	1	6.00	0.00	1	954 ACSR
504	8080 EAST BROAD	BEXLEY	138.00	138.00	2	0.00	0.00	1	954 ACSR
505	8081 HYATT	ROSS	138.00	138.00	1	1.00	0.00	1	1272 ACSR
506	8082 CORRIDOR	GENOA	138.00	138.00	1	0.36	0.00	1	1272 ACSR
507	8083 CORRIDOR	GAHANNA	138.00	138.00	1	0.00	0.00	1	1272 ACSR
508	KIRK	W. MILLERSPORT	138.00	138.00	3	0.00	8.00	1	1272 ACSR
509	KIRK	W. MILLERSPORT	138.00	138.00	3	0.00	0.00	1	636 ACSR
510	8086 CONESVILLE	KIRK	138.00	138.00	1	2.53	0.00	1	1272 KCM
511	8086 Conesville	Kirk	138.00	138.00	1	0.11	0.00	1	1590 ACSR
512	8086 CONESVILLE	KIRK	138.00	138.00	2	0.00	0.00	1	1272 ACSR
513	8086 CONESVILLE	KIRK	138.00	138.00	3	37.88	0.00	2	1272 ACSR
514	8086 CONESVILLE	KIRK	138.00	138.00	3	5.47	0.00	1	1272 ACSR
515	8088 HESS	VINE	138.00	138.00	4	2.00	0.00	1	1250 CU PIPT
516	8092 VINE	CITY OF COLUMBUS EAST	138.00	138.00	1	1.28	0.00	1	983.1 ACAR
517	8098 VINE	CITY OF COLUMBUS WEST	138.00	138.00	1	1.00	0.00	1	983.1 ACSR
518	8099 ST. CLAIR	VINE	138.00	138.00	1	1.00	0.00	1	954 ACSR
519	8099 ST. CLAIR	VINE	138.00	138.00	4	1.00	0.00	1	2750 CU KCM
520	8102 CLINTON	OSU	138.00	138.00	4	4.00	0.00	1	600 CU PIPT
521	8105 DAVIDSON RD	ROBERTS-BETHEL	138.00	138.00	1	0.00	0.00	2	636 ACSR
522	8129 OSU	HESS	138.00	138.00	4	1.00	0.00	1	600 CU PIPT
523	8712 SCIPPO	EAST SCIPPO	138.00	138.00		0.00	0.00	0	636 ACSR
524	8788 FISHER 138KV		138.00	138.00	3	0.42	0.00	1	636 ACSR
525	C792 CLAYBURNE	KENWORTH	138.00	138.00	1	0.32	0.00	1	565.5 ACSR 18/1
526	C793 DELANO	KENWORTH	138.00	138.00	1	0.31	0.00	1	556.5 ACSR 18/1
527	C794 BOLTON EXTENSION		138.00	138.00		0.00	0.00	0
528	TRANSMISSION LINES	LESS THAN 132 KV				458.11	22.50	0
529	Line costs and expenses are	not available by individual								107,959,660	1,209,880,291	1,317,839,951	75,821	19,639,855		19,715,677
530	transmission line.	Total shown in Column j-p
36	TOTAL					6,353.13	131.65	641		107,959,659.62	1,209,880,291.14	1,317,839,950.76	75,821.46	19,639,855.31	0.00	19,715,676.77

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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.

(a)

(b)

(c)

(d)

(e)

(f)

(g)

(h)

(i)

(j)

(k)

(l)

(m)

(n)

(o)

(p)

(q)

0403 Sporn

Kyger Creek (OVEC)

0.03

1.00

1272

ACSS

345

708,210

56,649

764,860

TOTAL

708,210

56,649

764,860

Name of Respondent:

Ohio Power Company

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

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		69.00	0.00	0.00	0.00			STATCAP	1	18.00
2	ACADEMIA - OH	Transmission		138.00	69.00	13.00	129.00	1			0	0.00
3	ADA - OH	Distribution		69.00	13.09		20.00	1			0	0.00
4	ADAMS (CSP) - OH	Transmission		138.00	69.00	13.09	56.00	1			0	0.00
5	ADAMS (CSP) - OH	Transmission		69.00	13.09		20.00	1			0	0.00
6	ADAMS (CSP) - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
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		30.00	1			0	0.00
12	AMLIN - OH	Distribution		138.00	13.80		50.00	0	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	12.00		6.25	1			0	0.00
16	ANCHOR HOCKING (OP) - OH	Distribution		69.00	4.00		6.25	1			0	0.00
17	ANCHOR HOCKING (OP) - OH	Distribution		34.50	4.00		2.50	0	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	13.20		9.38	1			0	0.00
24	ASHLEY - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	28.80
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	13.80		50.00	1			0	0.00
39	BEATTY ROAD - OH	Transmission		138.00	70.50	36.25	54.00	0	1		0	0.00
40	BEATTY ROAD - OH	Transmission		138.00	13.09		15.00	0	1		0	0.00
41	BEATTY ROAD - OH	Transmission		138.00	13.09			0	1		0	0.00
42	BEATTY ROAD - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	2	7.20
43	BEATTY ROAD - OH	Transmission		345.00	137.50	13.80	450.00	1			0	0.00
44	BEAVER - OH	Distribution		69.00	12.00		20.00	1			0	0.00
45	BEAVERDAM - OH	Distribution		34.50	13.09		9.74	1			0	0.00
46	BELDEN VILLAGE - OH	Distribution		138.00	13.09		34.40	2			0	0.00
47	BELLAIRE (OP) - OH	Distribution		69.00	12.00		6.25	1			0	0.00
48	BELLVILLE - OH	Distribution		69.00	12.00		9.38	1			0	0.00
49	BELPRE - OH	Distribution		138.00	13.09		40.00	2			0	0.00
50	BERKSHIRE - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1	7.20
51	BERKSHIRE - OH	Distribution		138.00	35.40	13.80	50.00	1			0	0.00
52	BERLIN (OP) - OH	Distribution		69.00	34.50		12.50	1			0	0.00
53	BERLIN (OP) - OH	Distribution		69.00	13.09		20.00	1			0	0.00
54	BERWICK - OH	Distribution		69.00	13.09		20.00	1			0	0.00
55	BETHEL ROAD - OH	Transmission		138.00	69.50	13.09	50.00	1			0	0.00
56	BETHEL ROAD - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	72.00
57	BETHEL ROAD - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	5	28.80
58	BETHEL ROAD - OH	Transmission		138.00	13.80	13.80	167.30	2			0	0.00
59	BETHEL ROAD - OH	Transmission		138.00	13.80	13.80	83.30	0	1		0	0.00
60	BEXLEY - OH	Transmission		138.00	40.00	13.80	83.33	2			0	0.00
61	BEXLEY - OH	Transmission		138.00	13.80	13.80	84.00	1			0	0.00
62	BEXLEY - OH	Transmission		138.00	39.40	13.80	41.67	0	1		0	0.00
63	BEXLEY - OH	Transmission		40.00	0.00	0.00	0.00			STATCAP	1	10.80
64	BEXLEY - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	2	5.70
65	BIG PRAIRIE - OH	Distribution		69.00	13.09		5.25	1			0	0.00
66	BILLIAR - OH	Distribution		69.00	13.09		18.75	2			0	0.00
67	BIXBY - OH	Transmission		138.00	13.80	13.80	75.00	1			0	0.00
68	BIXBY - OH	Transmission		138.00	34.50	13.80	50.00	0	1		0	0.00
69	BIXBY - OH	Transmission		40.00	13.80		9.38	0	1		0	0.00
70	BIXBY - OH	Transmission		345.00	138.00	35.00	675.00	1			0	0.00
71	BIXBY - OH	Transmission		138.00	13.80		50.00	0	1		0	0.00
72	BIXBY - OH	Transmission		138.00	70.50	36.20	30.00	0	1		0	0.00
73	BIXBY - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	2	6.30
74	BIXBY - OH	Transmission		40.00	14.50		33.00	0	1		0	0.00
75	BIXBY - OH	Transmission		69.00	13.80		22.40	0	1		0	0.00
76	BIXBY - OH	Transmission		138.00	13.80		41.67	1			0	0.00
77	BIXBY - OH	Transmission		23.00	13.09		9.38	0	1		0	0.00
78	BIXBY - OH	Transmission		69.00	4.36		9.38	0	1		0	0.00
79	BIXBY - OH	Transmission		69.00	13.20		22.40	0	1		0	0.00
80	BIXBY - OH	Transmission		34.50	4.00		9.38	0	1		0	0.00
81	BIXBY - OH	Transmission		69.00	13.80		7.00	0	1		0	0.00
82	BIXBY - OH	Transmission		34.50	13.80		6.25	0	1		0	0.00
83	BLACKJACK ROAD - OH	Distribution		69.00	12.00		20.00	1			0	0.00
84	BLACKLICK - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1	4.80
85	BLACKLICK - OH	Distribution		138.00	13.80		50.00	1			0	0.00
86	BLACKLICK - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	1	3.60
87	BLACKLICK - OH	Distribution		138.00	13.80		50.00	0	1		0	0.00
88	BLACKLICK - OH	Distribution		138.00	35.40	13.80	50.00	1			0	0.00
89	BLAIR - OH	Distribution		69.00	13.80		25.00	1			0	0.00
90	BLAIR - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
91	BLENDON - OH	Distribution		138.00	35.40	13.80	100.00	2			0	0.00
92	BLENDON - OH	Distribution		138.00	34.50	13.80	25.00	1			0	0.00
93	BLENDON - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1
94	BLOOM - OH	Distribution		69.00	13.20		9.38	1			0	0.00
95	BLOOM - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	1	2.25
96	BLOOM ROAD - OH	Distribution		69.00	13.09		9.38	1			0	0.00
97	BLOOMVILLE - OH	Distribution		69.00	13.09		4.69	1			0	0.00
98	BLUFFTON (OP) - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1	3.60
99	BLUFFTON (OP) - OH	Distribution		34.50	13.09		10.50	1			0	0.00
100	BOLIVAR - OH	Distribution		138.00	36.20		25.00	1			0	0.00
101	BOLTON - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1
102	BREMEN - OH	Distribution		69.00	13.09		9.38	1			0	0.00
103	BRIDGEPORT - OH	Distribution		69.00	13.09		20.00	1			0	0.00
104	BRIDGEPORT - OH	Distribution		12.00	0.01		0.30	1			0	0.00
105	BRIDGEPORT - OH	Distribution		69.00	4.00		3.00	1			0	0.00
106	BRIDGEVILLE - OH	Distribution		138.00	13.09		20.00	1			0	0.00
107	BRIGGSDALE - OH	Distribution		40.00	13.80		42.40	2			0	0.00
108	BRIGGSDALE - OH	Distribution		13.20	0.00	0.00	0.00			REACTIVE SPECIAL	3
109	BRIGGSDALE - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	1	3.00
110	BROADACRE - OH	Distribution		138.00	13.09		9.37	1			0	0.00
111	BROKEN SWORD - OH	Distribution		69.00	13.09		6.25	1			0	0.00
112	BROOKSIDE (CS) - OH	Distribution		138.00	13.80		100.00	2			0	0.00
113	BROOM ROAD - OH	Distribution		69.00	13.09		20.00	1			0	0.00
114	BROOM ROAD - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
115	BUCKLEY ROAD - OH	Transmission		138.00	69.50	13.09	128.80	1			0	0.00
116	BUCYRUS - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	13.19
117	BUCYRUS - OH	Distribution		69.00	13.09		20.00	1			0	0.00
118	BUCYRUS CENTER - OH	Transmission		138.00	69.50	13.09	75.00	1			0	0.00
119	BUCYRUS CENTER - OH	Transmission		69.00	13.09		20.00	1			0	0.00
120	CADIZ - OH	Distribution		69.00	13.09		10.50	1			0	0.00
121	CAIRO - OH	Distribution		69.00	12.99		3.92	1			0	0.00
122	CALCUTTA - OH	Distribution		69.00	13.09		20.00	1			0	0.00
123	CALDWELL - OH	Transmission		138.00	13.09		20.00	1			0	0.00
124	CALDWELL - OH	Transmission		138.00	34.50		9.37	1			0	0.00
125	CALIFORNIA - OH	Distribution		69.00	13.09		25.00	1			0	0.00
126	CAMBRIDGE - OH	Distribution		34.50	4.00		7.50	1			0	0.00
127	CAMBRIDGE - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1	9.60
128	CAMBRIDGE - OH	Distribution		34.50	12.00		10.50	1			0	0.00
129	CAMP SHERMAN - OH	Distribution		69.00	13.00		2.00	1			0	0.00
130	CAMP SHERMAN - OH	Distribution		69.00	13.09		20.00	1			0	0.00
131	CANAL ROAD - OH	Transmission		138.00	69.00	34.50	84.00	1			0	0.00
132	CANAL ROAD - OH	Transmission		69.00	23.00		12.50	1			0	0.00
133	CANAL STREET - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	3	23.40
134	CANAL STREET - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	3	21.60
135	CANAL STREET - OH	Distribution		138.00	13.80	13.80	252.00	3			0	0.00
136	CAREY SW - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	9.60
137	CARROLLTON - OH	Distribution		138.00	13.09		40.00	2			0	0.00
138	CARROTHERS - OH	Distribution		69.00	13.09		5.25	1			0	0.00
139	CARROTHERS - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.60
140	CENTER STREET - OH	Distribution		69.00	13.09		20.00	1			0	0.00
141	CENTERBURG - OH	Distribution		138.00	35.40	13.80	50.00	1			0	0.00
142	CENTRAL AVENUE (OP) - OH	Distribution		34.50	4.36		9.38	1			0	0.00
143	CENTRAL PORTSMOUTH - OH	Transmission		69.00	7.20		9.38	1			0	0.00
144	CENTRAL PORTSMOUTH - OH	Transmission		138.00	69.00	34.50	130.00	1			0	0.00
145	CHATFIELD - OH	Transmission		138.00	69.50	13.09	75.00	1			0	0.00
146	CHERRY AVENUE - OH	Distribution		69.00	12.00		10.00	2			0	0.00
147	CIRCLEVILLE - OH	Transmission		138.00	69.00	13.20	30.00	1			0	0.00
148	CIRCLEVILLE - OH	Transmission		138.00	13.09		50.00	1			0	0.00
149	CIRCLEVILLE - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	12.00
150	CIRCLEVILLE - OH	Transmission		138.00	13.20		30.00	1			0	0.00
151	CIRCLEVILLE - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	2	7.20
152	CIRCLEVILLE - OH	Transmission		138.00	69.00	13.20	30.00	0	1		0	0.00
153	CITIZENS - OH	Distribution		12.00	0.48		3.00	2			0	0.00
154	CLARK STREET - OH	Distribution		69.00	12.00		56.00	2			0	0.00
155	CLARK STREET - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	2	10.80
156	CLIFTMONT AVENUE - OH	Distribution		69.00	12.00		10.50	1			0	0.00
157	CLINTON - OH	Distribution		138.00	13.80	13.80	168.30	2			0	0.00
158	COAL GROVE - OH	Distribution		69.00	12.00		6.25	1			0	0.00
159	COLERAIN - OH	Distribution		69.00	13.09		9.38	1			0	0.00
160	COLUMBIA (CS) - OH	Distribution		40.00	13.20		15.00	1			0	0.00
161	COLUMBUS GROVE - OH	Distribution		69.00	12.47		8.40	1			0	0.00
162	COLUMBUS GROVE - OH	Distribution		69.00	13.09		2.50	1			0	0.00
163	CONESVILLE - OH	Distribution		69.00	12.00		2.50	1			0	0.00
164	CONESVILLE PLANT - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2	172.80
165	CONESVILLE PLANT - OH	Transmission		138.00	70.73	13.20	10.50	0	1		0	0.00
166	CONESVILLE PLANT - OH	Transmission		345.00	138.00	34.50	675.00	1			0	0.00
167	CONESVILLE PREPARATION PLANT - OH	Distribution		138.00	13.09		22.40	1			0	0.00
168	CONTINENTAL - OH	Distribution		69.00	13.09		7.00	1			0	0.00
169	COOLVILLE (CS) - OH	Distribution		69.00	13.09		9.38	1			0	0.00
170	COOLVILLE (CS) - OH	Distribution		69.00	13.20		10.50	1			0	0.00
171	COOPERMILL - OH	Distribution		69.00	4.00		9.38	1			0	0.00
172	COOPERMILL - OH	Distribution		69.00	13.09		9.38	1			0	0.00
173	COOPERMILL - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.39
174	COPELAND - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1
175	COPELAND - OH	Distribution		69.00	13.20		10.50	1			0	0.00
176	COPPERHEAD - OH	Distribution		34.50	7.20		333.00	1			0	0.00
177	CORNER - OH	Distribution		138.00	13.09		20.00	1			0	0.00
178	CORNERSTONE - OH	Distribution		69.00	13.09		40.00	2			0	0.00
179	CORRIDOR - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	115.20
180	CORRIDOR - OH	Transmission		138.00	34.50	13.80	100.00	2			0	0.00
181	CORRIDOR - OH	Transmission		345.00	138.00	34.50	675.00	1			0	0.00
182	CORWIN - OH	Distribution		138.00	13.09		45.00	2			0	0.00
183	COSHOCTON - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
184	COSHOCTON - OH	Distribution		69.00	12.00		22.40	1			0	0.00
185	COSHOCTON - OH	Distribution		69.00	4.00		8.40	0	1		0	0.00
186	COUNTY HOSPITAL - OH	Distribution		69.00	13.09		5.25	1			0	0.00
187	CRAWFIS COLLEGE - OH	Distribution		69.00	13.09		6.25	1			0	0.00
188	CRESTWOOD - OH	Distribution		34.50	13.09		40.00	2			0	0.00
189	CRIDERSVILLE - OH	Distribution		69.00	13.09		7.00	1			0	0.00
190	CROOKSVILLE - OH	Transmission		138.00	70.50	13.09	130.00	1			0	0.00
191	CROOKSVILLE - OH	Transmission		69.00	13.09		20.00	1			0	0.00
192	CROOKSVILLE - OH	Transmission		69.00	4.00		9.38	1			0	0.00
193	CROTON - OH	Distribution		34.50	13.80		6.25	1			0	0.00
194	CRYSTAL PARK - OH	Distribution		69.00	4.00		6.25	1			0	0.00
195	DAVIDSON (CS) - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	2	14.40
196	DAVIDSON (CS) - OH	Distribution		138.00	13.80		91.67	2			0	0.00
197	DAVON - OH	Distribution		69.00	13.20		11.20	1			0	0.00
198	DECLIFF - OH	Distribution		34.50	13.09		6.25	1			0	0.00
199	DELANO - OH	Distribution		13.20	4.00		5.00	0	1		0	0.00
200	DELANO - OH	Distribution		138.00	69.00	13.20	33.60	1			0	0.00
201	DELANO - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	28.80
202	DELAWARE (CSP) - OH	Transmission		138.00	13.80		41.67	1			0	0.00
203	DELAWARE (CSP) - OH	Transmission		138.00	40.00	13.80	25.00	1			0	0.00
204	DELAWARE (CSP) - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	2	10.80
205	DELAWARE (CSP) - OH	Transmission		138.00	34.50	13.80	25.00	1			0	0.00
206	DELAWARE (CSP) - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	6.00
207	DELAWARE (CSP) - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	19.20
208	DELAWARE (CSP) - OH	Transmission		138.00	69.00	13.09	78.00	1			0	0.00
209	DELAWARE (CSP) - OH	Transmission		138.00	35.40	13.80	30.00	1			0	0.00
210	DELPHOS - OH	Distribution		69.00	13.09		19.88	2			0	0.00
211	DENNISON - OH	Transmission		34.50	4.00		6.00	2			0	0.00
212	DENNISON - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
213	DENNISON - OH	Transmission		69.00	36.20		20.00	1			0	0.00
214	DERWENT - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
215	DERWENT - OH	Distribution		69.00	13.20		9.38	1			0	0.00
216	DIAMOND STREET - OH	Transmission		69.00	23.00		7.50	1			0	0.00
217	DILLONVALE - OH	Distribution		69.00	13.09		7.50	1			0	0.00
218	DOGWOOD RIDGE - OH	Distribution		138.00	13.09		20.00	1			0	0.00
219	DON MARQUIS (OP-CS) (OVEC) - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2	115.20
220	DON MARQUIS (OP-CS) (OVEC) - OH	Transmission		345.00						REACTOR	3	99.90
221	DON MARQUIS (OP-CS) (OVEC) - OH	Transmission		345.00	137.50	13.80	720.00	2			0	0.00
222	DOW CHEMICAL-HANGING ROCK - OH	Distribution		69.00	12.00		12.50	2			0	0.00
223	DOW CHEMICAL-HEBRON - OH	Distribution		69.00	12.00		9.36	2			0	0.00
224	DRESDEN - OH	Distribution		69.00	12.00		10.50	1			0	0.00
225	DUBLIN(CS) - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	3	13.50
226	DUBLIN(CS) - OH	Distribution		138.00	13.80		150.00	3			0	0.00
227	DUCK CREEK - OH	Distribution		138.00	13.09		22.40	1			0	0.00
228	DUEBER AVENUE - OH	Distribution		69.00	4.00		5.00	1			0	0.00
229	DUNKIRK (OP) - OH	Transmission		69.00	13.09		5.25	1			0	0.00
230	DUNKIRK (OP) - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	16.20
231	EAST AMSTERDAM - OH	Transmission		138.00	70.50	36.20	90.00	1			0	0.00
232	EAST ANTWERP - OH	Distribution		69.00	13.09		6.25	1			0	0.00
233	EAST ANTWERP - OH	Distribution		12.00	4.16		2.50	3			0	0.00
234	EAST BROAD STREET - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	4	12.30
235	EAST BROAD STREET - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	72.00
236	EAST BROAD STREET - OH	Transmission		138.00	13.80		30.00	1			0	0.00
237	EAST BROAD STREET - OH	Transmission		40.00	0.00	0.00	0.00			STATCAP	1	10.80
238	EAST BROAD STREET - OH	Transmission		138.00	40.00	13.80	83.34	2			0	0.00
239	EAST BROAD STREET - OH	Transmission		138.00	39.40	13.80	41.67	0	1		0	0.00
240	EAST BUCYRUS - OH	Distribution		69.00	13.09		9.37	1			0	0.00
241	EAST CAMBRIDGE - OH	Transmission		69.00	34.50		37.30	1			0	0.00
242	EAST CAMBRIDGE - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	21.60
243	EAST DELPHOS - OH	Distribution		69.00	13.09		7.00	1			0	0.00
244	EAST DOVER - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.39
245	EAST DOVER - OH	Distribution		69.00	13.09		9.38	1			0	0.00
246	EAST END FOSTORIA - OH	Distribution		69.00	4.36		9.38	1			0	0.00
247	EAST FREMONT - OH	Distribution		69.00	4.36		9.37	1			0	0.00
248	EAST FREMONT - OH	Distribution		69.00	13.09		10.50	1			0	0.00
249	EAST LANCASTER - OH	Distribution		69.00	12.00		14.38	2			0	0.00
250	EAST LANCASTER - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	16.20
251	EAST LEIPSIC - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	28.80
252	EAST LEIPSIC - OH	Transmission		138.00	69.50	7.20	50.00	1			0	0.00
253	EAST LEIPSIC - OH	Transmission		69.00	36.20		25.00	1			0	0.00
254	EAST LIMA - OH	Transmission		345.00	137.50	13.80	450.00	1			0	0.00
255	EAST LIMA - OH	Transmission		345.00	137.50	13.20	450.00	1			0	0.00
256	EAST LIMA - OH	Transmission		138.00	69.50	13.09	60.00	1			0	0.00
257	EAST LIVERPOOL - OH	Transmission		138.00	70.50	13.09	90.00	1			0	0.00
258	EAST LIVERPOOL - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
259	EAST LIVERPOOL-2ND STREET - OH	Distribution		69.00	4.00		8.00	2			0	0.00
260	EAST LIVERPOOL-E. END - OH	Distribution		69.00	4.00		4.69	1			0	0.00
261	EAST LOGAN - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
262	EAST MT CORY - OH	Distribution		34.50	13.09		3.13	1			0	0.00
263	EAST NEW CONCORD - OH	Distribution		138.00	13.09		9.38	1			0	0.00
264	EAST NEWARK - OH	Distribution		69.00	4.00		6.87	2			0	0.00
265	EAST NEWARK - OH	Distribution		69.00	13.09		25.00	1			0	0.00
266	EAST OTTAWA - OH	Transmission		69.00	13.09		20.00	1			0	0.00
267	EAST OTTAWA - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	19.79
268	EAST POINTE - OH	Distribution		138.00	13.09		20.00	1			0	0.00
269	EAST PROCTORVILLE - OH	Distribution		138.00	34.50		55.00	2			0	0.00
270	EAST SIDE (LIMA) - OH	Distribution		138.00	36.20		25.00	1			0	0.00
271	EAST SPRINGFIELD - OH	Distribution		69.00	4.00		3.75	1			0	0.00
272	EAST TIFFIN - OH	Distribution		69.00	13.09		10.50	1			0	0.00
273	EAST UNION - OH	Distribution		69.00	13.09		20.00	1			0	0.00
274	EAST WILLARD - OH	Distribution		69.00	13.09		10.50	1			0	0.00
275	EAST WOOSTER - OH	Transmission		138.00	13.09		20.00	1			0	0.00
276	EAST WOOSTER - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	43.20
277	EAST WOOSTER - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
278	EAST WOOSTER - OH	Transmission		138.00	24.14		25.00	0	1		0	0.00
279	EAST WOOSTER - OH	Transmission		138.00	69.50	13.09	84.00	1			0	0.00
280	EAST ZANESVILLE - OH	Transmission		138.00	69.00	12.00	50.00	1			0	0.00
281	EAST ZANESVILLE - OH	Transmission		138.00	69.00	13.00	50.00	1			0	0.00
282	EASTON STREET - OH	Distribution		69.00	13.09		42.40	2			0	0.00
283	EASTOWN ROAD - OH	Distribution		138.00	13.09		22.40	1			0	0.00
284	EASTOWN ROAD - OH	Distribution		138.00	13.20		20.00	1			0	0.00
285	EIGHTEEN STREET HEIGHTS - OH	Distribution		69.00	12.00		7.00	1			0	0.00
286	EIGHTEEN STREET HEIGHTS - OH	Distribution		69.00	13.09		9.38	1			0	0.00
287	ELIZABETH STREET - OH	Distribution		34.50	4.36		18.75	2			0	0.00
288	ELIZABETH STREET - OH	Distribution		4.16	0.00	0.00	0.00			AIR CORE REACTOR	6	0.00
289	ELK - OH	Distribution		138.00	13.00		50.00	2			0	0.00
290	ETNA - OH	Distribution		69.00	13.09		5.60	1			0	0.00
291	ETNA - OH	Distribution		69.00	34.50		25.00	1			0	0.00
292	ETNA ROAD - OH	Distribution		40.00	13.80	4.30	41.80	2			0	0.00
293	ETNA ROAD - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	2	9.60
294	ETNA ROAD - OH	Distribution		40.00	13.80		22.00	1			0	0.00
295	FAIRCREST STREET - OH	Distribution		138.00	13.09		22.40	1			0	0.00
296	FAIRDALE - OH	Distribution		69.00	12.00		10.50	1			0	0.00
297	FAIRFIELD - OH	Distribution		69.00	4.36		10.50	1			0	0.00
298	FIFTH AVENUE - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	1	2.70
299	FIFTH AVENUE - OH	Distribution		138.00	39.40	13.80	41.67	1			0	0.00
300	FINDLAY - OH	Distribution		34.50	13.09		17.50	2			0	0.00
301	FINDLAY - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1	13.50
302	FINDLAY CENTER - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	14.40
303	FINDLAY CENTER - OH	Transmission		138.00	69.50	35.00	75.00	1			0	0.00
304	FINDLAY RESERVOIR#1 - OH	Distribution		34.50	2.40		0.50	3			0	0.00
305	FINDLAY RESERVOIR#2 - OH	Distribution		34.50	2.50		1.00	1			0	0.00
306	FONTAINE - OH	Distribution		69.00	4.36		3.00	1			0	0.00
307	FOREST (OP) - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.39
308	FOREST (OP) - OH	Transmission		69.00	13.09		12.50	2			0	0.00
309	FRAZEYSBURG - OH	Distribution		138.00	13.09		8.40	1			0	0.00
310	FREDERICKTOWN - OH	Distribution		69.00	13.09		20.00	1			0	0.00
311	FREMONT (OP) - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	19.79
312	FREMONT (OP) - OH	Transmission		138.00	69.50	13.09	130.00	1			0	0.00
313	FREMONT CENTER - OH	Transmission		138.00	70.50	13.09	130.00	1			0	0.00
314	FREMONT CENTER - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	43.20
315	FREMONT CENTER - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	13.19
316	FREMONT CENTER - OH	Transmission		69.00	13.09		6.25	1			0	0.00
317	FULTON (OP) - OH	Distribution		138.00	13.09		10.00	1			0	0.00
318	GAHANNA - OH	Distribution		138.00	13.80		50.00	1			0	0.00
319	GAHANNA - OH	Distribution		138.00	34.50	13.80	53.00	2			0	0.00
320	GAHANNA - OH	Distribution		138.00	35.40	13.80	50.00	1			0	0.00
321	GAHANNA - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	2	6.30
322	GALLOWAY ROAD - OH	Distribution		69.00	13.80		62.00	3			0	0.00
323	GALLOWAY ROAD - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	2	6.74
324	GAMBIER - OH	Distribution		69.00	12.00		20.00	1			0	0.00
325	GAVIN 138KV - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2	115.18
326	GAVIN 138KV - OH	Transmission		138.00	69.00	12.00	130.00	1			0	0.00
327	GAY STREET - OH	Distribution		138.00	13.80	13.80	252.00	3			0	0.00
328	GAY STREET - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	6	37.77
329	GENOA - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2
330	GENOA - OH	Transmission		138.00	34.50	13.80	50.00	1			0	0.00
331	GENOA - OH	Transmission		138.00	69.00	12.00	130.00	1			0	0.00
332	GENOA - OH	Transmission		138.00	70.50	13.80	90.00	1			0	0.00
333	GENOA - OH	Transmission		138.00	34.50	13.80	42.00	1			0	0.00
334	GENOA - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	2
335	GEORGES RUN - OH	Distribution		69.00	13.09		7.00	1			0	0.00
336	GINGER - OH	Distribution		69.00	12.47		6.25	0	1		0	0.00
337	GINGER - OH	Distribution		69.00	13.09		9.38	1			0	0.00
338	GLASSROCK - OH	Distribution		69.00	13.09		9.38	1			0	0.00
339	GLENMONT - OH	Distribution		34.50	12.00		1.50	1			0	0.00
340	GLENMOOR - OH	Distribution		69.00	12.00		20.00	1			0	0.00
341	GLENWOOD (OP) - OH	Distribution		69.00	12.00		4.20	1			0	0.00
342	GLOUSTER - OH	Distribution		13.20	4.00		3.00	1			0	0.00
343	GORSUCH - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2	86.40
344	GRANVILLE - OH	Distribution		69.00	12.00		22.40	1			0	0.00
345	GRANVILLE - OH	Distribution		69.00	13.09		25.00	1			0	0.00
346	GREELY - OH	Distribution		69.00	4.36		6.25	1			0	0.00
347	GREELY - OH	Distribution		69.00	13.09		20.00	1			0	0.00
348	GREENLAWN - OH	Transmission		138.00	69.50	13.09	75.00	1			0	0.00
349	GREENWICH - OH	Distribution		69.00	2.52		3.75	1			0	0.00
350	GREER - OH	Transmission		34.50	12.90		1.50	0	1		0	0.00
351	GREER - OH	Transmission		34.50	12.00		5.63	3			0	0.00
352	GREER - OH	Transmission		69.00	35.00		35.00	1			0	0.00
353	GROVES ROAD - OH	Transmission		138.00	13.80	13.80	168.00	2			0	0.00
354	GROVES ROAD - OH	Transmission		40.00	13.80		22.00	0	1		0	0.00
355	GROVES ROAD - OH	Transmission		138.00	40.00	13.80	74.70	1			0	0.00
356	GROVES ROAD - OH	Transmission		138.00	13.80		50.00	1			0	0.00
357	GROVES ROAD - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1
358	GROVES ROAD - OH	Transmission		13.80	0.00	0.00	0.00			STATCAP	5	13.77
359	GROVES ROAD - OH	Transmission		46.00	0.00	0.00	0.00			STATCAP	1	10.80
360	GROVES ROAD - OH	Transmission		138.00	13.80	13.80	83.30	0	1		0	0.00
361	HALL - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	2	14.40
362	HALL - OH	Distribution		138.00	13.80		91.67	2			0	0.00
363	HAMMONDSVILLE - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
364	HAMMONDSVILLE - OH	Transmission		69.00	4.36		6.25	1			0	0.00
365	HANERS - OH	Distribution		69.00	13.09		25.00	1			0	0.00
366	HANERS - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	3.59
367	HANGING ROCK - OH	Transmission		138.00	69.00	34.50	56.00	1			0	0.00
368	HARMAR - OH	Distribution		23.00	4.36		10.94	2			0	0.00
369	HARMAR HILL - OH	Distribution		138.00	13.09		20.00	1			0	0.00
370	HARPSTER - OH	Transmission		69.00	35.00		22.40	1			0	0.00
371	HARPSTER PUMPING - OH	Distribution		69.00	4.30		3.00	1			0	0.00
372	HARRISON - OH	Transmission		138.00	69.00	13.80	56.00	1			0	0.00
373	HARRISON - OH	Transmission		138.00	39.40	13.80	41.67	0	1		0	0.00
374	HAVILAND - OH	Transmission		138.00	69.50	13.09	84.00	1			0	0.00
375	HAVILAND - OH	Transmission		138.00	70.50	13.09	90.00	1			0	0.00
376	HEATH - OH	Transmission		138.00	138.00	13.80	50.00	1			0	0.00
377	HEATH - OH	Transmission		138.00	69.00	12.00	128.80	1			0	0.00
378	HEBRON - OH	Distribution		34.50	12.00		6.25	1			0	0.00
379	HEMLOCK - OH	Distribution		69.00	13.09		7.50	1			0	0.00
380	HESS STREET - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	62.40
381	HESS STREET - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	2	12.60
382	HESS STREET - OH	Distribution		138.00	13.80		166.68	4			0	0.00
383	HIGH STREET - OH	Distribution		69.00	12.00		8.40	1			0	0.00
384	HIGHLAND (CS) - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	2	5.40
385	HIGHLAND (CS) - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	13.19
386	HIGHLAND (CS) - OH	Distribution		69.00	13.20		44.90	2			0	0.00
387	HIGHLAND AVENUE - OH	Distribution		69.00	13.09		20.00	1			0	0.00
388	HIGHLAND TERRACE - OH	Distribution		69.00	13.09		10.50	1			0	0.00
389	HILLIARD - OH	Distribution		69.00	13.80		69.80	3			0	0.00
390	HILLIARD - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	2	6.75
391	HILLIARD - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.60
392	HILLNDALE - OH	Distribution		69.00	13.09		9.38	1			0	0.00
393	HILLVIEW DRIVE - OH	Distribution		138.00	13.09		8.40	1			0	0.00
394	HILLVIEW DRIVE - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	52.80
395	HOCKING - OH	Transmission		138.00	69.00	12.00	90.00	1			0	0.00
396	HOLRAN - OH	Distribution		69.00	13.09		3.13	1			0	0.00
397	HOLRAN - OH	Distribution		69.00	4.16		6.25	1			0	0.00
398	HOPEDALE - OH	Distribution		69.00	12.00		3.92	1			0	0.00
399	HOVER PARK - OH	Distribution		34.50	2.50		4.50	3			0	0.00
400	HOWARD - OH	Transmission		138.00	69.50	11.00	90.00	1			0	0.00
401	HOWARD - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	12.00
402	HOWARD - OH	Transmission		69.00	13.09		9.37	1			0	0.00
403	HOWARD - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2	115.18
404	HUGHES STREET - OH	Distribution		69.00	4.36		10.50	1			0	0.00
405	HUNTLEY - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	4	14.36
406	HUNTLEY - OH	Transmission		138.00	13.80		83.00	2			0	0.00
407	HUNTLEY - OH	Transmission		138.00	69.00	13.80	50.00	0	1		0	0.00
408	HUNTLEY - OH	Transmission		138.00	69.50	13.09	84.00	1			0	0.00
409	HUNTLEY - OH	Transmission		69.00	13.80		30.00	1			0	0.00
410	HUNTLEY - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	52.79
411	HYATT - OH	Transmission		138.00	35.40	13.80	50.00	1			0	0.00
412	ISLETA - OH	Distribution		34.50	13.09		3.75	1			0	0.00
413	JEFFERSON (CS) - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	2.70
414	JEFFERSON (CS) - OH	Distribution		69.00	13.20		21.00	2			0	0.00
415	JOHNSTOWN - OH	Distribution		34.50	13.80		9.38	1			0	0.00
416	JONES CITY - OH	Distribution		34.50	13.00		1.88	1			0	0.00
417	JUG STREET - OH	Transmission		345.00	137.50	13.80	270.00	1			0	0.00
418	JUG STREET - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1
419	JUG STREET - OH	Transmission		138.00	35.40	13.80	50.00	1			0	0.00
420	KAISER JUNCTION SW - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	27.00
421	KALIDA - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	18.00
422	KALIDA - OH	Transmission		69.00	34.50		20.00	1			0	0.00
423	KALIDA - OH	Transmission		69.00	13.09		14.63	2			0	0.00
424	KAMMER 400 YARD - WV	Transmission		765.00	345.00	34.50	1000.00	2			0	0.00
425	KARL ROAD - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	3.60
426	KARL ROAD - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	5	25.20
427	KARL ROAD - OH	Distribution		138.00	13.80	13.80	251.30	3			0	0.00
428	KENNY - OH	Distribution		138.00	13.80	13.80	168.00	2			0	0.00
429	KENNY - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	2	9.60
430	KENTON - OH	Distribution		69.00	36.20		60.00	2			0	0.00
431	KENTON - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.39
432	KILLBUCK - OH	Distribution		34.50	7.20		1.88	0	1		0	0.00
433	KIMBERLY - OH	Distribution		138.00	13.09		40.00	2			0	0.00
434	KIMBOLTON - OH	Distribution		69.00	13.09		9.38	1			0	0.00
435	KIRK - OH	Transmission		138.00	69.00	34.00	90.00	1			0	0.00
436	KIRK - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	3.59
437	KOSSUTH - OH	Distribution		69.00	13.09		5.25	1			0	0.00
438	LAFAYETTE (OP) - OH	Distribution		69.00	13.09		7.00	1			0	0.00
439	LANCASTER - OH	Distribution		69.00	4.00		18.75	3			0	0.00
440	LANCASTER - OH	Distribution		69.00	12.00		22.40	1			0	0.00
441	LANCASTER - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	27.00
442	LANCASTER JUNCTION - OH	Distribution		69.00	13.09		25.00	1			0	0.00
443	LANCASTER JUNCTION - OH	Distribution		69.00	12.00		22.40	1			0	0.00
444	LATTY - OH	Distribution		69.00	13.09		3.75	1			0	0.00
445	LAYMAN - OH	Distribution		138.00	13.09		20.00	1			0	0.00
446	LAZELLE - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	3.59
447	LAZELLE - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.60
448	LAZELLE - OH	Distribution		69.00	13.80		44.80	2			0	0.00
449	LEE - OH	Distribution		69.00	12.00		10.50	1			0	0.00
450	LEIPSIC - OH	Distribution		69.00	13.09		14.63	2			0	0.00
451	LEXINGTON - OH	Distribution		69.00	13.09		6.25	1			0	0.00
452	LICK - OH	Transmission		138.00	69.00	13.20	90.00	3			0	0.00
453	LICK - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	43.20
454	LINCOLN STREET - OH	Distribution		69.00	13.80		60.00	2			0	0.00
455	LINDEN AVENUE - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
456	LINDEN AVENUE - OH	Distribution		69.00	4.00		10.50	1			0	0.00
457	LINDEN AVENUE - OH	Distribution		69.00	13.09		25.00	1			0	0.00
458	LINWORTH - OH	Distribution		138.00	13.80		41.67	1			0	0.00
459	LINWORTH - OH	Distribution		138.00	40.00	13.80	41.67	1			0	0.00
460	LINWORTH - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	2	7.18
461	LIVINGSTON AVENUE - OH	Distribution		40.00	13.00		44.00	2			0	0.00
462	LOCK SEVENTEEN - OH	Distribution		69.00	13.00		10.50	1			0	0.00
463	LOCK SEVENTEEN - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.60
464	LOCKWOOD ROAD - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	43.20
465	LOUISVILLE - OH	Distribution		69.00	12.00		20.00	1			0	0.00
466	MADISON (CS) - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	7.19
467	MADISON (CS) - OH	Distribution		69.00	13.80		20.00	1			0	0.00
468	MADISONBURG - OH	Distribution		69.00	13.09		20.00	1			0	0.00
469	MAHONING ROAD - OH	Distribution		69.00	12.00		22.40	1			0	0.00
470	MALISZEWSKI - OH	Transmission		138.00	0.00	0.00	0.00			AIR CORE REACTOR	3
471	MALISZEWSKI - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	7.20
472	MALISZEWSKI - OH	Transmission		138.00	35.40	13.80	50.00	0	1		0	0.00
473	MALISZEWSKI - OH	Transmission		765.00	138.00	13.80	250.00	0	1		0	0.00
474	MALISZEWSKI - OH	Transmission		765.00	138.00	13.80	250.00	3			0	0.00
475	MALISZEWSKI - OH	Transmission		138.00	34.50	13.80	50.00	1			0	0.00
476	MAPLE GROVE - OH	Distribution		69.00	13.09		9.37	1			0	0.00
477	MARION ROAD - OH	Transmission		138.00	40.00	13.00	83.33	1			0	0.00
478	MARION ROAD - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	3	10.58
479	MARION ROAD - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	52.79
480	MARION ROAD - OH	Transmission		138.00	39.40	13.80	166.66	2			0	0.00
481	MARION ROAD - OH	Transmission		40.00	13.00		12.50	0	1		0	0.00
482	MARK CENTER SW - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	12.00
483	MARTINS FERRY - OH	Distribution		69.00	12.00		10.50	1			0	0.00
484	MARTINSBURG ROAD - OH	Distribution		69.00	13.09		20.00	1			0	0.00
485	MARYSVILLE - OH	Transmission		765.00						REACTOR	1	100.00
486	MARYSVILLE - OH	Transmission		765.00	345.00	34.50	750.00	0	1		0	0.00
487	MAULE ROAD - OH	Distribution		69.00	13.09		20.00	1			0	0.00
488	MCCOMB (CS) - OH	Transmission		138.00	39.40	13.80	100.00	2			0	0.00
489	MCCOMB (CS) - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	86.40
490	MCCOMB (CS) - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	1	3.59
491	MCCOMB (OP) - OH	Distribution		34.50	13.09		6.25	1			0	0.00
492	MCDERMOTT - OH	Distribution		34.50	13.80		3.00	1			0	0.00
493	MEIGS (CS) - OH	Distribution		69.00	13.09		9.38	1			0	0.00
494	MEIGS (CS) - OH	Distribution		69.00	13.00		10.50	1			0	0.00
495	MEIGS (CS) - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	2	9.60
496	MEIGS (CS) - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	3.60
497	MEIGS NO. 1 - OH	Distribution		138.00	34.50		33.40	2			0	0.00
498	MEMORIAL DRIVE - OH	Distribution		69.00	13.09		22.40	1			0	0.00
499	MIFFLIN - OH	Distribution		138.00	13.80		150.00	3			0	0.00
500	MIFFLIN - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1
501	MIFFLIN - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	3.15
502	MILES AVENUE - OH	Distribution		138.00	13.09		20.00	1			0	0.00
503	MILL CREEK (CSP) - OH	Distribution		138.00	13.09		50.00	2			0	0.00
504	MILL CREEK (CSP) - OH	Distribution		138.00	24.80		40.00	2			0	0.00
505	MILL STREET - OH	Distribution		69.00	12.00		10.50	1			0	0.00
506	MILLBROOK PARK - OH	Transmission		138.00	13.09		12.00	1			0	0.00
507	MILLBROOK PARK - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	52.80
508	MILLBROOK PARK - OH	Transmission		138.00	69.00	34.50	75.00	1			0	0.00
509	MILLERSBURG - OH	Distribution		34.50	4.33		2.00	1			0	0.00
510	MILLERSBURG - OH	Distribution		34.50	4.36		2.30	1			0	0.00
511	MILLWOOD - OH	Distribution		138.00	13.09		12.00	1			0	0.00
512	MINERVA - OH	Distribution		69.00	13.09		20.00	1			0	0.00
513	MINFORD - OH	Distribution		69.00	12.00		10.50	1			0	0.00
514	MINK - OH	Distribution		138.00	35.40	13.80	30.00	1			0	0.00
515	MONROE STREET - OH	Distribution		69.00	12.00		20.00	1			0	0.00
516	MORSE ROAD - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	72.00
517	MORSE ROAD - OH	Distribution		138.00	13.80	13.80	242.30	3			0	0.00
518	MORSE ROAD - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	5	36.00
519	MOUND STREET - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	2	7.18
520	MOUND STREET - OH	Distribution		138.00	13.80	13.80	168.00	2			0	0.00
521	MOUNT STERLING - OH	Distribution		69.00	12.00		5.25	1			0	0.00
522	MOUNT VERNON (OP) - OH	Distribution		69.00	4.00		9.36	2			0	0.00
523	MOUNT VERNON (OP) - OH	Distribution		69.00	12.00		10.50	1			0	0.00
524	MUNGEN - OH	Distribution		34.50	13.00		5.00	1			0	0.00
525	MUSKINGUM RIVER 138KV - OH	Transmission		138.00	69.00	13.09	84.00	1			0	0.00
526	NEELYSVILLE - OH	Distribution		69.00	13.09		9.38	1			0	0.00
527	NEFFS - OH	Distribution		69.00	12.00		4.68	1			0	0.00
528	NEGLEY - OH	Distribution		138.00	13.09		20.00	1			0	0.00
529	NEW LEXINGTON - OH	Distribution		69.00	13.09		20.00	1			0	0.00
530	NEW LIBERTY - OH	Transmission		138.00	13.09		20.00	1			0	0.00
531	NEW LIBERTY - OH	Transmission		138.00	70.50	36.20	90.00	1			0	0.00
532	NEW LIBERTY - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	43.20
533	NEW LIBERTY - OH	Transmission		138.00	34.50		60.00	2			0	0.00
534	NEW LIBERTY - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	9.60
535	NEW MATAMORAS - OH	Distribution		23.00	13.09		6.25	1			0	0.00
536	NEW PHILADELPHIA - OH	Distribution		69.00	36.20		40.00	2			0	0.00
537	NEW PHILADELPHIA - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.39
538	NEWARK - OH	Distribution		69.00	4.36		14.00	2			0	0.00
539	NEWARK - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
540	NEWARK CENTER - OH	Transmission		138.00	69.00	12.00	128.00	1			0	0.00
541	NEWCOMERSTOWN - OH	Transmission		69.00	34.50	12.00	39.00	1			0	0.00
542	NEWCOMERSTOWN - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
543	NOBLE CORRECTIONAL - OH	Distribution		34.50	12.00		4.20	1			0	0.00
544	NORTH BALTIMORE - OH	Distribution		34.50	13.09		20.00	1			0	0.00
545	NORTH BALTIMORE - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1	7.20
546	NORTH BELLVILLE - OH	Transmission		138.00	69.50	13.09	56.00	1			0	0.00
547	NORTH BELLVILLE - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	10.80
548	NORTH BLUFFTON - OH	Distribution		69.00	13.00		1.50	1			0	0.00
549	NORTH BLUFFTON - OH	Distribution		7.62	0.28		1.00	3			0	0.00
550	NORTH BUCYRUS - OH	Distribution		69.00	4.36		6.25	1			0	0.00
551	NORTH CAMBRIDGE - OH	Distribution		69.00	4.36		7.50	1			0	0.00
552	NORTH CAMBRIDGE - OH	Distribution		69.00	13.09		7.50	1			0	0.00
553	NORTH CANTON - OH	Distribution		69.00	13.09		25.00	1			0	0.00
554	NORTH COSHOCTON - OH	Transmission		69.00	12.00		22.40	1			0	0.00
555	NORTH COSHOCTON - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	18.00
556	NORTH COSHOCTON - OH	Transmission		69.00	34.50	12.00	39.00	1			0	0.00
557	NORTH CROWN CITY - OH	Transmission		138.00	13.00		7.50	2			0	0.00
558	NORTH CROWN CITY - OH	Transmission		138.00	13.09		7.50	2			0	0.00
559	NORTH DELPHOS - OH	Transmission		138.00	70.50	36.20	90.00	1			0	0.00
560	NORTH DELPHOS - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	18.00
561	NORTH END FOSTORIA - OH	Distribution		69.00	13.09		15.62	2			0	0.00
562	NORTH FINDLAY - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	15.30
563	NORTH FINDLAY - OH	Transmission		138.00	35.00		90.00	1			0	0.00
564	NORTH FINDLAY - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1
565	NORTH FINDLAY - OH	Transmission		138.00	69.50	35.00	84.00	1			0	0.00
566	NORTH FINDLAY - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	43.20
567	NORTH FREDERICKSBURG - OH	Distribution		69.00	12.00		7.00	1			0	0.00
568	NORTH FREMONT - OH	Distribution		69.00	13.09		20.00	1			0	0.00
569	NORTH HEBRON - OH	Distribution		69.00	34.50		20.00	1			0	0.00
570	NORTH HICKSVILLE - OH	Distribution		69.00	13.09		15.63	2			0	0.00
571	NORTH IRONTON - OH	Distribution		69.00	13.09		9.38	1			0	0.00
572	NORTH LEIPSIC - OH	Distribution		69.00	13.09		20.00	1			0	0.00
573	NORTH LEXINGTON - OH	Distribution		138.00	13.00		20.00	1			0	0.00
574	NORTH LOGAN - OH	Distribution		69.00	4.00		6.00	1			0	0.00
575	NORTH MCCONNELSVILLE - OH	Distribution		69.00	13.09		9.38	1			0	0.00
576	NORTH MIDDLEPOINT - OH	Distribution		69.00	13.09		5.25	1			0	0.00
577	NORTH MOUNT VERNON - OH	Distribution		69.00	4.00		9.37	1			0	0.00
578	NORTH MUSKINGUM - OH	Transmission		138.00	69.00	12.00	50.00	1			0	0.00
579	NORTH NEWARK - OH	Transmission		138.00	13.09		25.00	1			0	0.00
580	NORTH NEWARK - OH	Transmission		138.00	69.00	4.00	80.00	2			0	0.00
581	NORTH NEWARK - OH	Transmission		69.00	4.00		3.12	1			0	0.00
582	NORTH NEWARK - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	12.00
583	NORTH NEWARK - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	57.60
584	NORTH SPENCERVILLE - OH	Distribution		69.00	13.09		20.00	1			0	0.00
585	NORTH STRASBURG - OH	Distribution		138.00	4.33	0.00	2.50	1			0	0.00
586	NORTH UPPER SANDUSKY - OH	Distribution		69.00	13.09		20.00	1			0	0.00
587	NORTH WALDO - OH	Transmission		138.00	69.00	7.20	40.00	1			0	0.00
588	NORTH WALDO - OH	Transmission		69.00	13.09		7.00	1			0	0.00
589	NORTH WELLSVILLE - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	13.19
590	NORTH WELLSVILLE - OH	Distribution		69.00	12.00		10.50	1			0	0.00
591	NORTH WILLARD - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	13.19
592	NORTH WILLARD - OH	Distribution		69.00	13.09		20.00	1			0	0.00
593	NORTH WOODCOCK - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	4.80
594	NORTH WOODCOCK - OH	Transmission		138.00	69.50	35.50	50.00	1			0	0.00
595	NORTH WOOSTER - OH	Distribution		69.00	12.00		10.50	1			0	0.00
596	NORTH ZANESVILLE - OH	Distribution		138.00	13.09		47.40	2			0	0.00
597	NORTHWEST LIMA - OH	Distribution		138.00	13.09		20.00	1			0	0.00
598	NORVAL PARK - OH	Distribution		69.00	4.00		10.50	1			0	0.00
599	OAKLAND - OH	Distribution		69.00	12.00		12.00	2			0	0.00
600	OAKLAND - OH	Distribution		69.00			12.00	2			0	0.00
601	OAKWOOD ROAD - OH	Distribution		69.00	12.00		20.00	1			0	0.00
602	OERTELS CORNERS - OH	Distribution		69.00	12.00		22.40	1			0	0.00
603	OHIO CENTRAL - OH	Transmission		138.00	69.00	12.00	56.00	0	1		0	0.00
604	OHIO CENTRAL - OH	Transmission		138.00	69.00	13.09	78.00	0	1		0	0.00
605	OHIO CENTRAL - OH	Transmission		69.00	34.50		30.00	0	1		0	0.00
606	OHIO CENTRAL - OH	Transmission		69.00	4.00		4.25	0	1		0	0.00
607	OHIO CENTRAL - OH	Transmission		34.50	13.09		5.00	0	1		0	0.00
608	OHIO CENTRAL - OH	Transmission		138.00	34.50		25.00	0	1		0	0.00
609	OHIO CITY - OH	Distribution		34.50	13.09		4.69	1			0	0.00
610	OSU - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	1	7.20
611	OSU - OH	Distribution		138.00	13.80		50.00	1			0	0.00
612	OTTOVILLE - OH	Distribution		69.00	13.09		4.68	1			0	0.00
613	OTTOVILLE - OH	Distribution		69.00	12.47		4.69	1			0	0.00
614	OTWAY - OH	Distribution		34.50	12.00		7.50	1			0	0.00
615	OWENS CORNING SW - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	27.00
616	PACKARD - OH	Distribution		138.00	13.20		20.00	1			0	0.00
617	PANDORA - OH	Distribution		69.00	13.09		9.38	1			0	0.00
618	PARK - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	1	2.70
619	PARK - OH	Distribution		69.00	13.80		33.60	1			0	0.00
620	PARSONS - OH	Distribution		40.00	13.80		40.00	2			0	0.00
621	PARSONS - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	2	6.30
622	PAULDING - OH	Distribution		69.00	13.09		20.00	1			0	0.00
623	PAULDING - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
624	PAYNE - OH	Distribution		69.00	13.09		7.00	1			0	0.00
625	PEACH MOUNT - OH	Distribution		13.20	4.00		6.25	1			0	0.00
626	PEACH MOUNT - OH	Distribution		34.50	12.00		6.00	1			0	0.00
627	PEKIN - OH	Transmission		69.00	13.09		5.25	1			0	0.00
628	PEKIN - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	9.60
629	PENNSVILLE - OH	Distribution		69.00	13.09		6.25	1			0	0.00
630	PITTSBURGH AVENUE - OH	Distribution		69.00	13.09		11.20	2			0	0.00
631	PLEASANT GROVE - OH	Distribution		69.00	13.09		6.25	1			0	0.00
632	PLEASANT STREET - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	10.80
633	PLEASANT STREET - OH	Transmission		69.00	13.09		25.00	1			0	0.00
634	PLEASANT STREET - OH	Transmission		69.00	34.50		9.38	1			0	0.00
635	PLEASANTVILLE - OH	Distribution		69.00	13.09		9.38	1			0	0.00
636	PLYMOUTH HEIGHTS - OH	Distribution		69.00	12.00		9.38	1			0	0.00
637	POLARIS - OH	Distribution		138.00	35.40	13.80	100.00	2			0	0.00
638	POLARIS - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	2	14.40
639	POMEROY(OP) - OH	Distribution		34.50	12.00		6.25	1			0	0.00
640	PORTERFIELD - OH	Distribution		138.00	13.09		14.00	1			0	0.00
641	POWELSON - OH	Distribution		138.00	13.09		20.00	1			0	0.00
642	POWHATAN - OH	Distribution		69.00	4.00		5.00	2			0	0.00
643	PROCTORVILLE - OH	Distribution		34.50	12.00		6.25	1			0	0.00
644	PROMWAY - OH	Distribution		138.00	13.09		20.00	1			0	0.00
645	QUARRY ROAD - OH	Distribution		69.00	12.00		22.40	1			0	0.00
646	RACINE HYDRO - OH	Transmission		69.00	13.09		9.38	1			0	0.00
647	RALSTON - OH	Distribution		69.00	12.00		10.50	1			0	0.00
648	RARDEN - OH	Distribution		69.00	34.50	13.00	38.00	2			0	0.00
649	RAVEN - OH	Distribution		69.00	13.20		12.50	1			0	0.00
650	RAY - OH	Distribution		69.00	34.50		15.63	2			0	0.00
651	RAY - OH	Distribution		69.00	13.09		25.00	3			0	0.00
652	REEDURBAN - OH	Transmission		138.00	69.00	13.09	54.00	1			0	0.00
653	REEDURBAN - OH	Transmission		138.00	13.09		22.40	1			0	0.00
654	RENO - OH	Distribution		138.00	13.09		20.00	1			0	0.00
655	REYNOLDSBURG - OH	Distribution		7.62	0.00	0.00	0.00			STATCAP	1	2.70
656	REYNOLDSBURG - OH	Distribution		40.00	13.20	4.15	10.00	1			0	0.00
657	RIDGELY - OH	Distribution		138.00	35.40	13.80	30.00	1			0	0.00
658	RIO - OH	Distribution		138.00	13.20		34.00	2			0	0.00
659	RIVERVIEW (CSP) - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	36.00
660	RIVERVIEW (CSP) - OH	Distribution		138.00	13.80		44.80	2			0	0.00
661	RIVERVIEW (OP) - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
662	RIVERVIEW (OP) - OH	Distribution		69.00	4.36		6.25	1			0	0.00
663	RIVERVIEW (OP) - OH	Distribution		69.00	13.09		22.40	1			0	0.00
664	ROBB AVENUE - OH	Distribution		34.50	4.00		10.00	6			0	0.00
665	ROBERTS - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	1	3.59
666	ROBERTS - OH	Transmission		345.00	138.00	34.50		1			0	0.00
667	ROBERTS - OH	Transmission		138.00	13.80		83.67	2			0	0.00
668	ROBERTS - OH	Transmission		345.00	138.00	34.50	675.00	1			0	0.00
669	ROBERTS - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2	172.80
670	ROBERTSVILLE - OH	Distribution		69.00	13.09		5.25	1			0	0.00
671	ROBYVILLE - OH	Distribution		69.00	12.00		3.00	2			0	0.00
672	ROCKBRIDGE - OH	Distribution		69.00	12.00		9.38	1			0	0.00
673	ROCKHILL (OP) - OH	Transmission		138.00	34.65	11.00	49.66	6			0	0.00
674	ROCKHILL (OP) - OH	Transmission		138.00	35.00		50.00	1			0	0.00
675	ROCKHILL (OP) - OH	Transmission		138.00	13.09		20.00	1			0	0.00
676	ROSE FARM - OH	Distribution		69.00	13.09		4.68	1			0	0.00
677	ROSEMOUNT - OH	Distribution		69.00	13.09		9.38	1			0	0.00
678	ROSEMOUNT - OH	Distribution		69.00	34.50		20.00	1			0	0.00
679	ROSS - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2
680	ROSS - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	3	10.77
681	ROSS - OH	Transmission		12.00	0.00	0.00	0.00			REACTOR	2
682	ROZELLE - OH	Distribution		138.00	13.09		20.00	1			0	0.00
683	RUHLMAN - OH	Distribution		69.00	13.00		20.00	1			0	0.00
684	RUTLAND - OH	Transmission		138.00	34.50		20.00	1			0	0.00
685	S.B.C. CONTAINERS - OH	Distribution		69.00	13.09		6.25	1			0	0.00
686	SAINT CLAIR AVENUE (CS) - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	72.00
687	SAINT CLAIR AVENUE (CS) - OH	Distribution		138.00	13.80	13.80	176.66	2			0	0.00
688	SAINT CLAIR AVENUE (CS) - OH	Distribution		138.00	0.00	0.00	0.00			AIR CORE REACTOR	6
689	SAINT CLAIR AVENUE (CS) - OH	Distribution		138.00	13.80	13.80	93.30	0	1		0	0.00
690	SAINT CLAIR AVENUE (OP) - OH	Distribution		69.00	13.09		22.40	1			0	0.00
691	SAINT CLAIRSVILLE - OH	Distribution		69.00	12.00		7.00	1			0	0.00
692	SAINT GEORGE STREET - OH	Distribution		69.00	4.00		7.00	1			0	0.00
693	SAVANNAH AVENUE - OH	Distribution		69.00	22.90	13.09	80.00	2			0	0.00
694	SAVANNAH AVENUE - OH	Distribution		69.00	13.09		15.00	1			0	0.00
695	SAWMILL - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	86.40
696	SAWMILL - OH	Transmission		138.00	34.50	13.80	149.37	2			0	0.00
697	SAWMILL - OH	Transmission		138.00	13.80		25.00	1			0	0.00
698	SAWMILL - OH	Transmission		138.00	69.00	13.00	90.00	1			0	0.00
699	SCHOENBRUNN - OH	Distribution		69.00	12.00		22.40	1			0	0.00
700	SCHROYER AVENUE - OH	Transmission		69.00	4.00		6.25	1			0	0.00
701	SCHROYER AVENUE - OH	Transmission		69.00	13.09		20.00	1			0	0.00
702	SCIO - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.60
703	SCIOTO TRAIL (CS) - OH	Distribution		138.00	13.20	7.24	30.00	1			0	0.00
704	SCIOTOVILLE - OH	Distribution		69.00	12.00		9.38	1			0	0.00
705	SEAMAN - OH	Transmission		69.00	13.09		20.00	1			0	0.00
706	SEAMAN - OH	Transmission		69.00	13.20		6.25	0	1		0	0.00
707	SEAMAN - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
708	SEAMAN - OH	Transmission		138.00	69.00	13.09	90.00	1			0	0.00
709	SENECAVILLE - OH	Distribution		69.00	13.09		5.00	1			0	0.00
710	SEROCO AVENUE - OH	Distribution		69.00	4.00		15.62	2			0	0.00
711	SHADYSIDE - OH	Distribution		69.00	13.09		10.50	1			0	0.00
712	SHANNON - OH	Distribution		138.00	13.80		71.67	2			0	0.00
713	SHANNON - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	2	12.60
714	SHARON VALLEY - OH	Distribution		69.00	13.09		25.00	1			0	0.00
715	SHARP ROAD - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	19.20
716	SHARP ROAD - OH	Transmission		138.00	69.00	12.00	84.00	1			0	0.00
717	SHAWNEE - OH	Distribution		69.00	13.09		9.38	1			0	0.00
718	SHAWNEE ROAD - OH	Transmission		138.00	13.09		22.40	1			0	0.00
719	SHAWNEE ROAD - OH	Transmission		138.00	69.50	35.00	75.00	1			0	0.00
720	SHERWOOD - OH	Distribution		69.00	13.09		7.00	1			0	0.00
721	SHINNICK STREET - OH	Distribution		69.00	4.36		9.37	1			0	0.00
722	SHREVE - OH	Distribution		69.00	13.09		12.50	1			0	0.00
723	SLATE MILLS - OH	Distribution		69.00	13.20		10.50	1			0	0.00
724	SMITHVILLE - OH	Distribution		69.00	12.00		6.25	1			0	0.00
725	SOMERTON - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	28.80
726	SOMERTON - OH	Transmission		138.00	69.00	12.00	50.00	1			0	0.00
727	SOUTH BELMONT - OH	Distribution		69.00	13.09		12.50	1			0	0.00
728	SOUTH BERWICK - OH	Transmission		345.00	68.80	13.09	150.00	1			0	0.00
729	SOUTH CADIZ - OH	Transmission		138.00	69.00	13.09	75.00	1			0	0.00
730	SOUTH CADIZ - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	9.60
731	SOUTH CADIZ - OH	Transmission		69.00	12.00		5.25	1			0	0.00
732	SOUTH CAMBRIDGE - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
733	SOUTH CAMBRIDGE - OH	Transmission		69.00	34.50		50.00	2			0	0.00
734	SOUTH CAMBRIDGE - OH	Transmission		69.00	34.50	12.00	39.00	1			0	0.00
735	SOUTH CANTON 138KV - OH	Transmission		138.00	13.09		8.40	1			0	0.00
736	SOUTH CANTON 345KV - OH	Transmission		345.00	137.50	35.00	675.00	1			0	0.00
737	SOUTH CANTON 345KV - OH	Transmission		345.00	138.00	34.50	675.00	1			0	0.00
738	SOUTH CANTON 765KV - OH	Transmission		765.00	345.00	34.50	3000.00	4			0	0.00
739	SOUTH CONVOY - OH	Distribution		34.50	13.09		6.25	1			0	0.00
740	SOUTH COSHOCTON - OH	Transmission		138.00	36.00	7.20	30.00	1			0	0.00
741	SOUTH COSHOCTON - OH	Transmission		138.00	69.00	12.00	75.00	1			0	0.00
742	SOUTH COSHOCTON - OH	Transmission		138.00	13.09		12.00	1			0	0.00
743	SOUTH COSHOCTON - OH	Transmission		34.50	12.00		2.50	0	1		0	0.00
744	SOUTH COSHOCTON - OH	Transmission		69.00	34.50	12.00	39.20	1			0	0.00
745	SOUTH CUMBERLAND - OH	Transmission		138.00	25.00		8.40	0	1		0	0.00
746	SOUTH CUMBERLAND - OH	Transmission		138.00	69.00	34.50	84.00	1			0	0.00
747	SOUTH DELPHOS - OH	Distribution		69.00	13.09		10.50	1			0	0.00
748	SOUTH FINDLAY - OH	Distribution		34.50	0.00	0.00	0.00			STATCAP	1	12.00
749	SOUTH FINDLAY - OH	Distribution		34.50	13.09		40.00	2			0	0.00
750	SOUTH FULTONHAM - OH	Distribution		69.00	4.00		3.75	1			0	0.00
751	SOUTH GRANVILLE - OH	Distribution		69.00	13.09		20.00	1			0	0.00
752	SOUTH GREENWICH - OH	Distribution		69.00	13.09		9.38	1			0	0.00
753	SOUTH HICKSVILLE - OH	Transmission		138.00	69.50	13.09	75.00	1			0	0.00
754	SOUTH HICKSVILLE - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	18.00
755	SOUTH KENTON - OH	Transmission		138.00	69.50	13.09	56.00	1			0	0.00
756	SOUTH KENTON - OH	Transmission		138.00	69.00	0.22	30.00	2			0	0.00
757	SOUTH KENTON - OH	Transmission		2.40	0.00	0.00	0.00			STATCAP	1
758	SOUTH LANCASTER - OH	Transmission		138.00	69.00	34.50	130.00	1			0	0.00
759	SOUTH LANCASTER - OH	Transmission		138.00	69.00	12.00	60.00	1			0	0.00
760	SOUTH LUCASVILLE - OH	Distribution		138.00	13.09		12.50	1			0	0.00
761	SOUTH MARTINS FERRY - OH	Distribution		69.00	13.09		22.40	1			0	0.00
762	SOUTH MILLERSBURG - OH	Transmission		138.00	35.00	7.20	25.00	1			0	0.00
763	SOUTH MILLERSBURG - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	1	6.00
764	SOUTH MORRAL - OH	Distribution		69.00	13.09		5.25	1			0	0.00
765	SOUTH NEWARK - OH	Distribution		69.00	12.00		40.00	2			0	0.00
766	SOUTH POINT - OH	Transmission		34.50	12.00		9.38	1			0	0.00
767	SOUTH POINT - OH	Transmission		138.00	69.00	34.50	129.00	1			0	0.00
768	SOUTH POINT - OH	Transmission		138.00	34.50		25.00	1			0	0.00
769	SOUTH POINT - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	67.20
770	SOUTH SIDE LIMA - OH	Distribution		34.50	4.00		3.75	1			0	0.00
771	SOUTH SIDE LIMA - OH	Distribution		34.50	13.09		20.00	1			0	0.00
772	SOUTH SOMERSET - OH	Distribution		69.00	13.09		7.00	1			0	0.00
773	SOUTH TIFFIN - OH	Transmission		138.00	69.30	6.90	50.00	1			0	0.00
774	SOUTH TORONTO - OH	Transmission		138.00	69.50	13.09	60.00	1			0	0.00
775	SOUTH VAN WERT - OH	Distribution		69.00	4.36		5.25	1			0	0.00
776	SOUTH VAN WERT - OH	Distribution		69.00	13.09		22.40	1			0	0.00
777	SOUTH VANLUE - OH	Distribution		69.00	13.09		9.38	1			0	0.00
778	SOUTH WOOSTER - OH	Distribution		23.00	4.00		3.75	1			0	0.00
779	SOUTHEAST LOGAN - OH	Distribution		69.00	12.00		10.50	1			0	0.00
780	SOUTHWEST LIMA - OH	Transmission		345.00	137.50	13.80	450.00	1			0	0.00
781	SOUTHWEST LIMA - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	24.00
782	SPARTA PUMPING - OH	Distribution		23.00	4.00		3.75	1			0	0.00
783	ST RITAS HOSP - OH	Distribution		34.50	4.16		18.60	2			0	0.00
784	STANLEY COURT - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	13.19
785	STANLEY COURT - OH	Transmission		69.00	13.09		20.00	1			0	0.00
786	STANTON STREET - OH	Distribution		69.00	13.09		8.40	1			0	0.00
787	STATE LINE - OH	Distribution		69.00	4.00		3.75	1			0	0.00
788	STEUBENVILLE - OH	Transmission		138.00	69.00	12.00	112.00	1			0	0.00
789	STEUBENVILLE PUMPING - OH	Distribution		69.00	4.00		4.20	1			0	0.00
790	STONE CREEK - OH	Distribution		34.50	13.09		2.00	1			0	0.00
791	STONE STREET - OH	Distribution		69.00	4.36		5.00	1			0	0.00
792	STONE STREET - OH	Distribution		69.00	13.09		20.00	1			0	0.00
793	STONY HOLLOW - OH	Distribution		69.00	13.09		20.00	1			0	0.00
794	STRASBURG - OH	Distribution		138.00	36.20		30.00	1			0	0.00
795	STRATTON (OP) - OH	Distribution		69.00	4.36		5.25	1			0	0.00
796	STROUDS RUN - OH	Transmission		138.00	69.00	12.00	84.00	1			0	0.00
797	STROUDS RUN - OH	Transmission		138.00	69.00	13.20	30.00	1			0	0.00
798	SUGAR HILL (OP) - OH	Distribution		69.00	13.09		20.00	1			0	0.00
799	SUGARCREEK TERMINAL - OH	Distribution		138.00	13.09		22.40	1			0	0.00
800	SUGARCREEK TERMINAL - OH	Distribution		69.00	35.00		30.00	1			0	0.00
801	SULPHUR SPRINGS - OH	Distribution		138.00	13.09		8.40	1			0	0.00
802	SUMMERFIELD - OH	Transmission		138.00	69.00	12.00	84.00	1			0	0.00
803	SUMMERFIELD - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
804	SUMMERHILL - OH	Distribution		69.00	13.09		20.00	1			0	0.00
805	SUNNYSIDE - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	115.20
806	SUNNYSIDE - OH	Transmission		138.00	23.00	6.90	30.00	3			0	0.00
807	SUNNYSIDE - OH	Transmission		138.00	13.09		20.00	1			0	0.00
808	SUNNYSIDE - OH	Transmission		138.00	23.00		41.66	1			0	0.00
809	SUNSET BOULEVARD - OH	Distribution		69.00	13.09		22.40	1			0	0.00
810	SUPERIOR (CS) - OH	Distribution		69.00	12.00		6.25	1			0	0.00
811	TAYLOR - OH	Distribution		138.00	34.50	13.80	46.67	1			0	0.00
812	THAYER ROAD - OH	Distribution		138.00	13.09		40.00	2			0	0.00
813	THIRD STREET - OH	Distribution		69.00	13.09		20.00	1			0	0.00
814	THORNVILLE - OH	Distribution		69.00	13.09		20.00	1			0	0.00
815	TIDD 138KV - OH	Transmission		138.00	13.09		8.40	0	1		0	0.00
816	TIDD 138KV - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	2	115.20
817	TIDD 138KV - OH	Transmission		138.00	69.00	34.50	130.00	1			0	0.00
818	TIDD 345KV - OH	Transmission		345.00	137.50	13.80	450.00	1			0	0.00
819	TIDD 345KV - OH	Transmission		138.00	0.00	0.00	0.00			AIR CORE REACTOR	2
820	TIDD 69KV - OH	Transmission		69.00	12.00		3.75	1			0	0.00
821	TIFFIN CENTER - OH	Transmission		138.00	69.50	13.09	50.00	1			0	0.00
822	TIFFIN TAP-OFF - OH	Distribution		69.00	13.09		9.37	1			0	0.00
823	TILTONSVILLE - OH	Transmission		69.00	13.09		10.50	1			0	0.00
824	TILTONSVILLE - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	19.20
825	TILTONSVILLE - OH	Transmission		138.00	69.00	12.00	90.00	1			0	0.00
826	TIMKEN - OH	Transmission		138.00	24.14		334.60	4			0	0.00
827	TIMKEN MERCY - OH	Distribution		69.00	4.00		10.50	2			0	0.00
828	TORONTO - OH	Distribution		69.00	13.09		20.00	1			0	0.00
829	TORREY - OH	Transmission		138.00	23.00	11.00	16.00	0	1		0	0.00
830	TORREY - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	115.20
831	TORREY - OH	Transmission		23.00	12.00		1.25	0	1		0	0.00
832	TORREY - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	9.60
833	TORREY - OH	Transmission		138.00	23.00	11.00	92.00	6			0	0.00
834	TORREY - OH	Transmission		69.00	13.09		10.50	1			0	0.00
835	TORREY - OH	Transmission		138.00	69.00	12.00	90.00	1			0	0.00
836	TOTTEN - OH	Distribution		34.50	2.30		1.00	1			0	0.00
837	TRABUE - OH	Distribution		138.00	13.80		83.34	2			0	0.00
838	TRABUE - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	2	14.40
839	TRABUE - OH	Distribution		138.00	69.50	13.80	128.80	1			0	0.00
840	TRENT - OH	Distribution		138.00	34.50	13.80	46.67	1			0	0.00
841	TRENT - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	28.00
842	TWO RIDGES - OH	Distribution		69.00	12.00		20.00	1			0	0.00
843	UPPER SANDUSKY - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.39
844	UPPER SANDUSKY - OH	Distribution		69.00	13.09		20.00	1			0	0.00
845	UTICA (OP) - OH	Distribution		69.00	13.09		25.00	1			0	0.00
846	VAN WERT - OH	Distribution		69.00	13.09		22.40	1			0	0.00
847	VAN WERT - OH	Distribution		69.00	4.36		6.25	1			0	0.00
848	VAN WERT - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	16.20
849	VIGO - OH	Distribution		69.00	13.09		20.00	1			0	0.00
850	VINE - OH	Distribution		13.20	0.00	0.00	0.00			STATCAP	3	17.97
851	VINE - OH	Distribution		138.00	0.00	0.00	0.00			STATCAP	1	86.40
852	VINE - OH	Distribution		138.00	13.80	13.80	93.30	1			0	0.00
853	VINE - OH	Distribution		138.00	13.80		91.67	2			0	0.00
854	WADE - OH	Distribution		23.00	13.09		4.20	1			0	0.00
855	WAGENHALS - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	115.20
856	WAGENHALS - OH	Transmission		138.00	70.50	13.09	130.00	1			0	0.00
857	WAGENHALS - OH	Transmission		138.00	69.00	23.00	84.00	1			0	0.00
858	WAGENHALS - OH	Transmission		138.00	23.50	7.20	30.00	1			0	0.00
859	WAKEFIELD - OH	Transmission		138.00	13.09		10.50	1			0	0.00
860	WALDO - OH	Distribution		69.00	12.00		3.75	1			0	0.00
861	WALDO - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.60
862	WALNUT CREEK - OH	Distribution		69.00	13.09		9.38	1			0	0.00
863	WALNUT CREEK - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	7.20
864	WAPAKONETA SW - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	12.00
865	WARSAW - OH	Distribution		34.50	12.00		3.75	1			0	0.00
866	WATER STREET - OH	Distribution		34.50	12.00		4.68	1			0	0.00
867	WATER STREET - OH	Distribution		34.50	4.00		3.75	1			0	0.00
868	WATERFORD (CSP) - OH	Distribution		23.00	13.09		7.95	2			0	0.00
869	WAVERLY - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	2	5.40
870	WAVERLY - OH	Transmission		138.00	69.00	13.53	30.00	1			0	0.00
871	WAVERLY - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	57.60
872	WAYVIEW - OH	Transmission		138.00	13.09		22.40	1			0	0.00
873	WAYVIEW - OH	Transmission		138.00	69.00	12.00	130.00	1			0	0.00
874	WEST ALIKANNA - OH	Distribution		69.00	13.09		6.25	1			0	0.00
875	WEST BELLAIRE - OH	Transmission		138.00	69.00	13.09	130.00	1			0	0.00
876	WEST BENTON - OH	Distribution		69.00	13.09		9.38	1			0	0.00
877	WEST CANTON - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	62.40
878	WEST CANTON - OH	Transmission		138.00	13.09		22.40	1			0	0.00
879	WEST CANTON - OH	Transmission		138.00	69.50	13.09	130.00	1			0	0.00
880	WEST CANTON - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	9.60
881	WEST CANTON - OH	Transmission		69.00	36.20		25.00	1			0	0.00
882	WEST CANTON - OH	Transmission		138.00	36.20		20.00	1			0	0.00
883	WEST COSHOCTON - OH	Transmission		138.00	69.00	13.09	56.00	1			0	0.00
884	WEST DOVER - OH	Transmission		138.00	69.50	13.09	90.00	1			0	0.00
885	WEST END FOSTORIA - OH	Transmission		69.00	4.36		6.25	1			0	0.00
886	WEST END FOSTORIA - OH	Transmission		69.00	4.16		3.75	1			0	0.00
887	WEST END FOSTORIA - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	21.60
888	WEST END FOSTORIA - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	57.59
889	WEST END FOSTORIA - OH	Transmission		138.00	69.50	13.09	75.00	1			0	0.00
890	WEST FOURTH STREET - OH	Distribution		34.50	4.16		6.25	1			0	0.00
891	WEST FREMONT - OH	Distribution		69.00	4.36		6.25	1			0	0.00
892	WEST GALION - OH	Distribution		69.00	13.09		9.38	1			0	0.00
893	WEST GRANVILLE - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
894	WEST GRANVILLE - OH	Distribution		69.00	12.00		10.50	1			0	0.00
895	WEST HEBRON - OH	Transmission		138.00	69.00	34.50	128.80	1			0	0.00
896	WEST HEBRON - OH	Transmission		34.50	0.00	0.00	0.00			STATCAP	2	4.80
897	WEST HEBRON - OH	Transmission		34.50	34.50		25.00	1			0	0.00
898	WEST HICKSVILLE - OH	Distribution		69.00	13.09		10.50	1			0	0.00
899	WEST LAFAYETTE - OH	Distribution		34.50	12.00		4.68	0	1		0	0.00
900	WEST LAFAYETTE - OH	Distribution		34.50	13.09		9.38	1			0	0.00
901	WEST LANCASTER - OH	Transmission		138.00	69.00	12.00	197.20	2			0	0.00
902	WEST LANCASTER - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	14.40
903	WEST LANCASTER - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	72.00
904	WEST LIMA - OH	Transmission		138.00	35.00		265.00	2			0	0.00
905	WEST LIMA - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	46.08
906	WEST LOGAN - OH	Distribution		69.00	12.00		20.00	1			0	0.00
907	WEST LONGLEY - OH	Distribution		69.00	2.50		2.00	1			0	0.00
908	WEST LOUISVILLE - OH	Distribution		69.00	12.00		19.88	2			0	0.00
909	WEST LOUISVILLE - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	9.89
910	WEST MALTA - OH	Distribution		69.00	12.00		6.25	1			0	0.00
911	WEST MELROSE - OH	Distribution		34.50	13.09		22.40	1			0	0.00
912	WEST MILLERSBURG - OH	Distribution		138.00	69.00	34.50	90.00	1			0	0.00
913	WEST MILLERSBURG - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.40
914	WEST MILLERSBURG - OH	Distribution		138.00	36.20		25.00	1			0	0.00
915	WEST MILLERSPORT - OH	Transmission		138.00	70.50	13.09	78.00	0	1		0	0.00
916	WEST MILLERSPORT - OH	Transmission		345.00	137.50	13.80	900.00	2			0	0.00
917	WEST MORRICAL - OH	Distribution		34.50	2.52		4.69	1			0	0.00
918	WEST MOULTON - OH	Transmission		138.00	70.50	36.20	200.00	1			0	0.00
919	WEST MOULTON - OH	Transmission		69.00	13.09		20.00	1			0	0.00
920	WEST MOUNT VERNON - OH	Transmission		69.00	0.00	0.00	0.00			STATCAP	1	13.20
921	WEST MOUNT VERNON - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	52.60
922	WEST MOUNT VERNON - OH	Transmission		138.00	69.00	4.00	30.00	1			0	0.00
923	WEST NEW PHILADELPHIA - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	72.00
924	WEST NEW PHILADELPHIA - OH	Transmission		138.00	69.00	12.00	128.80	1			0	0.00
925	WEST NEW PHILADELPHIA - OH	Transmission		138.00	34.50	4.00	15.00	1			0	0.00
926	WEST NEW PHILADELPHIA - OH	Transmission		138.00	13.09		30.50	2			0	0.00
927	WEST OAKWOOD - OH	Distribution		69.00	13.09		7.00	1			0	0.00
928	WEST PHILO - OH	Distribution		138.00	13.09		8.40	1			0	0.00
929	WEST TORONTO - OH	Distribution		69.00	13.09		10.50	1			0	0.00
930	WEST TRINWAY - OH	Distribution		138.00	13.09		20.00	1			0	0.00
931	WEST VAN WERT - OH	Transmission		69.00	35.00		25.00	1			0	0.00
932	WEST WOOSTER - OH	Distribution		69.00	12.00		22.40	1			0	0.00
933	WEST WOOSTER - OH	Distribution		69.00	0.00	0.00	0.00			STATCAP	1	14.39
934	WESTERVILLE - OH	Distribution		69.00	13.80		44.80	2			0	0.00
935	WHEELERSBURG - OH	Distribution		69.00	13.20		10.50	1			0	0.00
936	WHIRLPOOL (OP) - OH	Distribution		34.50	13.09		20.00	1			0	0.00
937	WHITE ROAD - OH	Distribution		138.00	13.80		50.00	1			0	0.00
938	WILDCAT - OH	Distribution		138.00	12.00		9.38	1			0	0.00
939	WILKESVILLE - OH	Distribution		138.00	13.09		10.50	1			0	0.00
940	WILLARD - OH	Distribution		69.00	13.09		9.37	1			0	0.00
941	WILSON ROAD - OH	Transmission		46.00	0.00	0.00	0.00			STATCAP	1	10.80
942	WILSON ROAD - OH	Transmission		138.00	13.80	13.80	41.67	1			0	0.00
943	WILSON ROAD - OH	Transmission		13.20	0.00	0.00	0.00			STATCAP	2	7.18
944	WILSON ROAD - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	72.00
945	WILSON ROAD - OH	Transmission		138.00	39.40	13.80	83.34	2			0	0.00
946	WINTERSVILLE - OH	Distribution		69.00	12.00		10.50	1			0	0.00
947	WOLF CREEK (CSP) - OH	Transmission		23.00	13.09		5.60	0	1		0	0.00
948	WOLF CREEK (CSP) - OH	Transmission		138.00	13.09		20.00	1			0	0.00
949	WOODLAWN (OP) - OH	Distribution		138.00	13.09		20.00	1			0	0.00
950	WOOSTER - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	28.80
951	WOOSTER - OH	Transmission		138.00	24.14		25.00	1			0	0.00
952	WOOSTER - OH	Transmission		138.00	13.09		20.00	1			0	0.00
953	WOOSTER - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	21.60
954	WOOSTER - OH	Transmission		138.00	69.50	13.09	50.00	1			0	0.00
955	ZANESVILLE - OH	Transmission		138.00	69.00	12.00	130.00	1			0	0.00
956	ZANESVILLE - OH	Transmission		138.00	13.09		25.00	1			0	0.00
957	ZANESVILLE - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	57.60
958	ZOARVILLE - OH	Distribution		69.00	13.09		9.38	1			0	0.00
959	ZUBER - OH	Distribution		138.00	13.80		50.00	1			0	0.00
960	ZUBER - OH	Distribution		13.80	0.00	0.00	0.00			STATCAP	1	7.20
961	TotalDistributionSubstationMember											1,381
962	TotalTransmissionSubstationMember											3,999
963	Total											5,380

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: OH Date of Incorporation: 1907-05-08 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	Barton, Lisa M. Vice President	Columbus, Ohio	false	false
3	Chodak, Paul . Vice President	Columbus, Ohio	false	false
4	Feinberg, David M. Secretary	Columbus, Ohio	false	false
5	Patton, Charles R.	Columbus, Ohio	false	false
6	Risch, Therace M. Vice President	Columbus, Ohio	false	false
7	Sloat, Julia A. Chief Financial Officer and Vice President	Columbus, Ohio	false	false
8	Thomas, Toby L. Vice President	Columbus, Ohio	false	false
9	Reitter, Marc D. President and Chief Operating Officer	Columbus, Ohio	false	false
10	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
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
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
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	20211221-5274	12/21/2021	ER17-405	AEP PJM OATT Proj Transmission	PJM OATT Attachment H-14
2	20211101-5315	11/01/2021	ER17-405	AEP PJM OATT Proj Transmission	PJM OATT Attachment H-14
3	20210525-5243	05/25/2021	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	10,109,679,319	9,503,644,245
3	ConstructionWorkInProgress Construction Work in Progress (107)	200	367,273,503	363,465,994
4	UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3)		10,476,952,821	9,867,110,239
5	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)	200	2,913,414,961	2,797,787,367
6	UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5)		7,563,537,860	7,069,322,872
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)		7,563,537,860	7,069,322,872
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	19,280,096
19	AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122)		4,131,262	3,051,729
20	InvestmentInAssociatedCompanies Investments in Associated Companies (123)		430,000	430,000
21	InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1)	224	2,029,553	1,685,427
23	NoncurrentPortionOfAllowances Noncurrent Portion of Allowances	228
24	OtherInvestments Other Investments (124)		9,132,024	10,146,696
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)		169,853,221	119,887,607
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)		196,558,506	148,378,097
33	CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS
34	CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130)
35	Cash Cash (131)		2,990,480	7,365,688
36	SpecialDeposits Special Deposits (132-134)		15,327,429	422,722
37	WorkingFunds Working Fund (135)
38	TemporaryCashInvestments Temporary Cash Investments (136)
39	NotesReceivable Notes Receivable (141)
40	CustomerAccountsReceivable Customer Accounts Receivable (142)		83,005,369	66,763,681
41	OtherAccountsReceivable Other Accounts Receivable (143)		5,939,084	3,918,546
42	AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144)		525,177	638,689
43	NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145)		41,991,513
44	AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146)		64,075,272	57,090,286
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	74,134,855	66,884,590
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)		6,594,846	7,352,949
58	AdvancesForGas Advances for Gas (166-167)
59	InterestAndDividendsReceivable Interest and Dividends Receivable (171)
60	RentsReceivable Rents Receivable (172)		3,273,990	2,859,145
61	AccruedUtilityRevenues Accrued Utility Revenues (173)		1,296,518	14,833,703
62	MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174)		79,379,846	83,949,239
63	DerivativeInstrumentAssets Derivative Instrument Assets (175)		828	847
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)		377,484,852	310,802,708
68	DeferredDebitsAbstract DEFERRED DEBITS
69	UnamortizedDebtExpense Unamortized Debt Expenses (181)		22,718,242	14,106,802
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	352,104,457	447,749,840
73	PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183)		71	15
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	363,165,008	326,289,608
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)		2,866,937	4,014,347
82	AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190)	234	204,357,451	210,800,135
83	UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191)
84	DeferredDebits Total Deferred Debits (lines 69 through 83)		945,212,167	1,002,960,748
85	AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84)		9,082,793,385	8,531,464,425

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	838,781,212	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	1,681,376,499	1,527,729,621
12	UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1)	118	4,915,703	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)	19,530	30,183
16	ProprietaryCapital Total Proprietary Capital (lines 2 through 15)		2,846,294,399	2,692,658,174
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	3,000,748,198	2,450,850,277
22	UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225)
23	UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226)		9,508,727	6,502,117
24	LongTermDebt Total Long-Term Debt (lines 18 through 23)		2,991,239,471	2,444,348,160
25	OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES
26	ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227)		83,449,573	96,377,645
27	AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1)
28	AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2)		276,600	701,310
29	AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3)		5,962,545	6,501,600
30	AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4)		1,899,511	1,132,011
31	AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229)		3,521,938	3,521,938
32	LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities		85,828,895	101,621,101
33	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges
34	AssetRetirementObligations Asset Retirement Obligations (230)		1,890,073	1,846,330
35	OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34)		182,829,135	211,701,934
36	CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES
37	NotesPayable Notes Payable (231)
38	AccountsPayable Accounts Payable (232)		213,484,925	180,956,534
39	NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233)			259,203,806
40	AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234)		125,475,611	118,427,030
41	CustomerDeposits Customer Deposits (235)		66,427,967	55,075,260
42	TaxesAccrued Taxes Accrued (236)	262	697,975,157	625,681,376
43	InterestAccrued Interest Accrued (237)		35,763,904	35,808,120
44	DividendsDeclared Dividends Declared (238)
45	MaturedLongTermDebt Matured Long-Term Debt (239)
46	MaturedInterest Matured Interest (240)
47	TaxCollectionsPayable Tax Collections Payable (241)		12
48	MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242)		40,205,131	58,470,854
49	ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243)		17,556,997	17,742,325
50	DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244)		92,565,601	110,332,687
51	LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities		85,828,895	101,621,101
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)		1,203,626,411	1,360,076,891
55	DeferredCreditsAbstract DEFERRED CREDITS
56	CustomerAdvancesForConstruction Customer Advances for Construction (252)
57	AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255)	266	512	512
58	DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256)
59	OtherDeferredCredits Other Deferred Credits (253)	269	38,222,082	40,261,693
60	OtherRegulatoryLiabilities Other Regulatory Liabilities (254)	278	615,289,045	616,563,737
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)		1,060,034,309	1,023,016,941
64	AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283)		145,258,021	142,836,382
65	DeferredCredits Total Deferred Credits (lines 56 through 64)		1,858,803,970	1,822,679,266
66	LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)		9,082,793,385	8,531,464,425

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	2,902,386,985	2,749,986,708			2,902,386,985	2,749,986,708
3	OperatingExpensesAbstract Operating Expenses
4	OperationExpense Operation Expenses (401)	320	1,551,797,442	1,452,633,811			1,551,797,442	1,452,633,811
5	MaintenanceExpense Maintenance Expenses (402)	320	158,167,742	127,064,831			158,167,742	127,064,831
6	DepreciationExpense Depreciation Expense (403)	336	258,106,708	245,047,316			258,106,708	245,047,316
7	DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1)	336
8	AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405)	336	43,861,977	30,356,379			43,861,977	30,356,379
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)		1,574,193	880,471			1,574,193	880,471
13	RegulatoryCredits (Less) Regulatory Credits (407.4)		574,879	684,934			574,879	684,934
14	TaxesOtherThanIncomeTaxesUtilityOperatingIncome Taxes Other Than Income Taxes (408.1)	262	480,442,903	450,159,785			480,442,903	450,159,785
15	IncomeTaxesOperatingIncome Income Taxes - Federal (409.1)	262	10,993,493	24,558,899			10,993,493	24,558,899
16	IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1)	262	2,983,877	5,373,611			2,983,877	5,373,611
17	ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1)	234, 272	212,385,252	572,389,917			212,385,252	572,389,917
18	ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1)	234, 272	181,056,268	497,348,330			181,056,268	497,348,330
19	InvestmentTaxCreditAdjustments Investment Tax Credit Adj. - Net (411.4)	266		47				47
20	GainsFromDispositionOfPlant (Less) Gains from Disp. of Utility Plant (411.6)			67,159				67,159
21	LossesFromDispositionOfServiceCompanyPlant Losses from Disp. of Utility Plant (411.7)
22	GainsFromDispositionOfAllowances (Less) Gains from Disposition of Allowances (411.8)		71	84			71	84
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)		2,533,864,373	2,352,003,631			2,533,864,373	2,352,003,632
27	NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25)		368,522,612	397,983,076			368,522,612	397,983,076
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)		1,722,741	2,520,368
34	ExpensesOfNonutilityOperations (Less) Expenses of Nonutility Operations (417.1)		1,495,645	2,636,422
35	NonoperatingRentalIncome Nonoperating Rental Income (418)		521,723	83,893
36	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1)	119
37	InterestAndDividendIncome Interest and Dividend Income (419)		645,317	989,256
38	AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1)		10,765,939	12,484,295
39	MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421)		3,809,957	3,318,454
40	GainOnDispositionOfProperty Gain on Disposition of Property (421.1)		254,918	1,247,531
41	OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40)		16,224,950	18,007,374
42	OtherIncomeDeductionsAbstract Other Income Deductions
43	LossOnDispositionOfProperty Loss on Disposition of Property (421.2)		38,887
44	MiscellaneousAmortization Miscellaneous Amortization (425)
45	Donations Donations (426.1)		1,850,095	4,979,999
46	LifeInsurance Life Insurance (426.2)
47	Penalties Penalties (426.3)		810,653	2,038
48	ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4)		1,932,950	1,780,490
49	OtherDeductions Other Deductions (426.5)		9,093,938	20,954,627
50	OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49)		12,105,216	27,717,154
51	TaxesApplicableToOtherIncomeAndDeductionsAbstract Taxes Applic. to Other Income and Deductions
52	TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions Taxes Other Than Income Taxes (408.2)	262	107,071	102,066
53	IncomeTaxesFederal Income Taxes-Federal (409.2)	262	4,184,240	2,074,937
54	IncomeTaxesOther Income Taxes-Other (409.2)	262	134,755	24,244
55	ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2)	234, 272	2,827,459	3,297,078
56	ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions (Less) Provision for Deferred Income Taxes-Cr. (411.2)	234, 272	3,471,713	1,170,702
57	InvestmentTaxCreditAdjustmentsNonutilityOperations Investment Tax Credit Adj.-Net (411.5)			876
58	InvestmentTaxCredits (Less) Investment Tax Credits (420)
59	TaxesOnOtherIncomeAndDeductions TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)		4,856,179	176,873
60	NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59)		8,975,912	9,886,654
61	InterestChargesAbstract Interest Charges
62	InterestOnLongTermDebt Interest on Long-Term Debt (427)		123,891,875	116,320,775
63	AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428)		2,045,678	1,569,958
64	AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1)		1,147,410	1,245,401
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)		85,844	1,833,225
68	OtherInterestExpense Other Interest Expense (431)		1,380,920	1,939,810
69	AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)		4,700,081	6,176,059
70	NetInterestCharges Net Interest Charges (Total of lines 62 thru 69)		123,851,646	116,733,109
71	IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70)		253,646,878	271,363,314
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)		253,646,878	271,363,314

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		1,527,729,621	1,343,540,511
2	ChangesAbstract Changes
3	AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439)
4	AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit
4.1	AdjustmentsToRetainedEarningsCredit CECL ADOPTION-NONELECTRIC A/R(ASC 326 as of January 1, 2020.			325,796
9	AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439)			325,796
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)		253,646,878	271,363,314
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		100,000,000	87,500,000
36	DividendsDeclaredCommonStock TOTAL Dividends Declared-Common Stock (Acct. 438)		100,000,000	87,500,000
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)		1,681,376,499	1,527,729,621
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)		1,681,376,499	1,527,729,621
	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)
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)		4,915,703	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)	253,646,878	271,363,314
3	NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income:
4	DepreciationAndDepletion Depreciation and Depletion	301,968,685	275,403,695
5	NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details)
5.1	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Amortization of Regulatory Debits and Credits (Net)	2,149,073	1,565,406
5.2	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Carrying Cost Income	1,247,083	1,601,311
8	DeferredIncomeTaxesNet Deferred Income Taxes (Net)	30,684,729	77,167,963
9	InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net)		923
10	NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables	25,728,194	101,575
11	NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory	7,250,265	14,623,903
12	NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory
13	NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses	91,384,382	52,660,216
14	NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets	37,168,666	70,630,662
15	NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities	7,111,275	72,144,223
16	AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction	10,765,939	12,484,295
17	UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies
18	OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote):
18.1	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other (provide details in footnote):	(a) 86,044,284	71,208,884
18.2	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Deferred Property Taxes (186)	35,319,613	16,608,316
18.3	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Over/Under Recovered Fuel, Net	15,882,589	8,115,789
22	NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)	573,640,899	410,843,862
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)	746,563,213	830,004,885
27	GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel
28	GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant
29	GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant		18,099
30	AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction	10,765,939	12,484,295
31	OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote):
31.1	OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Other (provide details in footnote):
31.2	OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Acquired Assets	829,600	930,532
34	CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33)	736,626,874	818,469,221
36	AcquisitionOfOtherNoncurrentAssets Acquisition of Other Noncurrent Assets (d)
37	ProceedsFromDisposalOfNoncurrentAssets Proceeds from Disposal of Noncurrent Assets (d)	(b) 9,551,543	8,261,202
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)	12,964,204	14,598,964
53.2	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Other (provide details in footnote):
53.3	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription (Increase) Decrease in Other Special Deposits	57,304	404
53.4	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Notes Receivable from Associated Companies	41,991,513
57	CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)	756,159,944	795,609,459
59	CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities:
60	ProceedsFromIssuanceAbstract Proceeds from Issuance of:
61	ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b)	1,050,000,000	350,000,000
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	2,975,552
66	NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c)
67	OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote):
67.1	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Proceeds From Acquired Asset Subject to Capital Lease	379,200	797,996
67.2	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Notes Payable to Associated Companies		128,212,289
70	CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69)	1,037,449,723	476,034,733
72	PaymentsForRetirementAbstract Payments for Retirement of:
73	PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b)	500,102,080	97,820
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	259,203,806
78	NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c)
80	DividendsOnPreferredStock Dividends on Preferred Stock
81	DividendsOnCommonStock Dividends on Common Stock	100,000,000	87,500,000
83	CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)	178,143,836	388,436,913
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)	4,375,208	3,671,316
88	CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period	7,365,688	3,694,371
90	CashAndCashEquivalents Cash and Cash Equivalents at End of Period	2,990,480	7,365,688

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	4,643,941
3	Grid Solutions	AEPSC	920,923	324,989
4	Information Technology	AEPSC	920, 923	10,035,032
5	Audit Services	AEPSC	920, 923	1,110,264
6	Leased Transmission Lines	WPCo	565	2,728,223
7	Physical & Cyber Security	AEPSC	920,923	1,379,724
8	Administrative and General Expenses - Operation	AEPSC	920-923, 925,926,928,930.1,930.2,931	2,109,607
9	Legal GC/Administration	AEPSC	920, 923	3,851,107
10	Other Operating Revenues	APCo	456	1,078,555
11	Civil & Political Activities and Other Services	AEPSC	426.1, 426.3-426.5	2,028,858
12	Corp Safety & Health	AEPSC	920,923	1,766,117
13	Construction Services	AEPSC	107, 108	106,646,691
14	Materials and Supplies	I&M	107,154,184,186,570,571,582,583,592,593,595,935	291,089
15	Construction Services	APCo	107, 108	259,364
16	Materials and Supplies	AEP TEXAS	107,566,592	253,283
17	Construction Services	I&M	107, 108	312,897
18	Real Estate & Workplace Services	AEPSC	920, 923	2,909,168
19	Corporate Communications	AEPSC	920, 923	1,341,409
20	Regulatory Services	AEPSC	920, 923	1,045,276
21	Corporate Planning & Budgeting	AEPSC	920, 923	1,363,517
22	Research and Other Services	AEPSC	183,186,188	3,064,157
23	Customer Support	AEPSC	920, 923	3,428,049
24	Strategy & Transformation	AEPSC	920, 923	876,128
25	Customer Accounts Expenses	AEPSC	901-905	27,492,601
26	Transmission Expenses - Maintenance	AEPSC	568, 569, 569.1, 569.2, 570-573	7,060,473
27	Customer Service and Informational Expenses	AEPSC	907-908, 910	586,321
28	Transmission Expenses - Operation	AEPSC	560, 561.2,561.5, 562-565, 566, 920, 923	16,095,170
29	Distribution Expenses - Maintenance	AEPSC	590-594,596-598	5,317,726
30	Treasury & Risk	AEPSC	920, 923	1,842,777
31	Distribution Expenses - Operation	AEPSC	580-584, 586, 588	9,493,877
32	Tax Services	AEPSC	920,923	868,233
33	Bus Ops & Perf Assurance	AEPSC	920,923	1,574,431
34	Factored Customer A/R Bad Debts	AEP Credit, Inc.	426.5	8,721,042
35	Central Machine Shop	APCO	107,108,592	367,854
36	Factored Customer A/R Expense	AEP Credit, Inc.	426.5	4,683,627
37	Corporate Accounting	AEPSC	920, 923	2,222,663
38	Corporate Human Resources	AEPSC	920,923	4,111,168
39	Fuel & Storeroom Services	AEPSC	152,163	8,109,032
40	Non-power Goods or Services Provided for Affiliate
41	Non-power Goods or Services Provided for Affiliate
19
20	Non-power Goods or Services Provided for Affiliated
21	A Ray King Transmission Training Facility	AEP Texas	566	304,663
22	Administrative and General Expenses - Operation	AEP T&D Services, LLC	920, 921, 923, 930.2, 931	280,310
23	Construction Services	KPCO	107,108	584,810
24	Materials and Supplies	IMTCo	154	560,354
25	Other Operating Revenues	APCo	456	923,114
26	Building and Property Leases	AEPSC	454	11,344,953
27	Construction Services	I&M	107-108	737,920
28	Construction Services	APCO	107-108	1,809,573
29	Construction Services	OHTCo	107	1,585,030
30	Distribution Expenses - Maintenance	I&M	592, 593,594,595,597,598	759,222
31	Fleet and Vehicle Charges	AEPSC	(b) Footnote	6,988,555
32	Materials and Supplies	AEP TEXAS	154	516,030
33	Materials and Supplies	APCo	154	6,376,213
34	Materials and Supplies	I&M	154	3,636,276
35	Materials and Supplies	KYTCO	154	365,820
36	Materials and Supplies	KPCo	154	2,564,009
37	Materials and Supplies	PSO	154	331,063
38	Materials and Supplies	SWEPCo	154	452,962
39	Materials and Supplies	AEP T&D Services, LLC	154	315,438
40	Materials and Supplies	WVTCo	154	496,227
41	Use of Jointly Owned Facility	OHTCo	454	4,591,145
42	Building Rent	AEPSC	454	9,322,909
43	Distribution Expenses - Maintenance	KPCO	593,595	589,357
44	Distribution Expenses - Maintenance	APCO	593-596	1,749,030
45	Administrative and General Expenses - Maintenance	OHTCo	935	373,346
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