FERC Form

THIS FILING IS

Item 1:

☐ An Initial (Original) Submission

OR

☑ Resubmission No.




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

Exact Legal Name of Respondent (Company)

AEP Ohio Transmission Company, Inc.

Year/Period of Report

End of:

2021

/

Q4

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

GENERAL INFORMATION

Purpose
FERC Form No. 1 (FERC Form 1) is an annual regulatory requirement for Major electric utilities, licensees and others (18 C.F.R. § 141.1). FERC Form No. 3-Q ( FERC Form 3-Q) is a quarterly regulatory requirement which supplements the annual financial reporting requirement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities, licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be non-confidential public use forms.
Who Must Submit
Each Major electric utility, licensee, or other, as classified in the Commission’s Uniform System of Accounts Prescribed for Public Utilities, Licensees, and Others Subject To the Provisions of The Federal Power Act (18 C.F.R. Part 101), must submit FERC Form 1 (18 C.F.R. § 141.1), and FERC Form 3-Q (18 C.F.R. § 141.400).
Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following:
1. one million megawatt hours of total annual sales,
2. 100 megawatt hours of annual sales for resale,
3. 500 megawatt hours of annual power exchanges delivered, or
4. 500 megawatt hours of annual wheeling for others (deliveries plus losses).

What and Where to Submit

Submit FERC Form Nos. 1 and 3-Q electronically through the eCollection portal at https://eCollection.ferc.gov, and according to the specifications in the Form 1 and 3-Q taxonomies.
The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings.
Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report to the Secretary of the Commission at:
Secretary
Federal Energy Regulatory Commission 888 First Street, NE
Washington, DC 20426

For the CPA Certification Statement, submit within 30 days after filing the FERC Form 1, a letter or report (not applicable to filers classified as Class C or Class D prior to January 1, 1984). The CPA Certification Statement can be either eFiled or mailed to the Secretary of the Commission at the address above.

The CPA Certification Statement should:

Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with the Commission's applicable Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and

Be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 41.10-41.12 for specific qualifications.)

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

The following format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained in the letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported.
“In connection with our regular examination of the financial statements of [COMPANY NAME] for the year ended on which we have reported separately under date of [DATE], we have also reviewed schedules [NAME OF SCHEDULES] of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.
Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.” The letter or report must state which, if any, of the pages above do not conform to the Commission’s requirements. Describe the discrepancies that exist.
Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. Further instructions are found on the Commission’s website at https://www.ferc.gov/ferc-online/ferc-online/frequently-asked-questions-faqs-efilingferc-online.
Federal, State, and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q free of charge from https://www.ferc.gov/general-information-0/electric-industry-forms.

When to Submit
FERC Forms 1 and 3-Q must be filed by the following schedule:
1. FERC Form 1 for each year ending December 31 must be filed by April 18th of the following year (18 CFR § 141.1), and
2. FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. § 141.400).
Where to Send Comments on Public Reporting Burden.
The public reporting burden for the FERC Form 1 collection of information is estimated to average 1,168 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the FERC Form 3-Q collection of information is estimated to average 168 hours per response.
Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S.C. § 3512 (a)).

GENERAL INSTRUCTIONS

Prepare this report in conformity with the Uniform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and phrases in accordance with the USofA.
Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts.
Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact.
For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3.
Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below).
Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
For any resubmissions, please explain the reason for the resubmission in a footnote to the data field.
Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used.
Schedule specific instructions are found in the applicable taxonomy and on the applicable blank rendered form.

Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:

FNS - Firm Network Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. "Self" means the respondent.

FNO - Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff.

LFP - for Long-Term Firm Point-to-Point Transmission Reservations. "Long-Term" means one year or longer and” firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Reservations" are described in Order No. 888 and the Open Access Transmission Tariff. For all transactions identified as LFP, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally cancel the contract.

OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and “firm” means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.

SFP - Short-Term Firm Point-to-Point Transmission Reservations. Use this classification for all firm point-to-point transmission reservations, where the duration of each period of reservation is less than one-year.

NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions.

OS - Other Transmission Service. Use this classification only for those services which can not be placed in the above-mentioned classifications, such as all other service regardless of the length of the contract and service FERC Form. Describe the type of service in a footnote for each entry.

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.

DEFINITIONS

Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization.
Respondent -- The person, corporation, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is made.

EXCERPTS FROM THE LAW

Federal Power Act, 16 U.S.C. § 791a-825r

Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:

’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined;
'Person' means an individual or a corporation;
'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof;

'municipality means a city, county, irrigation district, drainage district, or other political subdivision or agency of a State competent under the Laws thereof to carry and the business of developing, transmitting, unitizing, or distributing power; ......

"project' means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the primary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit;

"Sec. 4. The Commission is hereby authorized and empowered

'To make investigations and to collect and record data concerning the utilization of the water 'resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development costs, and relation to markets of power sites; ... to the extent the Commission may deem necessary or useful for the purposes of this Act."

"Sec. 304.

Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the Commission may by rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the proper administration of this Act. The Commission may prescribe the manner and FERC Form in which such reports shall be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies*.10

"Sec. 309.

The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and the time within which they shall be field..."

GENERAL PENALTIES

The Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).

FERC FORM NO.

1

REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER

IDENTIFICATION

01 Exact Legal Name of Respondent

AEP Ohio Transmission Company, Inc.

02 Year/ Period of Report

End of:

2021

/

Q4

03 Previous Name and Date of Change (If name changed during year)

/

04 Address of Principal Office at End of Period (Street, City, State, Zip Code)

1 Riverside Plaza, 26th Flr, Columbus, Ohio 43215-2373

05 Name of Contact Person

Jason M. Johnson

06 Title of Contact Person

Accountant

07 Address of Contact Person (Street, City, State, Zip Code)

1 Riverside Plaza, 26th Flr, Columbus, Ohio 43215-2373

08 Telephone of Contact Person, Including Area Code

(614) 716-1000

09 This Report is An Original / A Resubmission

(1)

☐ An Original

(2)

☑ A Resubmission

10 Date of Report (Mo, Da, Yr)

05/19/2022

Annual Corporate Officer Certification

The undersigned officer certifies that:

I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts.

01 Name

Jeffrey W. Hoersdig

02 Title

Assistant Controller

03 Signature

Jeffrey W. Hoersdig

04 Date Signed (Mo, Da, Yr)

05/19/2022

Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	N/A
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	N/A
16	ScheduleElectricPlantInServiceAbstract Electric Plant in Service	204
17	ScheduleElectricPropertyLeasedToOthersAbstract Electric Plant Leased to Others	213	N/A
18	ScheduleElectricPlantHeldForFutureUseAbstract Electric Plant Held for Future Use	214	N/A
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	N/A
22	ScheduleMaterialsAndSuppliesAbstract Materials and Supplies	227
23	ScheduleAllowanceInventoryAbstract Allowances	228	N/A
24	ScheduleExtraordinaryPropertyLossesAbstract Extraordinary Property Losses	230a	N/A
25	ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract Unrecovered Plant and Regulatory Study Costs	230b	N/A
26	ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract Transmission Service and Generation Interconnection Study Costs	231	N/A
27	ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets	232
28	ScheduleMiscellaneousDeferredDebitsAbstract Miscellaneous Deferred Debits	233
29	ScheduleAccumulatedDeferredIncomeTaxesAbstract Accumulated Deferred Income Taxes	234
30	ScheduleCapitalStockAbstract Capital Stock	250	N/A
31	ScheduleOtherPaidInCapitalAbstract Other Paid-in Capital	253
32	ScheduleCapitalStockExpenseAbstract Capital Stock Expense	254b	N/A
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	N/A
37	ScheduleOtherDeferredCreditsAbstract Other Deferred Credits	269
38	ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract Accumulated Deferred Income Taxes-Accelerated Amortization Property	272	N/A
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	N/A
44	ScheduleSalesOfElectricityByRateSchedulesAbstract Sales of Electricity by Rate Schedules	304	N/A
45	ScheduleSalesForResaleAbstract Sales for Resale	310	N/A
46	ScheduleElectricOperationsAndMaintenanceExpensesAbstract Electric Operation and Maintenance Expenses	320
47	SchedulePurchasedPowerAbstract Purchased Power	326	N/A
48	ScheduleTransmissionOfElectricityForOthersAbstract Transmission of Electricity for Others	328
49	ScheduleTransmissionOfElectricityByIsoOrRtoAbstract Transmission of Electricity by ISO/RTOs	331	N/A
50	ScheduleTransmissionOfElectricityByOthersAbstract Transmission of Electricity by Others	332	N/A
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	N/A
56	ScheduleCommonUtilityPlantAndExpensesAbstract Common Utility Plant and Expenses	356	N/A
57	ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract Amounts included in ISO/RTO Settlement Statements	397	N/A
58	SchedulePurchasesSalesOfAncillaryServicesAbstract Purchase and Sale of Ancillary Services	398	N/A
59	ScheduleMonthlyTransmissionSystemPeakLoadAbstract Monthly Transmission System Peak Load	400	N/A
60	ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract Monthly ISO/RTO Transmission System Peak Load	400a	N/A
61	ScheduleElectricEnergyAccountAbstract Electric Energy Account	401a	N/A
62	ScheduleMonthlyPeakAndOutputAbstract Monthly Peaks and Output	401b	N/A
63	ScheduleSteamElectricGeneratingPlantStatisticsAbstract Steam Electric Generating Plant Statistics	402	N/A
64	ScheduleHydroelectricGeneratingPlantStatisticsAbstract Hydroelectric Generating Plant Statistics	406	N/A
65	SchedulePumpedStorageGeneratingPlantStatisticsAbstract Pumped Storage Generating Plant Statistics	408	N/A
66	ScheduleGeneratingPlantStatisticsAbstract Generating Plant Statistics Pages	410	N/A
0	ScheduleEnergyStorageOperationsLargePlantsAbstract Energy Storage Operations (Large Plants)	414	N/A
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

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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, 26th Flr, Columbus, Ohio 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: 2009-10-02 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

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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.

AEP Transmission Company, LLC, controls 100% of the Respondent as of December 31, 2021. AEP Transmission Holding Company, LLC, controls 100% of AEP Transmission Company, LLC as of December 31, 2021. American Electric Power Company, Inc., a registered holding company, controls 100% of AEP Transmission Holding Company, LLC as of December 31, 2021.

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	Not Applicable

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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) See Footnote

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: OfficerTitle

Summary Compensation Table The following table provides summary information concerning compensation earned by our Chief Executive Officer, our Chief Financial Officer and the three other most highly compensated executive officers, to whom we refer collectively as the named executive officers.


Name and Principal Position	Year	Salary ($)(1)	Bonus ($)	Stock Awards ($)(2)	Non-Equity Incentive Plan Compensation ($)(3)	Change in Pension Value and Nonqualified Deferred Compensation Earnings ($)(4)	All Other Compensation ($)(5)	Total ($)
Nicholas K. Akins
Chair of the Board and Chief Executive Officer	2021	1,515,808		9,976,149	2,850,000	461,732	247,526	15,051,215


Julia A. Sloat
Executive Vice President and Chief Financial Officer	2021	602,308		1,628,789	637,350	76,622	58,042	3,003,111


Lisa M. Barton
Executive Vice President and Chief Operating Officer	2021	803,077		2,443,104	890,000	165,173	88,143	4,389,497


David M. Feinberg
Executive Vice President, General Counsel and Secretary	2021	696,669		1,527,000	690,000	93,625	98,652	3,105,946


Charles E. Zebula
Executive Vice President - Portfolio Optimization	2021	579,219		1,323,341	640,000	42,921	71,745	2,657,226


Brian X. Tierney
Former Executive Vice President - Strategy	2021	410,000	—	2,675,947	—	—	732,507	3,818,454


Mark C. McCullough
Former Executive Vice President - Energy Delivery	2021	322,327	—	1,823,341	—	—	1,115,159	3,260,827

a. Amounts in the salary column are composed of executive salaries earned for the year shown, which include 261 days of pay for 2021. This is one day more than the standard 260 calendar work days and holidays in a year.

b. The amounts reported in this column reflect the aggregate grant date fair value calculated in accordance with FASB ASC Topic 718 of the performance shares, restricted stock units (RSUs) and unrestricted shares granted under our Long-Term Incentive Plan. See Note 15 to the Consolidated Financial Statements included in our Form 10-K for the year ended December 31, 2021 for a discussion of the relevant assumptions used in calculating these amounts. The number of shares realized and the value of the performance shares, if any, will depend on the Company’s performance during a 3-year performance period. The potential payout can range from 0 percent to 200 percent of the target number of performance shares, plus any dividend equivalents. The value of the 2021 performance shares will be based on three measures: a Board approved cumulative operating earnings per share measure (Cumulative EPS 50%), a total shareholder return measure (Relative TSR 40%) and a carbon free capacity mix (Carbon Free Capacity 10%). The grant date fair value of the 2021 performance shares that are based on Cumulative EPS was computed in accordance with FASB ASC Topic 718 and was measured based on the closing price of AEP’s common stock on the grant date. The maximum amount payable for the 2021 performance shares that are based on Cumulative EPS measured on the grant date was $7,350,035 for Mr. Akins; $1,200,060 for Ms. Sloat; $1,800,012 for Ms. Barton; $1,125,066 for Mr. Feinberg; $975,000 for Mr. Zebula; $1,500,036 for Mr. Tierney; and $975,000 for Mr. McCullough. The maximum amount payable for the 2021 performance shares that are based on Carbon Free

Capacity is equal to $1,470,007 for Mr. Akins; $240,012 for Ms. Sloat; $360,002 for Ms. Barton; $225,013 for Mr. Feinberg; $195,000 for Mr. Zebula; $300,007 for Mr. Tierney; and $195,000 for Mr. McCullough. The grant date fair value of the 2021 performance shares that are based on Relative TSR is calculated using a Monte-Carlo model as of the date of grant, in accordance with FASB ASC Topic 718. Because the performance shares that are based on Relative TSR are subject to market conditions as defined under FASB ASC Topic 718, they did not have a maximum value on the grant date that differed from the grant date fair values presented in the table. Instead, the maximum value is factored into the calculation of the grant date fair value. The values realized from the 2019 performance shares are included in the Option Exercises and Stock Vested for 2021 table.

c. The amounts shown in this column reflect annual incentive compensation paid for the year shown.

a. The amounts shown in this column are attributable to the increase in the actuarial values of each of the named executive officer’s combined benefits under AEP’s qualified and non-qualified defined benefit pension plans determined using interest rate and mortality assumptions consistent with those used in the Company’s financial statements. Negative values of ($404,033) and ($269,258) for Messrs. Tierney and McCullough, respectfully, were replaced with $0 for the purposes of the Summary Compensation Table. These negative values were caused by their severance from the company during 2021, which resulted in the removal of projected benefits that would have been attributable to eligible earnings for future years under these plans. See the Pension Benefits for 2021 table and related footnotes for additional information. See Note 8 to the Consolidated Financial Statements included in our Form 10-K for the year ended December 31, 2021 for a discussion of the relevant assumptions. None of the named executive officers received preferential or above-market earnings on deferred compensation.

a. Amounts shown in the All Other Compensation column for 2021 include: (a) Company matching contributions to the Company’s Retirement Savings Plan, (b) Company matching contributions to the Company’s Supplemental Retirement Savings Plan, (c) perquisites, (d) vacation payout, and (e) severance benefits. The 2021 values for these items are listed in the following table:


Type	Nicholas K. Akins	Julia A. Sloat	Lisa M. Barton	David M. Feinberg	Charles E. Zebula	Brian X. Tierney	Mark C. McCullough
Retirement Savings Plan Match	13,050	13,050	13,050	13,050	13,050	13,050	13,050
Supplemental Retirement Savings Plan Match	212,400	31,272	61,373	56,295	46,665	53,097	35,468
Perquisites	22,076	13,720	13,720	29,307	12,030	6,360	6,804
Vacation Payout	—	—	—	—	—	41,000	60,837
Severance	—	—	—	—	—	619,000	999,000
Total	$ 247,52	$ 58,04	$ 88,14	$ 98,65	$ 71,74	$ 732,50	$ 1,115,15

a. Ms. Sloat's compensation is provided only for the years in which she was an executive officer of the Company.

Perquisites provided in 2021 included: financial counseling and tax preparation services and, for Mr. Akins, director’s group travel accident insurance premium. Executive officers may also have the occasional personal use of event tickets when such tickets are not being used for business purposes; however, there is no associated incremental cost. From time-to-time executive officers may receive customary gifts from third parties that sponsor events (subject to our policies on conflicts of interest).

Mr. Akins has entered into an Aircraft Time Sharing Agreement that allows him to use our corporate aircraft for personal use for a limited number of hours each year. The Aircraft Time Sharing Agreement requires Mr. Akins to reimburse the Company for the cost of his personal use of corporate aircraft in accordance with limits set forth in Federal Aviation Administration regulations. Mr. Akins reimbursed the Company all incremental costs incurred in connection with personal flights under the Aircraft Timesharing Agreement including fuel, oil, hangar costs, crew travel expenses, catering, landing fees and other incremental airport fees. Accordingly, no value is shown for these amounts in the Summary Compensation Table. If the aircraft flies empty before picking up or after dropping off Mr. Akins at a destination on a personal flight, the cost of the empty flight is included in the incremental cost for which Mr. Akins reimburses the Company. Since AEP aircraft are used predominantly for business purposes, we do not include fixed costs that do not change in amount based on usage, such as depreciation and pilot salaries.

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	David M. Feinberg, Vice President and Secretary	Columbus, Ohio	false	false
3	(a) Scott P.Moore, Vice President	Columbus, Ohio	false	false
4	(b) Julia A.Sloat, Chief Financial Office and Vice President	Columbus, Ohio	false	false
5	(c) Toby L.Thomas , President and Chief Operating Officer	Columbus, Ohio	false	false
6	(d) Wade A. Smith, Vice President	Columbus, Ohio	false	false
7	(e) Mark C. McCullough, President and Chief Operating Officer	Columbus, Ohio	false	false
8	Note: Respondent does not have an Executive Committee

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: NameAndTitleOfDirector

Elected effective 5/2/2021

(b) Concept: NameAndTitleOfDirector

Elected effective 1/1/2021

(c) Concept: NameAndTitleOfDirector

Elected effective 7/31/2021

(d) Concept: NameAndTitleOfDirector

Resigned effective 5/1/2021

(e) Concept: NameAndTitleOfDirector

Resigned effective 7/30/2021

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	FERC OATT, PJM Interconnection LLC - Attachment H-20	ER17-406

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	20210525-5244	05/25/2021	ER17-406	AEP PJM OATT Annual Formula Rate	PJM OATT Attachment H-20
2	20211101-5316	11/01/2021	ER17-406	AEP PJM OATT Annual Formula Rate	PJM OATT Attachment H-20
3	20211221-5278	12/21/2021	ER17-406	AEP PJM OATT Annual Formula Rate	PJM OATT Attachment H-20

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
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

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

IMPORTANT CHANGES DURING THE QUARTER/YEAR
Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments. State the estimated annual effect and nature of any important wage scale changes during the year. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Pages 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest. (Reserved.) If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.

None
None
The notification for the acquisition by AEP Ohio Transmission Company of certain transmission assets from Hog Creek Wind Project, LLC was submitted to FERC on March 5, 2020. The Commission authorized the transaction in Docket No. EC20-1-000
None
None
AEP Ohio Transmission Company Intercompany Note $160M State Authority: Case No. 20-1513-EL-AIS FERC Authority: N/A Issued: 8/4/2021 Maturity: 8/15/2051
None
None
None
None
Not Used
Julia A. Sloat elected as Director and Chief Financial Officer on Jan 01, 2021 Julie A. Sherwood elected as Vice President and Treasurer on Jan 01, 2021 Daniel E. Mueller elected as Assistant Vice President Tax on Mar 24, 2021 Scott P. Moore elected as Director and Vice President on May 02, 2021 Wade A Smith resigned as Director and Vice President on May 01, 2021 Charles E Zebula elected as Vice President on July 03, 2021 Toby L Thomas elected as Director, President and Chief Operating Officer on July 31, 2021 Mark C McCullough resigned as Director, President and Chief Operating Officer on July 30, 2021
Proprietary capital ratio exceeds 30%

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	4,893,892,345	4,278,394,455
3	ConstructionWorkInProgress Construction Work in Progress (107)	200	457,843,906	517,875,622
4	UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3)		5,351,736,252	4,796,270,077
5	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)	200	492,333,214	368,028,050
6	UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5)		4,859,403,038	4,428,242,027
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)		4,859,403,038	4,428,242,027
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	AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122)
20	InvestmentInAssociatedCompanies Investments in Associated Companies (123)
21	InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1)	224
23	NoncurrentPortionOfAllowances Noncurrent Portion of Allowances	228
24	OtherInvestments Other Investments (124)		82,785	502,846
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)
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)		82,785	502,846
33	CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS
34	CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130)
35	Cash Cash (131)
36	SpecialDeposits Special Deposits (132-134)
37	WorkingFunds Working Fund (135)
38	TemporaryCashInvestments Temporary Cash Investments (136)
39	NotesReceivable Notes Receivable (141)
40	CustomerAccountsReceivable Customer Accounts Receivable (142)		7,770,321	6,668,188
41	OtherAccountsReceivable Other Accounts Receivable (143)
42	AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144)
43	NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145)
44	AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146)		52,814,179	43,384,329
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	9,255,545	8,445,166
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)		827,725	2,700,316
58	AdvancesForGas Advances for Gas (166-167)
59	InterestAndDividendsReceivable Interest and Dividends Receivable (171)
60	RentsReceivable Rents Receivable (172)
61	AccruedUtilityRevenues Accrued Utility Revenues (173)
62	MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174)
63	DerivativeInstrumentAssets Derivative Instrument Assets (175)
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)		70,667,770	61,197,999
68	DeferredDebitsAbstract DEFERRED DEBITS
69	UnamortizedDebtExpense Unamortized Debt Expenses (181)		12,996,950	11,935,648
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	55,296,952	55,189,709
73	PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183)
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	213,244,876	191,184,838
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)
82	AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190)	234	47,571,018	47,729,628
83	UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191)
84	DeferredDebits Total Deferred Debits (lines 69 through 83)		329,109,795	306,039,823
85	AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84)		5,259,263,388	4,795,982,695

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
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	1,120,500,000	1,075,500,000
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	1,159,997,026	906,610,082
12	UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1)	118
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)
16	ProprietaryCapital Total Proprietary Capital (lines 2 through 15)		2,280,497,026	1,982,110,082
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	1,780,700,000	1,640,700,000
21	OtherLongTermDebt Other Long-Term Debt (224)	256
22	UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225)		209,740	252,399
23	UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226)		5,118,870	4,695,184
24	LongTermDebt Total Long-Term Debt (lines 18 through 23)		1,775,790,869	1,636,257,215
25	OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES
26	ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227)		523,240	443,390
27	AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1)
28	AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2)
29	AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3)
30	AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4)
31	AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229)			2,174,078
32	LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities
33	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges
34	AssetRetirementObligations Asset Retirement Obligations (230)
35	OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34)		523,240	2,617,468
36	CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES
37	NotesPayable Notes Payable (231)
38	AccountsPayable Accounts Payable (232)		91,559,813	116,281,801
39	NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233)		34,999,773	45,768,738
40	AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234)		23,848,989	35,115,048
41	CustomerDeposits Customer Deposits (235)
42	TaxesAccrued Taxes Accrued (236)	262	400,636,604	350,322,616
43	InterestAccrued Interest Accrued (237)
44	DividendsDeclared Dividends Declared (238)
45	MaturedLongTermDebt Matured Long-Term Debt (239)
46	MaturedInterest Matured Interest (240)
47	TaxCollectionsPayable Tax Collections Payable (241)
48	MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242)		82,152	2,986
49	ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243)		427,398	687,320
50	DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244)
51	LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities
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)		551,554,729	548,178,509
55	DeferredCreditsAbstract DEFERRED CREDITS
56	CustomerAdvancesForConstruction Customer Advances for Construction (252)
57	AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255)	266
58	DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256)
59	OtherDeferredCredits Other Deferred Credits (253)	269	1,262,773	675,649
60	OtherRegulatoryLiabilities Other Regulatory Liabilities (254)	278	213,962,726	214,021,663
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)		419,340,306	396,006,283
64	AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283)		16,331,720	16,115,826
65	DeferredCredits Total Deferred Credits (lines 56 through 64)		650,897,524	626,819,421
66	LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)		5,259,263,388	4,795,982,695

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	706,783,609	569,698,915			706,783,609	569,698,915
3	OperatingExpensesAbstract Operating Expenses
4	OperationExpense Operation Expenses (401)	320	40,662,501	39,306,963			40,662,501	39,306,963
5	MaintenanceExpense Maintenance Expenses (402)	320	6,340,927	4,294,382			6,340,927	4,294,382
6	DepreciationExpense Depreciation Expense (403)	336	123,085,011	103,150,944			123,085,011	103,150,944
7	DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1)	336
8	AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405)	336	8,161,880	6,594,980			8,161,880	6,594,980
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)
13	RegulatoryCredits (Less) Regulatory Credits (407.4)
14	TaxesOtherThanIncomeTaxesUtilityOperatingIncome Taxes Other Than Income Taxes (408.1)	262	183,749,407	160,325,497			183,749,407	160,325,497
15	IncomeTaxesOperatingIncome Income Taxes - Federal (409.1)	262	40,845,799	17,385,776			40,845,799	17,385,776
16	IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1)	262	143,713	936			143,713	936
17	ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1)	234, 272	32,098,712	55,376,232			32,098,712	55,376,232
18	ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1)	234, 272	12,622,247	29,445,084			12,622,247	29,445,084
19	InvestmentTaxCreditAdjustments Investment Tax Credit Adj. - Net (411.4)	266
20	GainsFromDispositionOfPlant (Less) Gains from Disp. of Utility Plant (411.6)
21	LossesFromDispositionOfServiceCompanyPlant Losses from Disp. of Utility Plant (411.7)
22	GainsFromDispositionOfAllowances (Less) Gains from Disposition of Allowances (411.8)
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)		422,465,704	356,988,754			422,465,704	356,988,754
27	NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25)		284,317,905	212,710,161			284,317,905	212,710,161
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)
34	ExpensesOfNonutilityOperations (Less) Expenses of Nonutility Operations (417.1)
35	NonoperatingRentalIncome Nonoperating Rental Income (418)		550	500
36	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1)	119
37	InterestAndDividendIncome Interest and Dividend Income (419)		54,514	176,204
38	AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1)		21,717,887	25,910,814
39	MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421)		68,475	4,766
40	GainOnDispositionOfProperty Gain on Disposition of Property (421.1)		56,349
41	OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40)		21,897,775	26,092,284
42	OtherIncomeDeductionsAbstract Other Income Deductions
43	LossOnDispositionOfProperty Loss on Disposition of Property (421.2)		654,757	12,641
44	MiscellaneousAmortization Miscellaneous Amortization (425)
45	Donations Donations (426.1)		26,311	13,185
46	LifeInsurance Life Insurance (426.2)
47	Penalties Penalties (426.3)		854,095	1,041
48	ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4)		246,465	219,014
49	OtherDeductions Other Deductions (426.5)		101,180	75,730
50	OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49)		1,882,808	321,611
51	TaxesApplicableToOtherIncomeAndDeductionsAbstract Taxes Applic. to Other Income and Deductions
52	TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions Taxes Other Than Income Taxes (408.2)	262
53	IncomeTaxesFederal Income Taxes-Federal (409.2)	262	8,471,925	3,416,720
54	IncomeTaxesOther Income Taxes-Other (409.2)	262	4,441	4,956
55	ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2)	234, 272	235,565	474,966
56	ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions (Less) Provision for Deferred Income Taxes-Cr. (411.2)	234, 272	474,966	164,863
57	InvestmentTaxCreditAdjustmentsNonutilityOperations Investment Tax Credit Adj.-Net (411.5)
58	InvestmentTaxCredits (Less) Investment Tax Credits (420)
59	TaxesOnOtherIncomeAndDeductions TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)		8,715,768	3,101,661
60	NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59)		28,730,736	28,872,334
61	InterestChargesAbstract Interest Charges
62	InterestOnLongTermDebt Interest on Long-Term Debt (427)
63	AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428)		887,997	835,276
64	AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1)
65	AmortizationOfPremiumOnDebtCredit (Less) Amort. of Premium on Debt-Credit (429)		42,659	42,659
66	AmortizationOfGainOnReacquiredDebtCredit (Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67	InterestOnDebtToAssociatedCompanies Interest on Debt to Assoc. Companies (430)		65,163,359	62,082,570
68	OtherInterestExpense Other Interest Expense (431)		473,013	452,118
69	AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)		6,820,014	8,958,550
70	NetInterestCharges Net Interest Charges (Total of lines 62 thru 69)		59,661,697	54,368,755
71	IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70)		253,386,944	187,213,740
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)		253,386,944	187,213,740

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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		906,610,082	719,396,427
2	ChangesAbstract Changes
3	AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439)
4	AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit
4.1	AdjustmentsToRetainedEarningsCredit Adoption of ASC 326	123		85
9	AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439)			85
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)		253,386,944	187,213,740
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)
36	DividendsDeclaredCommonStock TOTAL Dividends Declared-Common Stock (Acct. 438)
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)		1,159,997,026	906,610,082
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)		1,159,997,026	906,610,082
	UnappropriatedUndistributedSubsidiaryEarningsAbstract UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49	UnappropriatedUndistributedSubsidiaryEarnings Balance-Beginning of Year (Debit or Credit)
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)

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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)	253,386,944	187,213,740
3	NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income:
4	DepreciationAndDepletion Depreciation and Depletion	131,246,891	109,745,924
5	NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details)
5.1	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Amortization of
8	DeferredIncomeTaxesNet Deferred Income Taxes (Net)	19,237,064	26,241,251
9	InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net)
10	NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables	10,531,983	10,296,718
11	NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory	810,379	609,459
12	NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory
13	NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses	47,288,520	74,079,237
14	NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets	4,305,283	4,029,646
15	NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities
16	AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction	21,717,887	25,910,814
17	UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies
18	OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote):
18.1	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other (provide details in footnote):	(a) 20,696,645	20,160,283
22	NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)	401,707,808	337,492,150
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)	587,692,186	678,438,856
27	GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel
28	GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant
29	GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant
30	AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction	21,717,887	25,910,814
31	OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote):
31.1	OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Other (provide details in footnote):
31.2	OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Acquired Assets	8,247,956	3,588,199
34	CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33)	574,222,254	656,116,241
36	AcquisitionOfOtherNoncurrentAssets Acquisition of Other Noncurrent Assets (d)
37	ProceedsFromDisposalOfNoncurrentAssets Proceeds from Disposal of Noncurrent Assets (d)	551,502	766,411
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 Insurance Receivable	0	244,073
53.2	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Notes Receivable from Associated Companies
57	CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)	573,670,752	655,105,757
59	CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities:
60	ProceedsFromIssuanceAbstract Proceeds from Issuance of:
61	ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b)	160,000,000	182,000,000
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 Issuances Costs	2,268,090	1,998,102
66	NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c)
67	OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote):
67.1	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote):
67.2	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Notes Payable to Associated Companies - Issued		27,611,709
67.3	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Capital Contributions from Parent	45,000,000	110,000,000
70	CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69)	202,731,910	317,613,607
72	PaymentsForRetirementAbstract Payments for Retirement of:
73	PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b)	20,000,000
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	10,768,965
78	NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c)
80	DividendsOnPreferredStock Dividends on Preferred Stock
81	DividendsOnCommonStock Dividends on Common Stock
83	CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)	171,962,945	317,613,607
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)
88	CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period
90	CashAndCashEquivalents Cash and Cash Equivalents at End of Period

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities


	2021 Cash Flow Incr / (Decr)		2020 Cash Flow Incr / (Decr)
Utility Plant, Net	$	(161,914)	$	(467,962)
Property and Investments, Net	420,061		—
Prepayments	1,872,591		(405,537)
Unamortized Debt Expense	589,188		671,951
Other Deferred Debits, Net	(22,256,082)		(21,539,483)
Proprietary Capital, Net	—		(86)
Unamortized Discount/Premium on Long-Term Debt	151,255		76,636
Accumulated Provisions - Misc	—		2,174,078
Current and Accrued Liabilities, Net	(2,094,912)		(666,453)
Other Deferred Credits, Net	783,168		(3,427)
Total	$	(20,696,645)	$	(20,160,283)

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

NOTES TO FINANCIAL STATEMENTS

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

INDEX OF NOTES TO FINANCIAL STATEMENTS


			Glossary of Terms for Notes
1.			Organization and Summary of Significant Accounting Policies
2.			New Accounting Standards
3.			Rate Matters
4.			Effects of Regulation
5.			Commitments, Guarantees and Contingencies
6.			Fair Value Measurements
7.			Income Taxes
8.			Financing Activities
9.			Related Party Transactions
10.			Transmission Property
11.			Revenue from Contracts with Customers

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 East Transmission Companies						APTCo, IMTCo, KTCo, OHTCo and WVTCo.
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 Onsite Partners						AEP Onsite Partners, LLC, a subsidiary of AEP, owns distributed generation assets and sells the output to schools, municipalities, hospitals, and other commercial and industrial customers.
AEP System						American Electric Power System, an electric system, owned and operated by AEP subsidiaries.
AEP Texas						AEP Texas Inc., an AEP electric utility subsidiary.
AEP Transmission Holdco						AEP Transmission Holding Company, LLC, a wholly-owned subsidiary of AEP.
AEPEP						AEP Energy Partners, Inc., a subsidiary of AEP dedicated to wholesale marketing and trading, hedging activities, asset management and commercial and industrial sales in deregulated markets.
AEPSC						American Electric Power Service Corporation, an AEP service subsidiary providing management and professional services to AEP and its subsidiaries.
AEPTCo						AEP Transmission Company, LLC, and its consolidated State Transcos, a subsidiary of AEP Transmission Holdco.
AGR						AEP Generation Resources Inc., a competitive AEP subsidiary in the Generation & Marketing segment.
APCo						Appalachian Power Company, an AEP electric utility subsidiary.
APTCo						AEP Appalachian Transmission Company, Inc., a wholly-owned AEPTCo transmission subsidiary.
ARAM						Average Rate Assumption Method, an IRS approved method used to calculate the reversal of Excess ADIT for ratemaking purposes.
ATRR						Annual Transmission Revenue Requirement.
Excess ADIT						Excess accumulated deferred income taxes.
FASB						Financial Accounting Standards Board.
FERC						Federal Energy Regulatory Commission.
Grid Assurance						Grid Assurance, LLC, a jointly-owned organization between AEP Transmission Holdco and certain nonaffiliated entities formed to procure critical transmission equipment, manage inventory of critical transmission equipment and provide logistics support to facilitate the rapid deployment of large power transformers and other critical equipment to recover from grid emergencies.
I&M						Indiana Michigan Power Company, an AEP electric utility subsidiary.
IMTCo						AEP Indiana Michigan Transmission Company, Inc., a wholly-owned AEPTCo transmission subsidiary.
IRS						Internal Revenue Service.
KPCo						Kentucky Power Company, an AEP electric utility subsidiary.
KTCo						AEP Kentucky Transmission Company, Inc., a wholly-owned AEPTCo transmission subsidiary.


OATT						Open Access Transmission Tariff.
OHTCo						AEP Ohio Transmission Company, Inc., a wholly-owned AEPTCo transmission subsidiary.
OKTCo						AEP Oklahoma Transmission Company, Inc., a wholly-owned AEPTCo transmission subsidiary.
OPCo						Ohio Power Company, an AEP electric utility subsidiary.
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.
ROE						Return on equity.
RTO						Regional Transmission Organization, responsible for moving electricity over large interstate areas.
SPP						Southwest Power Pool.
State Transcos						Wholly-owned AEPTCo transmission subsidiaries; APTCo, IMTCo, KTCo, OHTCo, OKTCo, SWTCo and WVTCo.
SWEPCo						Southwestern Electric Power Company, an AEP electric utility subsidiary.
SWTCo						AEP Southwestern Transmission Company, Inc., a wholly-owned AEPTCo transmission subsidiary.
Transource Energy						Transource Energy, LLC, a consolidated variable interest entity formed for the purpose of investing in utilities which develop, acquire, construct, own and operate transmission facilities in accordance with FERC-approved rates.
Utility Money Pool						Centralized funding mechanism AEP uses to meet the short-term cash requirements of certain utility subsidiaries.
WPCo						Wheeling Power Company, an AEP electric utility subsidiary.
WVTCo						AEP West Virginia Transmission Company, Inc., a wholly-owned AEPTCo transmission subsidiary.

1. ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

ORGANIZATION

OHTCo builds, owns and operates transmission facilities in Ohio. OHTCo is a member of PJM. AEPTCo owns all of OHTCo’s outstanding equity. Currently, all of OHTCo’s capital needs are provided by AEPTCo and the Utility Money Pool. AEPSC and other AEP subsidiaries provide services to OHTCo through service agreements. OHTCo does not have employees.

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Rates and Service Regulation

OHTCo’s rates are regulated by the FERC. Historically, the FERC formula rates for OHTCo were established each July based on prior calendar year’s financial activity and projected plant balances. Effective January 1, 2017, OHTCo implemented the modified PJM OATT formula rate calculation which establishes the annual FERC formula rates on a calendar year basis using the projected calendar year’s financial activity and projected plant balances. Refer to Note 3 for additional information. The FERC also regulates OHTCo’s, AEPSC’s and AEPTCo’s affiliated transactions, including AEPSC’s and AEPTCo’s billings 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 OHTCo, the acquisition or sale of certain utility assets and mergers with another electric utility or holding company. The FERC is permitted to review and audit the relevant books and records of OHTCo.

Basis of Accounting

OHTCo’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:


•			The requirement to report deferred tax assets and liabilities separately rather than as a single amount.
•			The exclusion of current maturities of long-term debt from current liabilities.
•			The classification of accrued taxes as a single amount rather than as assets and liabilities.
•			The classification of accrued non-ARO asset removal costs as accumulated depreciation rather than regulatory liabilities.
•			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 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 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 operating lease assets as Utility Plant rather than as a noncurrent asset.
•			The presentation of obligations under operating leases as Obligations Under Capital Leases.
•			The classification of interest on regulated finance leases as Operating Expense instead of Other Income (Expense).
•			The classification of certain expenses in operating income rather than operating expenses.
•			The classification of cloud computing implementation costs as Utility Plant rather than as a noncurrent asset.

Accounting for the Effects of Cost-Based Regulation

As a rate-regulated entity, OHTCo’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. Under OHTCo’s formula rate mechanism and in accordance with accounting guidance for “Regulated Operations,” OHTCo records regulatory assets (deferred expenses) and regulatory liabilities (deferred revenue reductions or refunds) 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, long-lived asset impairment, the effects of regulation, long-lived asset recovery and the effects of contingencies. 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.

Supplementary Information


	2021		2020
For the Twelve Months Ended December 31,	(in thousands)
Cash Was Paid for:
Interest (Net of Capitalized Amounts)	$	56,768	$	51,610
Income Taxes (Net of Refunds)	29,122		16,805
As of December 31,
Construction Expenditures Included in Current and Accrued Liabilities	56,514		89,477

Inventory

Materials and supplies inventories are carried at average cost.

Accounts Receivable

Accounts receivable primarily includes receivables from PJM based on the monthly allocation of the tariff rates that were authorized by FERC order and receivables for sales to miscellaneous customers.

Transmission Property

Transmission property is stated at original cost. Additions, major replacements and betterments are added to the property accounts. Under the group composite method of depreciation, continuous interim routine replacements of items such as poles, transformers, 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 salvage received. These rates and the related lives are subject to periodic review. Removal costs are charged to accumulated depreciation. The costs of labor, materials and overhead incurred to operate and maintain the transmission property is included in operation 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, the cost of that asset shall be removed from plant-in-service or CWIP and charged to expense.

The fair value of an asset or investment is the amount at which that asset or investment 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 or investments 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)

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 transmission property.

Valuation of Nonderivative Financial Instruments

The book values of 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. Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2.

Revenue Recognition

Regulatory Accounting

OHTCo’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, OHTCo records them as assets on its balance sheets. OHTCo tests for probability of recovery at each balance sheet date or whenever new events occur. Examples of new events include the issuance of a FERC order or passage of new legislation. If it is determined that recovery of a regulatory asset is no longer probable, that regulatory asset is derecognized as a charge against income.

Transmission Revenue Accounting

Pursuant to an order approved by the FERC, the AEP East Transmission Companies are included in the OATT administered by PJM. The FERC order implemented an ATRR for each of the AEP East Transmission Companies. Under this requirement, AEPSC, on behalf of the AEP East Transmission Companies, makes annual filings in order to recover prudently incurred costs and an allowed return on plant in service. An annual formula rate filing is made for each calendar year using projected costs, which is used to determine the billings to PJM ratepayers. The annual rate filing is compared to actual costs with any over- or under-recovery being trued-up with interest and recovered in a future year’s rates.

In accordance with the accounting guidance for "Regulated Operations-Revenue Recognition", OHTCo recognizes revenue related to OATT rate true-ups immediately following the annual FERC filings. 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 Other Regulatory Assets or Other Regulatory Liabilities on the balance sheets.

Income Taxes

OHTCo 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 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.

OHTCo accounts for uncertain tax positions in accordance with the accounting guidance for “Income Taxes.” OHTCo 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.

Long-term Debt

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. The net amortization expense is included in Amortization of Debt Discount and Expense.

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 13, 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 OHTCo’s business. There are no new standards expected to have a material impact on OHTCo’s financial statements.

3. RATE MATTERS

OHTCo is involved in rate and regulatory proceedings at the FERC and the PUCO. This note discusses rate matters and related regulatory proceedings that could have a material effect on OHTCo’s results of operations, financial position and cash flows.

Formula Rate

The AEP East Transmission Companies, including OHTCo, submit an annual filing with the FERC and PJM which establishes their projected transmission revenue requirement (PTRR). The new rates become effective at the beginning of the year and are subject to refund and true-up.

OHTCo's 2020 PTRR was $571.1 million plus an additional $7.4 million of 2018 under-recovered revenues. In 2020, OHTCo had an under-recovery of revenues totaling $10.1 million, including carrying charges that were subject to true-up. The 2020 true-up of revenues was incorporated in the 2022 PTRR discussed below.

OHTCo's 2021 PTRR was $692.3 million. OHTCo refunded $12.9 million, including carrying charges, of 2019 over-recovered revenues in 2021. The 2021 true-up of revenues will be incorporated in the 2023 PTRR.

OHTCo's 2022 PTRR is $780.7 million plus an additional $10.1 million of 2020 under-recovered revenues. The 2022 true-up of revenues will be incorporated in the 2024 PTRR.

FERC Notice of Proposed Rule Making

In April 2021, the FERC issued a supplemental Notice of Proposed Rulemaking (NOPR) proposing to modify its incentive for transmission owners that join RTOs (RTO Incentive). Under the supplemental NOPR, the RTO Incentive would be modified such that a utility would only be eligible for the RTO Incentive for the first three years after the utility joins a FERC-approved Transmission Organization. This is a significant departure from a previous NOPR issued in 2020 seeking to increase the RTO Incentive from 50 basis points to 100 basis points. The supplemental NOPR also required utilities that have received the RTO Incentive for three or more years to

submit, within 30 days of the effective date of a final rule, a compliance filing to eliminate the incentive from its tariff prospectively. The supplemental NOPR was subject to a 60 day comment period followed by a 30 day period for reply comments. In July 2021, AEP submitted reply comments. AEP is awaiting a final rule from the FERC.

In July 2021, the FERC issued an order denying Dayton Power and Light’s request for a 50 basis point RTO incentive on the basis that its RTO participation was not voluntary, but rather is required by Ohio law. This precedent could have an impact on AEP’s transmission owning subsidiaries. In its February 2022 order on rehearing, the FERC affirmed the decision in its July 2021 order.

In 2019, the FERC approved settlement agreements establishing base ROEs of 9.85% (10.35% inclusive of RTO Incentive adder of 0.5%) and 10% (10.5% inclusive of RTO Incentive adder of 0.5%) for AEP’s PJM and SPP transmission-owning subsidiaries, respectively. In 2020, the FERC determined the base ROE for MISO’s transmission owning subsidiaries should be 10.02% (10.52% inclusive of RTO Incentive adder of 0.5%).

If the FERC modifies its RTO Incentive policy, it would be applied, as applicable, to OHTCo on a prospective basis, and could affect future net income and cash flows and impact financial condition.

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.

4. EFFECTS OF REGULATION

Regulatory assets and liabilities are comprised of the following items:


					Remaining
	December 31,				Recovery
Regulatory Assets:	2021		2020		Period
	(in thousands)
Regulatory assets approved for recovery:

Regulatory Assets Currently Not Earning a Return
Income Tax Assets Subject to Flow Through	$	54,564	$	50,152	31 years
PJM Annual Formula Rate True-Up	733		5,038		2 years
Total Regulatory Assets Currently Not Earning a Return	55,297		55,190

Total Regulatory Assets Approved for Recovery	55,297		55,190

Total FERC Account 182.3 Regulatory Assets	$	55,297	$	55,190


					Remaining
	December 31,				Refund
Regulatory Liabilities:	2021		2020		Period
	(in thousands)
Regulatory liabilities approved for payment:

Income Tax Related Regulatory Liabilities (a)
Excess ADIT Associated with Certain Depreciable Property	$	219,177	$	219,996	(b)
Excess ADIT that is Not Subject to Rate Normalization Requirements	(5,214)		(5,974)		7 years
Total Income Tax Related Regulatory Liabilities	213,963		214,022

Total Regulatory Liabilities Approved for Payment	213,963		214,022

Total FERC Account 254 Regulatory Liabilities	$	213,963	$	214,022

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

(b)Refunded using ARAM.

5. COMMITMENTS, GUARANTEES AND CONTINGENCIES

OHTCo is subject to certain claims and legal actions arising in its ordinary course of business. In addition, OHTCo’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. OHTCo 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, OHTCo 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

OHTCo has construction commitments to support its operations and investments. In managing the overall construction program and in the normal course of business, AEPSC provides project development services and OHTCo contractually commits to third-party construction vendors for certain material purchases and other construction services. OHTCo purchases materials, supplies, services and property, plant and equipment under contract as part of its normal course of business. Certain supply contracts contain penalty provisions for early termination.

In accordance with the accounting guidance for “Commitments”, OHTCo had no actual contractual commitments as of December 31, 2021.

GUARANTEES

Indemnifications

OHTCo enters into certain types of contracts which require indemnifications. Typically these contracts include, but are not limited to, 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. As of December 31, 2021, there were no material liabilities recorded for any indemnifications.

CONTINGENCIES

Insurance and Potential Losses

OHTCo maintains property insurance coverage normal and customary for an electric utility, subject to various deductibles. Insurance includes coverage for all risks of physical loss or damage to OHTCo property, subject to insurance policy conditions and exclusions. Covered property generally includes substations, facilities and inventories. Excluded property generally includes transmission lines, poles and towers. OHTCo’s insurance program also generally provides coverage against loss arising from certain claims made by third parties in excess of retentions absorbed by OHTCo. Coverage is generally provided by a combination of 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. 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.

6. 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 value and fair value of Long-term Debt are summarized in the following table:


	December 31, 2021				December 31, 2020
	Book Value		Fair Value		Book Value		Fair Value
	(in thousands)
Long-term Debt	$	1,775,791	$	2,018,008	$	1,636,257	$	2,046,239

7. INCOME TAXES

Income Tax Expense

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


	Years Ended December 31,
	2021		2020
	(in thousands)
Charged to Operating Expenses, Net:
Current	$	40,989	$	17,385
Deferred	19,476		25,931
Total	60,465		43,316

Charged (Credited) to Non-Operating Income, Net:
Current	(8,476)		(3,412)
Deferred	(239)		310
Total	(8,715)		(3,102)
Total Income Taxes	$	51,750	$	40,214

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 thousands)
Net Income	$	253,387		$	187,214
Income Tax Expense	51,750			40,214
Pretax Income	$	305,137		$	227,428

Income Taxes on Pretax Income at Statutory Rate (21%)	$	64,079		$	47,760
Increase (Decrease) in Income Taxes Resulting from the Following Items:
Depreciation	1,075			902
State and Local Income Taxes, Net	569			556
Allowance for Funds Used During Construction	(4,561)			(5,441)
Parent Company Loss Benefit	(8,441)			(3,387)
Other	(971)			(176)
Income Tax Expense	$	51,750		$	40,214

Effective Income Tax Rate	17.0		%	17.7		%

The following table shows elements of OHTCo’s net deferred tax liability and significant temporary differences:


	December 31,
	2021		2020
	(in thousands)
Deferred Tax Assets	$	47,571	$	47,730
Deferred Tax Liabilities	(435,672)		(412,122)
Net Deferred Tax Liabilities	$	(388,101)	$	(364,392)

Property Related Temporary Differences	$	(431,042)	$	(406,782)
Amounts Due to Customers for Future Income Taxes	45,239		45,251
Deferred State Income Taxes	(3,658)		(3,323)
Net Operating Loss Carryforward	—		289
All Other, Net	1,360		173
Net Deferred Tax Liabilities	$	(388,101)	$	(364,392)

AEP System Tax Allocation Agreement

OHTCo 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 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.

Federal and State Income Tax Audit Status

The statute of limitations for the IRS to examine OHTCo and other AEP subsidiaries originally filed federal return has expired for tax years 2016 and earlier. In the third quarter of 2019, OHTCo and other AEP subsidiaries elected to amend the 2014 through 2017 federal returns. In the first quarter of 2020, the IRS notified OHTCo 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 OHTCo and other AEP subsidiaries claimed on the amended returns. OHTCo 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.

OHTCo and other AEP subsidiaries file income tax returns in various state and local jurisdictions. These taxing authorities routinely examine the tax returns, and OHTCo 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.

8. FINANCING ACTIVITIES

Long-term Debt

The following table details Long-term Debt outstanding as follows:


		Weighted
		Average
		Interest
		Rate as of	Interest Rate Ranges as of		Outstanding as of
		December 31,	December 31,		December 31,
Type of Debt	Maturity	2021	2021	2020	2021		2020
					(in thousands)
Notes Payable - Affiliated	2022 - 2051	3.76%	2.75% - 5.52%	3.10% - 5.52%	$	1,780,700	$	1,640,700
Unamortized Discount, Net					(4,909)		(4,443)
Total Long-term Debt					$	1,775,791	$	1,636,257

Long-term Debt outstanding as of December 31, 2021 is payable as follows:


	(in thousands)
2022	$	83,200
2023	37,800
2024	37,900
2025	29,000
2026	47,000
After 2026	1,545,800
Principal Amount	1,780,700
Unamortized Discount, Net	(4,909)
Total Long-term Debt	1,775,791

Dividend Restrictions

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

All of the dividends declared by OHTCo 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 OHTCo is through the Federal Power Act restriction. As of December 31, 2021, the maximum amount of restricted net assets of OHTCo that may not be distributed to the AEPTCo in the form of a loan, advance or dividend was $1.1 billion.

Corporate Borrowing Program

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 the AEP System Utility Money Pool agreement filed with the FERC.

OHTCo’s amounts of outstanding borrowings from the Utility Money Pool as of December 31, 2021 and 2020 are included in Notes Payable to Associated Companies on the balance sheets. OHTCo’s money pool activity and its corresponding authorized borrowing limits are described in the following table:


	Maximum				Average
	Borrowings		Maximum		Borrowings		Average				Authorized
	from the		Loans to the		from the		Loans to the		Borrowings from		Short-term
Years Ended	Utility		Utility		Utility		Utility		the Utility Money		Borrowing
December 31,	Money Pool		Money Pool		Money Pool		Money Pool		Money Pool		Limit
	(in thousands)
2021	$	209,678	$	26,055	$	81,477	$	11,344	$	35,000	$	250,000
2020	143,011		73,164		59,435		30,997		45,769		250,000

Maximum, minimum and average interest rates for funds borrowed from and loaned to the Utility Money Pool were as follows:

Maximum

Minimum

Maximum

Minimum

Average

Interest Rate

for Funds

Borrowed from

Loaned to the

Borrowed from

Loaned to the

Years Ended

the Utility

Utility Money

the Utility

Utility Money

December 31,

Money Pool

Pool

Money Pool

Pool

2021

0.48%

0.02%

0.09%

0.03%

0.32%

0.05%

2020

2.24%

0.27%

2.70%

0.28%

1.22%

2.05%

Interest expense and interest income related to the direct financing relationship to the Utility Money Pool are included in Interest on Debt to Associated Companies and Interest and Dividend Income, respectively, on OHTCo’s statements of income. For amounts borrowed from and advanced to the Utility Money Pool, OHTCo incurred the following amounts of interest expense and earned the following amounts of interest income:


	Years Ended December 31,
	2021		2020
	(in thousands)
Interest Expense	$	247	$	541
Interest Income	—		173

9. RELATED PARTY TRANSACTIONS

For other related party transactions, also see “AEP System Tax Allocation Agreement” section of Note 7 in addition to “Corporate Borrowing Program” section of Note 8.

Affiliated Transmission Revenues

For the years ended December 31, 2021 and 2020, subsidiaries of AEP that are load serving entities within the PJM region incurred $560.2 million and $459.6 million, respectively, in PJM transmission services related to OHTCo that were billed to them in accordance with the OATT and Transmission Agreement. For the years ended December 31, 2021 and 2020, OHTCo derived other revenue of $12.8 million and $6.8 million, respectively. OHTCo recorded these affiliated revenues in Operating Revenues.

Services Provided by AEP Subsidiaries

AEPSC provides certain managerial and professional services to AEP’s subsidiaries. The costs of the services are based on a direct charge or on a prorated basis and billed to the AEP subsidiary companies at AEPSC's cost. AEPSC and its billings are subject to regulation by the FERC.

Other AEP subsidiaries perform certain transmission 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 included no compensation for the use of equity capital.

OHTCo’s net billings from AEP’s subsidiaries were as follows:


	Years Ended December 31,
Billing Company	2021		2020
	(in thousands)
AEP Energy	$	1	$	5
AEP OnSite Partners	—		3
AEP Texas	84		124
AEPEP	8		47
AEPSC	116,901		113,658
AEPTCo	(5)		(26)
AGR	—		7
APCo	90		54
Grid Assurance	206		107
I&M	125		396
IMTCo	—		6
KPCo	7		31
OKTCo	1		—
OPCo	2,407		2,236
PSO	64		109
SWEPCo	25		54
Transource Energy	6		4
WPCo	—		1
WVTCo	15		—

Purchases of Property

OHTCo purchased $7.7 million and $3.6 million of transmission property at book value from OPCo during the years ended December 31, 2021 and 2020, respectively, and purchased $498 thousand of transmission property at book value from AGR during the year ended December 31, 2021. There were no gains or losses recorded on these transactions.

Joint License Agreement

In January 2011, OHTCo and OPCo entered into a 50-year joint license agreement 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, ROE and income taxes. OHTCo recorded costs of $4.6 million and $4.5 million in Operation Expenses for the years ended December 31, 2021 and 2020, respectively.

10. TRANSMISSION PROPERTY

Depreciation

OHTCo provides for depreciation of transmission property on a straight-line basis over the estimated useful lives of property. OHTCo’s composite depreciation rates were as follows:


	2021		2020
Transmission Property	2.57	%	2.45	%

Asset Retirement Obligations

OHTCo has identified, but not recognized, ARO liabilities related to electric transmission 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 OHTCo plans to use its facilities indefinitely. The retirement obligation would only be recognized if and when OHTCo abandons or ceases the use of specific easements, which is not expected.

11. REVENUE FROM CONTRACTS WITH CUSTOMERS

Disaggregated Revenues from Contracts with Customers

OHTCo’s statements of income represent revenues from contracts with customers by type of revenue. OHTCo had $22.5 million and $(19.4) million of alternative revenues for the years ended December 31, 2021 and 2020, respectively.

Performance Obligations

OHTCo 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. OHTCo 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 OHTCo are summarized as follows:

Wholesale Revenues - Transmission

OHTCo has performance obligations to transmit electricity to wholesale customers through assets owned and operated by OHTCo and other AEP subsidiaries. The performance obligation of OHTCo to provide transmission services to PJM encompasses a time frame greater than a year. Payments from PJM for transmission services are typically received within one week from the issuance of the invoice, which is issued weekly.

OHTCo collects revenues through transmission formula rates charged to affiliates and nonaffiliates. The FERC-approved rates establish the 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.”

Fixed Performance Obligations

The following table represents OHTCo’s remaining fixed performance obligations satisfied over time as of December 31, 2021. Fixed performance obligations primarily include wholesale transmission services. The amounts below include affiliated and nonaffiliated revenues.


2022		2023-2024		2025-2026		After 2026		Total
(in thousands)
$	784,800	$	—	$	—	$	—	$	784,800

Contract Assets and Liabilities

Contract assets are recognized when OHTCo 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. OHTCo did not have any material contract assets as of December 31, 2021 and 2020.

When OHTCo 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. OHTCo 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 OHTCo’s balance sheets within the Customer Accounts Receivable line item. OHTCo’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.

The amount of affiliated accounts receivable from contracts with customers included in Accounts Receivable from Associated Companies on OHTCo’s balance sheets were $48.5 million and $39.9 million, respectively, as of December 31, 2021 and 2020.

Contract Costs

Contract costs to obtain or fulfill a contract for OHTCo are accounted for under the guidance for “Other Assets and Deferred Costs” and presented as a single asset and 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 statements of income. OHTCo did not have material contract costs as of December 31, 2021 and 2020.

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
2	Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3	Preceding Quarter/Year to Date Changes in Fair Value
4	Total (lines 2 and 3)								187,213,740	187,213,740
5	Balance of Account 219 at End of Preceding Quarter/Year
6	Balance of Account 219 at Beginning of Current Year
7	Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8	Current Quarter/Year to Date Changes in Fair Value
9	Total (lines 7 and 8)								253,386,944	253,386,944
10	Balance of Account 219 at End of Current Quarter/Year

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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)	3,558,417,695	3,558,417,695
4	UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases	914,189	914,189
5	UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold
6	UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified	1,334,560,462	1,334,560,462
7	UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified
8	UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7)	4,893,892,345	4,893,892,345
9	UtilityPlantLeasedToOthers Leased to Others
10	UtilityPlantHeldForFutureUse Held for Future Use
11	ConstructionWorkInProgress Construction Work in Progress	457,843,906	457,843,906
12	UtilityPlantAcquisitionAdjustment Acquisition Adjustments
13	UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12)	5,351,736,252	5,351,736,252
14	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion	492,333,214	492,333,214
15	UtilityPlantNet Net Utility Plant (13 less 14)	4,859,403,038	4,859,403,038
16	DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17	AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service:
18	DepreciationUtilityPlantInService Depreciation	474,939,842	474,939,842
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	17,393,372	17,393,372
22	DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21)	492,333,214	492,333,214
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
29	AmortizationUtilityPlantHeldForFutureUse Amortization
30	DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29)
31	AbandonmentOfLeases Abandonment of Leases (Natural Gas)
32	AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment
33	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32)	492,333,214	492,333,214

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
3	(302) Franchise and Consents
4	(303) Miscellaneous Intangible Plant	42,068,658	10,850,670	4,562,346			48,356,981
5	TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)	42,068,658	10,850,670	4,562,346			48,356,981
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	101,475,534	10,670,802	274,134			111,872,201
48.1	(351) Energy Storage Equipment - Transmission
49	(352) Structures and Improvements	125,565,167	16,772,743	23,610			142,314,300
50	(353) Station Equipment	1,691,647,337	164,415,043	1,932,780			1,854,129,600
51	(354) Towers and Fixtures	21,340,278	3,934,125				25,274,403
52	(355) Poles and Fixtures	1,450,273,354	274,074,686	98,512			1,724,249,528
53	(356) Overhead Conductors and Devices	638,447,617	105,757,757	228,559			743,976,815
54	(357) Underground Conduit	32,854,038	7,592,954	243			40,446,748
55	(358) Underground Conductors and Devices	23,799,184	1,114,096	6,153			24,907,127
56	(359) Roads and Trails
57	(359.1) Asset Retirement Costs for Transmission Plant
58	TOTAL Transmission Plant (Enter Total of lines 48 thru 57)	4,085,402,509	584,332,205	2,563,991			4,667,170,723
59	4. Distribution Plant
60	(360) Land and Land Rights
61	(361) Structures and Improvements
62	(362) Station Equipment
63	(363) Energy Storage Equipment – Distribution
64	(364) Poles, Towers, and Fixtures
65	(365) Overhead Conductors and Devices
66	(366) Underground Conduit
67	(367) Underground Conductors and Devices
68	(368) Line Transformers
69	(369) Services
70	(370) Meters
71	(371) Installations on Customer Premises
72	(372) Leased Property on Customer Premises
73	(373) Street Lighting and Signal Systems
74	(374) Asset Retirement Costs for Distribution Plant
75	TOTAL Distribution Plant (Enter Total of lines 60 thru 74)
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	13,335,789	4,865,793	188,867			18,012,714
87	(390) Structures and Improvements	122,624,785	21,594,026	16,004			144,202,808
88	(391) Office Furniture and Equipment	11,595,198	788,530				12,383,727
89	(392) Transportation Equipment
90	(393) Stores Equipment	912,869					912,869
91	(394) Tools, Shop and Garage Equipment
92	(395) Laboratory Equipment
93	(396) Power Operated Equipment
94	(397) Communication Equipment	1,174,938	579,308				1,754,246
95	(398) Miscellaneous Equipment	185,341	1,254				184,087
96	SUBTOTAL (Enter Total of lines 86 thru 95)	149,828,920	27,826,403	204,871			177,450,452
97	(399) Other Tangible Property
98	(399.1) Asset Retirement Costs for General Plant
99	TOTAL General Plant (Enter Total of lines 96, 97, and 98)	149,828,920	27,826,403	204,871			177,450,452
100	TOTAL (Accounts 101 and 106)	4,277,300,087	623,009,278	7,331,208			4,892,978,157
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)	4,277,300,087	623,009,278	7,331,208			4,892,978,157

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21	Other Property:
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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	Alpine - Trail Transco	2,911,541
2	Baseline Ohio Transco Work	8,178,615
3	Bluffton Supp Transco CI	4,065,200
4	Bluffton Transco CI	1,173,370
5	Corp Prgrm Billing - AEP OH Tr	3,029,042
6	Crooksville-N.Newark Transco	1,172,586
7	DeCliff_LaRue Transco CI	12,367,700
8	Lick Rebuild - Transco CI	2,253,203
9	MillbrookP-SPoint Transco CI	6,508,350
10	MP-FF Transco Baseline	1,379,940
11	OH TCo work	3,701,962
12	OH Transco	5,359,341
13	OH Transco	15,337,956
14	OH Transco Glencoe-Somerton	14,532,884
15	OH TRANSCo Pre Eng Parent	16,845,961
16	OH Transco Transmission Work	1,333,177
17	OH Transco Work	1,270,438
18	OH Transco Work	17,080,564
19	OH Transco Work	3,639,086
20	OH Transco Work	8,195,740
21	OH Transco Work	4,449,281
22	OH Transco Work	1,333,807
23	OH Transco Work	22,748,354
24	OH Transco Work	1,282,800
25	Ohio TansCo Work	4,807,967
26	Ohio Transco work	1,134,127
27	Ohio Transco work	11,106,542
28	Ohio Transco work	2,167,515
29	Ohio Transco work	6,049,338
30	Ohio Transco work	3,553,268
31	Ohio Transco work	7,879,798
32	Ohio Transco work	2,049,451
33	Ohio Transco work	5,324,844
34	Ohio Transco work	7,040,640
35	OHTC - BlnktProj Under $3M	20,789,924
36	OHTCo Baseline	5,417,021
37	OHTCo Supplemental	1,234,298
38	OHTCo Work	19,786,303
39	OHTCo-Baseline	2,944,120
40	OHTCo-Supplemental	5,798,031
41	OH-Transco Line Rebuild-OHTC	29,763,962
42	OH-Transco Work	9,408,483
43	Salerno 138kV Sta Install 380	1,121,858
44	SS-CI-OH-Transco GEN PLT	1,496,429
45	Supplemental Ohio TransCo Work	7,501,457
46	T/OH Trans/Transco Wrk	18,414,833
47	T/OH/Ohio Transco work	6,500,431
48	T/OH/Transco Work	1,814,912
49	T/OH/Transco Work	2,774,292
50	T/OHTC/NERC Physical Security	22,016,896
51	T/OHTR/TransCo Line Rebuild	30,033,467
52	Transco Work	17,647,512
53	Transco Work	5,321,192
54	Transco Work CI	15,548,010
55	Zanesville Area TTMP TC380 CI	1,133,410
56	Other Minor Projects Under $1,000,000	20,112,677
43	Total	457,843,906

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	354,234,212	354,234,212
2	Depreciation Provisions for Year, Charged to
3	DepreciationExpenseExcludingAdjustments (403) Depreciation Expense	123,085,011	123,085,011.10
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):
10	DepreciationProvision TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)	123,085,011	123,085,011
11	Net Charges for Plant Retired:
12	BookCostOfRetiredPlant Book Cost of Plant Retired	2,768,862	2,768,862
13	CostOfRemovalOfPlant Cost of Removal	1,409,831	(a) 1,409,831
14	SalvageValueOfRetiredPlant Salvage (Credit)	1,799,312	(b) 1,799,312
15	NetChargesForRetiredPlant TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)	2,379,382	2,379,382
16	OtherAdjustmentsToAccumulatedDepreciation Other Debit or Cr. Items (Describe, details in footnote):
17.1	Other Debit or Cr. Items (Describe, details in footnote):
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)	474,939,842	474,939,842
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	461,504,899	461,504,899
26	AccumulatedDepreciationDistribution Distribution
27	AccumulatedDepreciationRegionalTransmissionAndMarketOperation Regional Transmission and Market Operation
28	AccumulatedDepreciationGeneral General	13,434,943	13,434,942.80
29	AccumulatedProvisionForDepreciationOfElectricUtilityPlant TOTAL (Enter Total of lines 20 thru 28)	474,939,842	474,939,842

FOOTNOTE DATA

(a) Concept: CostOfRemovalOfPlant

Includes 1,312,149 of removal cost in retirement work in progress (RWIP).

(b) Concept: SalvageValueOfRetiredPlant

Includes ($ 1,067,935) of salvage in retirement work in progress (RWIP).

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
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	Total Cost of Account 123.1 $		Total

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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)	8,122,445	9,162,926	Electric
6	Assigned to - Operations and Maintenance
7	Production Plant (Estimated)
8	Transmission Plant (Estimated)	322,009	84,814	Electric
9	Distribution Plant (Estimated)
10	Regional Transmission and Market Operation Plant (Estimated)
11	Assigned to - Other (provide details in footnote)	712	(a) 7,805	Electric
12	TOTAL Account 154 (Enter Total of lines 5 thru 11)	8,445,166	9,255,545
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	8,445,166	9,255,545

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesOther

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

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20	Total
21	Generation Studies
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39	Total
40	Grand Total

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	SFAS 109 Deferred FIT	50,151,793	5,973,109	282/283	1,560,583	54,564,319
2	2020 PJM Transmission True-upAmortization Period 01/2022 - 12/2022	5,037,916	732,633	456	5,037,916	732,633
44	TOTAL	55,189,709	6,705,742		6,598,499	55,296,952

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	Billings and Deferred Projects	415,689	393,296	142, 418	338,697	470,288
2	Deferred Property Taxes	190,594,000	212,224,000	236, 408	190,594,000	212,224,000
3	S3 Filing FeesAmortized through April 2024	13,875	77,169	431	31,024	60,020
4	Unamortized Credit Line FeesAmortized through March 2026	161,274	497,186	431, 146	167,892	490,568
47	Miscellaneous Work in Progress
48	Deferred Regulatroy Comm. Expenses (See pages 350 - 351)
49	TOTAL	191,184,838				213,244,876

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	Provision for Revenue Refund	456,556	173,876
3	Net Operating Loss and Tax Credit Carryforwards	359,596
4	DSIT Entry Normalized	883,231	972,264
5	Accrued Companywide Incentive Compensation	538,202	749,564
7	Other		43,669
8	TOTAL Electric (Enter Total of lines 2 thru 7)	2,237,585	1,852,035
9	Gas
15	Other
16	TOTAL Gas (Enter Total of lines 10 thru 15)
17.1	(a) Other (Specify)	45,492,043	45,718,983
17	Other (Specify)
18	TOTAL (Acct 190) (Total of lines 8, 16 and 17)	47,729,628	47,571,018

Notes

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: DescriptionOfAccumulatedDeferredIncomeTax


Line 17 Other - Detail		Balance at Beginning of Year	Balance at End of Year

Non Utility Items-190.2		240,648	480,050
Sfas 109-Regulatory Assets - 190.3&190.4		45,251,395	45,238,933

Total		$45,492,043	$45,718,983

Line 18
Reconciliation of details applicable to Account 190, Line 18, Columns (b) and (c) :

Balance at Beginning of Year		$47,729,628

(Less) Amounts Debited to:
	(a) Account 410.1	(937,065)
	(b) Account 410.2	(235,565)
	(c) 1823/254/219/129/427	(173,611)

(Plus) Amounts Credited to:
	(a) Account 410.1	551,514
	(b) Account 410.2	474,966
	(c) 1823/254/219/129/427	161,151

Balance at End of Year		$47,571,018

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
3
4
5	Total
6	Preferred Stock (Account 204)
7
8
9
10	Total
1	Capital Stock (Accounts 201 and 204) - Data Conversion
2
3
4
5	Total

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

2022-05-19

Year/Period of Report

End of:

2021

/

Q4

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	1,075,500,000.00
3.1	IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders Increases (Decreases) from Donations Received from Stockholders	45,000,000.00
4	DonationsReceivedFromStockholders Ending Balance Amount	1,120,500,000.00
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
11.1	IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock
12	GainOnResaleOrCancellationOfReacquiredCapitalStock Ending Balance Amount
13	MiscellaneousPaidInCapitalAbstract Miscellaneous Paid-In Capital (Account 211)
14	MiscellaneousPaidInCapital Beginning Balance Amount
15.1	IncreasesDecreasesDueToMiscellaneousPaidInCapital Increases (Decreases) Due to Miscellaneous Paid-In Capital
16	MiscellaneousPaidInCapital Ending Balance Amount
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	1,120,500,000

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
3
4
5	Subtotal
6	Reacquired Bonds (Account 222)
7
8
9
10	Subtotal
11	Advances from Associated Companies (Account 223)
12						391,040
13	Senior Notes, Series A, Tranche A, 3.30%		83,200,000		442,146			10/18/2012	10/18/2022	10/18/2012	10/18/2022	83,200,000	2,745,600
14	Senior Notes, Series A, Tranche B, 4.00%		68,000,000		361,369			10/18/2012	10/18/2032	10/18/2012	10/18/2032	68,000,000	2,720,000
15	Senior Notes, Series A, Tranche C, 4.73%		48,800,000		259,336			10/18/2012	10/18/2042	10/18/2012	10/18/2042	48,800,000	2,308,240
16	Senior Notes, Series A, Tranche E, 4.83%		10,000,000		55,316			03/18/2013	03/18/2043	03/18/2013	03/18/2043	10,000,000	483,000
17	Senior Notes, Series B, Tranche B, 4.05%		37,800,000		202,475			11/07/2013	11/07/2023	11/07/2013	11/07/2023	37,800,000	1,530,900
18	Senior Notes, Series B, Tranche C, 4.38%		37,800,000		202,475			11/07/2013	11/07/2028	11/07/2013	11/07/2028	37,800,000	1,655,640
19	Senior Notes, Series B, Tranche D, 5.32%		63,000,000		337,459			11/07/2013	11/07/2043	11/07/2013	11/07/2043	63,000,000	3,351,600
20	Senior Notes, Series B, Tranche E, 5.42%		18,900,000		100,004			04/30/2014	04/30/2044	04/30/2014	04/30/2044	18,900,000	1,024,380
21	Senior Notes, Series B, Tranche F, 5.52%		43,000,000		241,779			10/30/2014	10/30/2044	10/30/2014	10/30/2044	43,000,000	2,373,600
22	Senior Notes, Series C, Tranche B, 3.18%		20,000,000		83,448			11/14/2014	11/14/2021	11/14/2014	11/14/2021		552,967
23	Senior Notes, Series C, Tranche C, 3.56%		37,900,000		158,133			11/14/2014	11/14/2024	11/14/2014	11/14/2024	37,900,000	1,349,240
24	Senior Notes, Series C, Tranche F, 3.81%		21,900,000		91,375			11/14/2014	11/14/2029	11/14/2014	11/14/2029	21,900,000	834,390
25	Senior Notes, Series C, Tranche H, 4.05%		8,400,000		35,048			11/14/2014	11/14/2034	11/14/2014	11/14/2034	8,400,000	340,200
26	Senior Notes, Series C, Tranche I, 4.53%		16,000,000		66,758			11/14/2014	11/14/2044	11/14/2014	11/14/2044	16,000,000	724,800
27	Senior Notes, Series C, Tranche D, 3.66%		15,000,000		61,129			03/16/2015	03/16/2025	03/16/2015	03/16/2025	15,000,000	549,000
28	Senior Notes, Series C, Tranche G, 4.01%		21,000,000		85,105			06/15/2015	06/15/2030	06/15/2015	06/15/2030	21,000,000	842,100
29	Senior Notes, Series C, Tranche E, 3.76%		14,000,000		56,736			06/15/2015	06/15/2025	06/15/2015	06/15/2025	14,000,000	526,400
30	Senior Notes, Series D, 3.10%		82,000,000		867,786			11/21/2016	12/01/2026	11/21/2016	12/01/2026	82,000,000	2,542,000
31							161,540
32	Senior Notes, Series E, 4.00%		147,000,000		1,555,521			11/21/2016	12/01/2046	11/21/2016	12/01/2046	147,000,000	5,880,000
33							2,426,970
34	Senior Notes, Series D, 3.10%		47,000,000		502,701			09/28/2017	12/01/2026	09/28/2017	12/01/2026	47,000,000	1,457,000
35	Senior Notes, Series H, 3.75%		188,000,000		2,010,804			09/28/2017	12/01/2047	09/28/2017	12/01/2047	188,000,000	7,050,000
36							453,080
37	Senior Notes, Series J, 4.25%		115,000,000		1,279,060			09/07/2018	09/15/2048	09/15/2018	09/15/2048	115,000,000	4,887,500
38							20,700
39	Senior Notes, Series K, 3.80%		127,000,000		1,411,375			06/12/2019	06/15/2049	06/15/2019	06/15/2049	127,000,000	4,826,000
40							744,220
41	Senior Notes, Series L, 3.15%		188,000,000		2,089,720			09/11/2019	09/15/2049	09/15/2019	09/15/2049	188,000,000	5,922,000
42							1,374,280
43	Senior Notes, Series M, 3.65%		182,000,000		1,976,262			04/01/2020	04/01/2050	04/01/2020	04/01/2050	182,000,000	6,643,000
44							65,520
45	Senior Notes, Series N, 2.75%		160,000,000		1,753,690			08/04/2021	08/15/2051	08/04/2021	08/15/2051	160,000,000	1,796,667
46							617,600
38	Subtotal		1,800,700,000		16,287,010	391,040	5,863,910					1,780,700,000	64,916,224
39	Other Long Term Debt (Account 224)
40
41
42
43	Subtotal
33	TOTAL		1,800,700,000									1,780,700,000	64,916,224

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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)	253,386,944
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	206,957,161
28	Show Computation of Tax:
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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			2,506,278	0	32,373,875	28,941,788		925,809	0	40,845,800			8,471,925
2	Subtotal Federal Tax				2,506,278	0	32,373,875	28,941,788		925,809	0	40,845,800			8,471,925
3		Local Tax	OH	2017	80,717	0				80,717	0
4		Local Tax	OH	2019	28,349	0				28,349	0
5		Local Tax	OH	2020	118,791	0	4,441	8,285		131,517	0				4,441
6		Local Tax	OH	2021	0	0	143,713	172,275		28,562	0				143,713
7	Subtotal Local Tax				171,159	0	139,272	180,560		212,447	0				139,272
8	Property Tax	Property Tax	OH	2019	162,334,646	0	3,849,415	158,485,231		0	0	3,849,415
9	Property Tax	Property Tax	OH	2020	190,594,000	0	3,000,000	383		187,593,617	0	187,594,000			190,594,000
10	Property Tax	Property Tax	OH	2021	0	0	212,224,000			212,224,000	0				212,224,000
11	Subtotal Property Tax				352,928,646	0	205,374,585	158,485,614		399,817,617	0	183,744,585			21,630,000
12	Sales and Use Tax	Sales And Use Tax	OH	2020	71,407	30,000	685,333	643,926		0	0				685,333
13	Sales and Use Tax	Sales And Use Tax	OH	2021	0	0	488,110	409,696		105,625	27,211				488,110
14	Subtotal Sales And Use Tax				71,407	30,000	197,223	234,230		105,625	27,211				197,223
15		Income Tax			0	0				0	0	143,713			143,713
16	Subtotal Income Tax				0	0				0	0	143,713			143,713
17	Other State Tax	Other State Tax	OH	2020	0	0	3,301	3,301		0	0	3,301
18	Other State Tax	Other State Tax	OH	2021	0	0	1,520	1,520		0	0	1,520
19	Subtotal Other State Tax				0	0	4,821	4,821		0	0	4,821
20	Other Taxes and Fees	Other Taxes and Fees	OH	2021	0	0	1,119,253	1,119,253		0	0				1,119,253
21	Subtotal Other Taxes And Fees				0	0	1,119,253	1,119,253		0	0				1,119,253
40	TOTAL				350,322,616	30,000	238,814,583	188,497,806		400,636,604	27,211	224,738,919			14,075,664

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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%
3	4%
4	7%
5	10%
8	TOTAL Electric (Enter Total of lines 2 thru 7)
9	Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10										`
47	OTHER TOTAL
48	GRAND TOTAL

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	Other Deferred Credits	675,649	186	196,044		479,605
2	NERC Penalty		242/426	44,812	827,980	783,168
47	TOTAL	675,649		240,856	827,980	1,262,773

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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)

1

Accelerated Amortization (Account 281)

2

Electric

3

Defense Facilities

4

Pollution Control Facilities

5

Other

5.1

Other (provide details in footnote):

8

TOTAL Electric (Enter Total of lines 3 thru 7)

9

Gas

10

Defense Facilities

11

Pollution Control Facilities

12

Other

12.1

Other (provide details in footnote):

15

TOTAL Gas (Enter Total of lines 10 thru 14)

16

Other

16.1

Other

16.2

Other

17

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

18

Classification of TOTAL

19

Federal Income Tax

20

State Income Tax

21

Local Income Tax

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	528,406,946	30,344,877	10,925,423							547,826,400
3	Gas
4	Other (Specify)
5	Total (Total of lines 2 thru 4)	528,406,946	30,344,877	10,925,423							547,826,400
6	(a) Other SFAS 109	132,400,663					1823/254	1,291,446	1823/254	5,206,015	128,486,094
9	TOTAL Account 282 (Total of Lines 5 thru 8)	396,006,283	30,344,877	10,925,423				1,291,446		5,206,015	419,340,306
10	Classification of TOTAL
11	Federal Income Tax	396,006,283	30,344,877	10,925,423				1,291,446		5,206,015	419,340,306
12	State Income Tax
13	Local Income Tax

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: DescriptionOfNonUtilityAccountDetails

Balance at Balance at

Beginning of year End of year

Non-Utility

SFAS 109 (132,400,663) (128,486,094)

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	Excess ADIT- Unprotected	3,006,927	382,198								2,624,729
4	NOL-Deferred Tax Asset	1,134,707	4,634	1,139,342							1
5	DSIT Entry-Normalized	4,205,860	429,938	5,968							4,629,830
9	TOTAL Electric (Total of lines 3 thru 8)	2,333,640	816,770	1,145,310							2,005,100
10	Gas
11
12
13
14
15
16
17	TOTAL Gas (Total of lines 11 thru 16)
18	TOTAL Other	13,782,186					1823/254	667,920	1823/254	1,212,354	14,326,620
19	TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)	16,115,826	816,770	1,145,310				667,920		1,212,354	16,331,720
20	Classification of TOTAL
21	Federal Income Tax	11,909,965	386,832	1,139,342				667,920		1,212,354	11,701,889
22	State Income Tax	4,205,861	429,938	5,968							4,629,831
23	Local Income Tax
NOTES

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	SFAS 109 Deferred FIT	214,021,663	190, 282, 283	144,785	85,848	213,962,726
41	TOTAL	214,021,663		144,785	85,848	213,962,726

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
3	CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales
4	CommercialSalesAbstract Small (or Comm.) (See Instr. 4)
5	IndustrialSalesAbstract Large (or Ind.) (See Instr. 4)
6	PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting
7	OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities
8	SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways
9	InterdepartmentalSalesAbstract (448) Interdepartmental Sales
10	SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers
11	SalesForResaleAbstract (447) Sales for Resale
12	SalesOfElectricityAbstract TOTAL Sales of Electricity
13	ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds		12,517,332
14	RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds		12,517,332
15	OtherOperatingRevenuesAbstract Other Operating Revenues
16	ForfeitedDiscounts (450) Forfeited Discounts
17	MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues
18	SalesOfWaterAndWaterPower (453) Sales of Water and Water Power
19	RentFromElectricProperty (454) Rent from Electric Property	13,338,858	7,124,695
20	InterdepartmentalRents (455) Interdepartmental Rents
21	OtherElectricRevenue (456) Other Electric Revenues	44,278
22	RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others	(a) 693,400,473	575,091,552
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	706,783,609	582,216,247
27	ElectricOperatingRevenues TOTAL Electric Operating Revenues	706,783,609	569,698,915
Line12, column (b) includes $ of unbilled revenues.
Line12, column (d) includes MWH relating to unbilled revenues

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: RevenuesFromTransmissionOfElectricityOfOthers

Reference Page 328 for Revenue Details

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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 - All Accounts
42	TOTAL Unbilled Rev. (See Instr. 6) - All Accounts
43	TOTAL - All Accounts

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
2
3
4
5
6
7
8
9
10
11
12
13
14
15	Subtotal - RQ
16	Subtotal-Non-RQ
17	Total

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	11
67	OtherPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 62 thru 67)	11
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)	11
75	OtherPowerSuplyExpensesAbstract E. Other Power Supply Expenses
76	PurchasedPower (555) Purchased Power
76.1	PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations	0
77	SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching
78	OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses
79	OtherPowerSupplyExpense TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)
80	PowerProductionExpenses TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)	11
81	TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES
82	TransmissionExpensesOperationAbstract Operation
83	OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering	14,603,614	13,031,487
85	LoadDispatchReliability (561.1) Load Dispatch-Reliability
86	LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System	635,977	679,042
87	LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling
88	SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services		11
89	ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development	743,370	568,383
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	1,388,195	404,796
93.1	OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment
94	OverheadLineExpense (563) Overhead Lines Expenses	118,392	159,074
95	UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses	1	1
96	TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others	1,686
97	MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses	4,657,543	4,334,721
98	RentsTransmissionElectricExpense (567) Rents	4,591,517	4,533,659
99	TransmissionOperationExpense TOTAL Operation (Enter Total of Lines 83 thru 98)	26,740,292	23,711,174
100	TransmissionMaintenanceAbstract Maintenance
101	MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering	16,906	52,168
102	MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures	101,402	25,319
103	MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware	47,677	38,425
104	MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software	661,426	843,530
105	MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment	216,290	113,108
106	MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant
107	MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment	2,845,918	1,538,429
107.1	MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment
108	MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines	1,593,233	638,920
109	MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines	39
110	MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant	156,008	206,550
111	TransmissionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 101 thru 110)	5,638,900	3,456,449
112	TransmissionExpenses TOTAL Transmission Expenses (Total of Lines 99 and 111)	32,379,192	27,167,623
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
122	RentsRegionalMarketExpenses (575.8) Rents
123	RegionalMarketOperationExpense Total Operation (Lines 115 thru 122)
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)
132	DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES
133	DistributionExpensesOperationAbstract Operation
134	OperationSupervisionAndEngineeringDistributionExpense (580) Operation Supervision and Engineering
135	LoadDispatching (581) Load Dispatching
136	StationExpensesDistribution (582) Station Expenses
137	OverheadLineExpenses (583) Overhead Line Expenses
138	UndergroundLineExpenses (584) Underground Line Expenses
138.1	OperationOfEnergyStorageEquipmentDistribution (584.1) Operation of Energy Storage Equipment
139	StreetLightingAndSignalSystemExpenses (585) Street Lighting and Signal System Expenses
140	MeterExpenses (586) Meter Expenses
141	CustomerInstallationsExpenses (587) Customer Installations Expenses
142	MiscellaneousDistributionExpenses (588) Miscellaneous Expenses
143	RentsDistributionExpense (589) Rents
144	DistributionOperationExpensesElectric TOTAL Operation (Enter Total of Lines 134 thru 143)
145	DistributionExpensesMaintenanceAbstract Maintenance
146	MaintenanceSupervisionAndEngineering (590) Maintenance Supervision and Engineering
147	MaintenanceOfStructuresDistributionExpense (591) Maintenance of Structures
148	MaintenanceOfStationEquipment (592) Maintenance of Station Equipment
148.1	MaintenanceOfEnergyStorageEquipment (592.2) Maintenance of Energy Storage Equipment
149	MaintenanceOfOverheadLines (593) Maintenance of Overhead Lines
150	MaintenanceOfUndergroundLines (594) Maintenance of Underground Lines
151	MaintenanceOfLineTransformers (595) Maintenance of Line Transformers
152	MaintenanceOfStreetLightingAndSignalSystems (596) Maintenance of Street Lighting and Signal Systems
153	MaintenanceOfMeters (597) Maintenance of Meters
154	MaintenanceOfMiscellaneousDistributionPlant (598) Maintenance of Miscellaneous Distribution Plant
155	DistributionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 146 thru 154)
156	DistributionExpenses TOTAL Distribution Expenses (Total of Lines 144 and 155)
157	CustomerAccountsExpensesAbstract 5. CUSTOMER ACCOUNTS EXPENSES
158	CustomerAccountsExpensesOperationsAbstract Operation
159	SupervisionCustomerAccountExpenses (901) Supervision
160	MeterReadingExpenses (902) Meter Reading Expenses
161	CustomerRecordsAndCollectionExpenses (903) Customer Records and Collection Expenses
162	UncollectibleAccounts (904) Uncollectible Accounts
163	MiscellaneousCustomerAccountsExpenses (905) Miscellaneous Customer Accounts Expenses
164	CustomerAccountExpenses TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)
165	CustomerServiceAndInformationalExpensesAbstract 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166	CustomerServiceAndInformationalExpensesOperationAbstract Operation
167	SupervisionCustomerServiceAndInformationExpenses (907) Supervision
168	CustomerAssistanceExpenses (908) Customer Assistance Expenses
169	InformationalAndInstructionalAdvertisingExpenses (909) Informational and Instructional Expenses
170	MiscellaneousCustomerServiceAndInformationalExpenses (910) Miscellaneous Customer Service and Informational Expenses
171	CustomerServiceAndInformationExpenses TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)
172	SalesExpenseAbstract 7. SALES EXPENSES
173	SalesExpenseOperationAbstract Operation
174	SupervisionSalesExpense (911) Supervision
175	DemonstratingAndSellingExpenses (912) Demonstrating and Selling Expenses
176	AdvertisingExpenses (913) Advertising Expenses
177	MiscellaneousSalesExpenses (916) Miscellaneous Sales Expenses
178	SalesExpenses TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)
179	AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
180	AdministrativeAndGeneralExpensesOperationAbstract Operation
181	AdministrativeAndGeneralSalaries (920) Administrative and General Salaries	8,914,635	8,427,556
182	OfficeSuppliesAndExpenses (921) Office Supplies and Expenses	688,460	434,578
183	AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit		2,541
184	OutsideServicesEmployed (923) Outside Services Employed	1,126,043	4,860,531
185	PropertyInsurance (924) Property Insurance	1,108,095	838,452
186	InjuriesAndDamages (925) Injuries and Damages	376,430	244,995
187	EmployeePensionsAndBenefits (926) Employee Pensions and Benefits	11,897	17,255
188	FranchiseRequirements (927) Franchise Requirements
189	RegulatoryCommissionExpenses (928) Regulatory Commission Expenses	1,333,313	107,531
190	DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr.
191	GeneralAdvertisingExpenses (930.1) General Advertising Expenses	364	457
192	MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses	238,883	224,530
193	RentsAdministrativeAndGeneralExpense (931) Rents	124,078	437,363
194	AdministrativeAndGeneralOperationExpense TOTAL Operation (Enter Total of Lines 181 thru 193)	13,922,198	15,595,789
195	AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance
196	MaintenanceOfGeneralPlant (935) Maintenance of General Plant	702,027	837,933
197	AdministrativeAndGeneralExpenses TOTAL Administrative & General Expenses (Total of Lines 194 and 196)	14,624,225	16,433,722
198	OperationsAndMaintenanceExpensesElectric TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)	47,003,428	43,601,345

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
2
3
4
5
6
7
8
9
10
11
12
13
14
15	TOTAL						0	0	0	0

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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)

1

PJM

FNO

PJMOATT

(a)

693,400,473

35

TOTAL

0

693,400,473

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Revenue earned from PJM per the revenue requirement for transmission services filed with FERC.

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
	TOTAL		0	0	0	0	0	0

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
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	Corporate Memberships	131,135
7	Trustee Fees	21,207
8	Travel Expenses	17,743
9	Miscellaneous Expenses	68,798
46	MiscellaneousGeneralExpenses TOTAL	238,883

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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			8,161,880		8,161,880
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	118,889,069				118,889,069
8	Distribution Plant
9	Regional Transmission and Market Operation
10	General Plant	4,195,943				4,195,943
11	Common Plant-Electric
12	TOTAL	123,085,011		8,161,880		131,246,891

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.

	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	350 (Rights)	71,465	0 years		1.03
14	352	138,663	60 years	20	1.95	R3
15	353	1,787,450	43 years	10	2.43	R2
16	353.16	9,750	43 years	10	2.43	R2
17	354	24,882	75 years	19	2.27	R4
18	355	1,694,034	37 years	20	3.53	L1.5
19	356	679,030	68 years	8	2.3	R4
20	356.16	53,460	68 years	8	2.3	R4
21	357	36,327	42 years		2.59	S6
22	358	18,690	24 years		3.09	L3.5
23	358.16	5,670	24 years		3.09	L3.5
24	TOTAL TRANSMISSION	4,519,421
25	GENERAL PLANT
26	390	141,936	45 years	8	2.65	R2.5
27	391	12,366	30 years		3.73	SQ
28	393	913	55 years		4.43	SQ
29	397	1,632	24 years	8	4.87	SQ
30	398	184	35 years		4.24	SQ
31	TOTAL GENERAL PLANT	157,031
32	DEPRECIABLE SUM	4,676,452

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	FERC 205 Filing		21,790	21,790		Electric	928	21,790
2	PJM Formula Rate Filing		44,142	44,142		Electric	928	44,142
3	PUCO - Long Term Forecast Fee		139,921	139,921		Electric	928	139,921
4	Minor Items <$25,000		8,207	8,207		Electric	928	8,207
5	State Commission Fees		1,119,253	1,119,253		Electric	928	1,119,253
46	TOTAL		1,333,313	1,333,313				1,333,313

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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 (2): Transmission	1 item under $50,000	3,212		566	3,212
2	A (6): Other	2 items under $50,000	49,627		566	49,627
3	A (6)g: Other	1 items under $50,000		1,684	566	1,684
4	B: Electric RD&D Performed External	4 items under $50,000		7,132	566	7,132
5	B(1): Research Support	9 items under $50,000		210,633	566	210,633
6	B(4): Research Support to Others	1 items under $50,000		7	566	7

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
4	SalariesAndWagesElectricOperationTransmission Transmission
5	SalariesAndWagesElectricOperationRegionalMarket Regional Market
6	SalariesAndWagesElectricOperationDistribution Distribution
7	SalariesAndWagesElectricOperationCustomerAccounts Customer Accounts
8	SalariesAndWagesElectricOperationCustomerServiceAndInformational Customer Service and Informational
9	SalariesAndWagesElectricOperationSales Sales
10	SalariesAndWagesElectricOperationAdministrativeAndGeneral Administrative and General
11	SalariesAndWagesElectricOperation TOTAL Operation (Enter Total of lines 3 thru 10)
12	SalariesAndWagesElectricMaintenanceAbstract Maintenance
13	SalariesAndWagesElectricMaintenanceProduction Production
14	SalariesAndWagesElectricMaintenanceTransmission Transmission
15	SalariesAndWagesElectricMaintenanceRegionalMarket Regional Market
16	SalariesAndWagesElectricMaintenanceDistribution Distribution
17	SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral Administrative and General
18	SalariesAndWagesElectricMaintenance TOTAL Maintenance (Total of lines 13 thru 17)
19	SalariesAndWagesElectricOperationAndMaintenanceAbstract Total Operation and Maintenance
20	SalariesAndWagesElectricProduction Production (Enter Total of lines 3 and 13)
21	SalariesAndWagesElectricTransmission Transmission (Enter Total of lines 4 and 14)
22	SalariesAndWagesElectricRegionalMarket Regional Market (Enter Total of Lines 5 and 15)
23	SalariesAndWagesElectricDistribution Distribution (Enter Total of lines 6 and 16)
24	SalariesAndWagesElectricCustomerAccounts Customer Accounts (Transcribe from line 7)
25	SalariesAndWagesElectricCustomerServiceAndInformational Customer Service and Informational (Transcribe from line 8)
26	SalariesAndWagesElectricSales Sales (Transcribe from line 9)
27	SalariesAndWagesElectricAdministrativeAndGeneral Administrative and General (Enter Total of lines 10 and 17)
28	SalariesAndWagesElectricOperationAndMaintenance TOTAL Oper. and Maint. (Total of lines 20 thru 27)
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)
66	SalariesAndWagesUtilityPlantAbstract Utility Plant
67	SalariesAndWagesUtilityPlantConstructionAbstract Construction (By Utility Departments)
68	SalariesAndWagesUtilityPlantConstructionElectricPlant Electric Plant
69	SalariesAndWagesUtilityPlantConstructionGasPlant Gas Plant
70	SalariesAndWagesUtilityPlantConstructionOther Other (provide details in footnote):
71	SalariesAndWagesUtilityPlantConstruction TOTAL Construction (Total of lines 68 thru 70)
72	SalariesAndWagesPlantRemovalAbstract Plant Removal (By Utility Departments)
73	SalariesAndWagesPlantRemovalElectricPlant Electric Plant
74	SalariesAndWagesPlantRemovalGasPlant Gas Plant
75	SalariesAndWagesPlantRemovalOther Other (provide details in footnote):
76	SalariesAndWagesPlantRemoval TOTAL Plant Removal (Total of lines 73 thru 75)
77	SalariesAndWagesOtherAccountsAbstract Other Accounts (Specify, provide details in footnote):
78	SalariesAndWagesOtherAccountsDescription Other Accounts (Specify, provide details in footnote):
79	SalariesAndWagesOtherAccountsDescription
80	SalariesAndWagesOtherAccountsDescription
81	SalariesAndWagesOtherAccountsDescription
82	SalariesAndWagesOtherAccountsDescription
83	SalariesAndWagesOtherAccountsDescription
84	SalariesAndWagesOtherAccountsDescription
85	SalariesAndWagesOtherAccountsDescription
86	SalariesAndWagesOtherAccountsDescription
87	SalariesAndWagesOtherAccountsDescription
88	SalariesAndWagesOtherAccountsDescription
89	SalariesAndWagesOtherAccountsDescription
90	SalariesAndWagesOtherAccountsDescription
91	SalariesAndWagesOtherAccountsDescription
92	SalariesAndWagesOtherAccountsDescription
93	SalariesAndWagesOtherAccountsDescription
94	SalariesAndWagesOtherAccountsDescription
95	SalariesAndWagesOtherAccounts TOTAL Other Accounts
96	SalariesAndWagesGeneralExpense TOTAL SALARIES AND WAGES

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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)
2.1	Net Purchases (Account 555.1)
3	Net Sales (Account 447)
4	Transmission Rights
5	Ancillary Services
6	Other Items (list separately)
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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

2022-05-19

Year/Period of Report

End of:

2021

/

Q4

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)
3	Steam		23	Requirements Sales for Resale (See instruction 4, page 311.)
4	Nuclear		24	Non-Requirements Sales for Resale (See instruction 4, page 311.)
5	Hydro-Conventional		25	Energy Furnished Without Charge
6	Hydro-Pumped Storage		26	Energy Used by the Company (Electric Dept Only, Excluding Station Use)
7	Other		27	Total Energy Losses
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	0
10	Purchases (other than for Energy Storage)	0
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)	0

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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
30	February
31	March
32	April
33	May
34	June
35	July
36	August
37	September
38	October
39	November
40	December
41	Total	0	0

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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)	0
6	PlantHoursConnectedToLoad Plant Hours Connect to Load While Generating	0
7	NetContinuousPlantCapability Net Plant Capability (in megawatts)	0
8	PlantAverageNumberOfEmployees Average Number of Employees
9	NetGenerationExcludingPlantUse Generation, Exclusive of Plant Use - kWh	0
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	0
15	CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant Reservoirs, Dams, and Waterways	0
16	CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant Water Wheels, Turbines, and Generators	0
17	CostOfAccessoryElectricEquipmentPumpedStoragePlant Accessory Electric Equipment	0
18	CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant Miscellaneous Powerplant Equipment	0
19	CostOfRoadsRailroadsAndBridgesPumpedStoragePlant Roads, Railroads, and Bridges	0
20	AssetRetirementCostsPumpedStoragePlant Asset Retirement Costs	0
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	0
25	WaterForPower Water for Power	0
26	PumpedStorageExpenses Pumped Storage Expenses	0
27	ElectricExpensesPumpedStoragePlant Electric Expenses	0
28	MiscellaneousPumpedStoragePowerGenerationExpenses Misc Pumped Storage Power generation Expenses	0
29	RentsPumpedStoragePlant Rents	0
30	MaintenanceSupervisionAndEngineeringPumpedStoragePlant Maintenance Supervision and Engineering	0
31	MaintenanceOfStructuresPumpedStoragePlant Maintenance of Structures	0
32	MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant Maintenance of Reservoirs, Dams, and Waterways	0
33	MaintenanceOfElectricPlantPumpedStoragePlant Maintenance of Electric Plant	0
34	MaintenanceOfMiscellaneousPumpedStoragePlant Maintenance of Misc Pumped Storage Plant	0
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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	0285 Guernsey EXT WEST		765.00	765.00	1	0.29	0	1	(4) 954 KCM ACSR
2	0286 Guernsey EXT EAST		765.00	765.00	1	0.33	0	1	(4) 954 KCM ACSR
3	0028 VASSELL EXT EAST		345.00	345.00	1	0.50	0	1	954 KCM ACSR
4	0029 VASSELL EXT WEST		345.00	345.00	1	0.90	0	1	954 KCM ACSR
5	0030 VASSELL LOOP EAST		345.00	345.00	1	0.38	0	1	(2) 954 KCM ACSR
6	0031 VASSELL LOOP WEST		345.00	345.00	1	0.41	0	1	(2) 954 KCM ACSR
7	0047 SPORN	MUSKINGUM	345.00	345.00	1	2.00	0	2	(2) 959 KCM ACS
8	0047 SPORN	MUSKINGUM	345.00	345.00	3	39.34	0	2	(2) 959 KCM ACS
9	0053 KIRK	JUG STREET	345.00	345.00	1	12.18	0	2	(2) 954 KCM ACSR
10	0053 KIRK	JUG STREET	345.00	345.00	1	0.51	0	1	(2) 954 KCM ACSR
11	0079 MUSKINGUM	TIDD	345.00	345.00	3	13.15	0	1	1851 KCM ACCR
12	0093 OHIO CENTRAL EXT		345.00	345.00	1	2.24	0	2	954 KCM ACSR
13	0122 HYATT EXTENSION		345.00	345.00	1	0.35	0	1	954 KCM ACSR
14	0129 JUG STREET	CORRIDOR	345.00	345.00	1	6.91	0	2	(2) 1590 KCM ACSR
15	0159 STEMPLE EXT		345.00	345.00	1	0.45	0	2	(2) 954 KCM ACSR
16	0220 HAYDEN	HYATT	345.00	345.00	3	9.41	0	1	(2) 954 KCM ACSR
17	0238 LAMPING EXT WEST		345.00	345.00	1	0.48	0	2	(2) 954 KCM ACSR
18	0239 LAMPING EXT EAST		345.00	345.00	1	0.19	0	2	(2) 954 KCM ACSR
19	0270 EAST LIMA	SORENSON	345.00	345.00	1	1.11	0	1	(2) 954 KCM ACSS
20	0270 EAST LIMA	SORENSON	345.00	345.00	3	29.13	0	1	(2) 954 KCM ACSS
21	0357 CONESVILLE	BIXBY	345.00	345.00	2	0.58	0	1	(2) 954 KCM ACSR
22	0359 Marysville	Peoria	345.00	345.00	1	0.17	0	1	(2) 954 KCM ACSR
23	0365 WATERFORD EXT		345.00	345.00	3	0.98	0	2	959 KCM ACSS
24	0006 TRENT	VASSELL	138.00	138.00	1	3.05	0	1	1590 KCM ACSR
25	0019 ELK EXT NORTH		138.00	138.00	1	7.03	0	1	1233 KCM ACSR
26	0020 PHILLIPI EXT		40.00	138.00	1	0.23	0	1	795 KCM ACSR
27	0024 COLE 138KV EXT		69.00	138.00	1	1.12	0	1	1590 KCM ACSR
28	0026 YELLOW CREEK EXT		138.00	138.00	1	0.41	0	1	1033 KCM ACSR
29	0037 ELK EXT SOUTH		138.00	138.00	1	10.13	0	1	1233 KCM ACSR
30	0038 HILLSBORO	HIGHLAND	138.00	138.00	2	4.25	0	1	1033 KCM ACSR
31	0038 HILLSBORO	HIGHLAND	138.00	138.00	1	3.25	0	2	1033 KCM ACSR
32	0039 GAHANNA	138KV LOOP	138.00	138.00	1	1.22	0	2	1590 KCM ACSR
33	0042 GLENCOE	SPEIDEL	69.00	138.00	1	12.52	0	1	1233 KCM ACSS
34	0043 BARNESVILLE	SUMMERFIELD	69.00	138.00	1	15.88	0	1	1233 KCM ACSS
35	0044 SPEIDEL	BARNESVILLE	69.00	138.00	1	3.82	0	1	1233 KCM ACSS
36	0057 BUCKLEY ROAD	FREMONT CENTER	69.00	138.00	1	15.81	0	1	795 KCM ACSR
37	0057 Buckley Road	Fremont Center	69.00	138.00	1	0.60	0	2	795 KCM ACSR
38	0060 LIMA	STERLING	138.00	138.00	1	5.87	0	1	795 KCM ACSR
39	0066 WAGENHALS	WEST CANTON	138.00	138.00	1	1.40	0	1	565 KCM ACSS
40	0066 WAGENHALS	WEST CANTON	138.00	138.00	3	7.60	0	1	565 KCM ACSS
41	0072 BIERS RUN	CIRCLEVILLE	138.00	138.00	1	19.20	0	1	1590 KCM ACSR
42	0086 HYATT TIE LINE SOUTH		138.00	138.00	1	0.68	0	1	(2) 954 KCM ACSR
43	0088 TIDD	SUNNYSIDE	138.00	138.00	1	30.56	0	1	1233 KCM ACSS
44	0089 STEAMTOWN	138KV LOOP	138.00	138.00	1	0.86	0	2	556 KCM ACSR
45	0090 MUSKINGUM RIVER	GLOBE METAL	138.00	138.00	1	0.30	0	1	397 KCM ACSR
46	0091 MUSKINGUM RIVER	TIE LINE - EAST	138.00	138.00	1	0.21	0	1	1926 KCM ACSS
47	0092 MUSKINGUM RIVER	MUSKINGUM RIVER TIE	138.00	138.00	1	0.21	0	1	1926 KCM ACSS
48	0095 OHIO CENTRAL LOOP		138.00	138.00	1	0.71	0	2	556 KCM ACSR
49	0099 POSTON	ROSEWOOD	138.00	138.00	1	2.71	0	1	1272 KCM ACSR
50	0099 POSTON	ROSEWOOD	138.00	138.00	1	0.41	0	1	1272 KCM ACSR
51	0100 NEW MARKET	SOUTH CENTRAL POWER	138.00	138.00	1	0.18	0	1	795 KCM ACSR
52	0103 BIERS RUN	DELANO	138.00	138.00	1	10.00	0	1	1590 KCM ACSR
53	0106 POLO ROAD TAP	INTERCO FIRST ENERGY	138.00	138.00	1	1.30	0	1	795 KCM ACSR
54	0108 MUSKINGUM RIVER	WOLF CREEK	138.00	138.00	1	4.35	0	1	1233 KCM ACSR
55	0111 EAST AMSTERDAM	MILLER SWITCH	69.00	138.00	1	9.58	0	1	1233 KCM ACSR
56	0112 AZALEA EXT EAST		138.00	138.00	1	0.94	0	1	959 KCM ACSS
57	0112 AZALEA EXT EAST		138.00	138.00	1	0.41	0	1	1033 KCM ACSR
58	0112 AZALEA EXT EAST		138.00	138.00	1	0.41	0	1	959 KCM ACSR
59	0113 TIMBER SWITCH	HAVILAND	138.00	138.00	1	0.47	0	1	1033 KCM ACSR
60	0113 TIMBER SWITCH	HAVILAND	138.00	138.00	1	11.00	0	2	1233 KCM ACSR
61	0114 HARRISON	CIRCLEVILLE	138.00	138.00	1	15.20	0	2	1233 KCM ACSR
62	0115 SCIOTO TRAIL	CIRCLEVILLE	138.00	138.00	1	2.54	0	1	1590 KCM ACSR
63	0116 SCIPPO EXTENSION		138.00	138.00	1	0.86	0	2	1590 KCM ACSR
64	0117 DELANO	SCIOTO TRAIL	138.00	138.00	1	3.04	0	1	1926 KCM ACSR
65	0117 DELANO	SCIOTO TRAIL	138.00	138.00	2	9.26	0	1	1926 KCM ACSR
66	0118 ROSS	DELANO	138.00	138.00	1	4.69	0	2	1033 KCM ACSR
67	0119 HOLLOWAY BUS TIE		138.00	138.00	1	0.27	0	1	1926 KCM ACSR
68	0121 BOLTON EXTENSION		138.00	138.00	1	0.15	0	2	1033 KCM ACSR
69	0123 PANDA EXTENSION		138.00	138.00	1	0.28	0	1	1033 KCM ACSR
70	0127 SPARROW LOOP		69.00	138.00	1	3.98	0	1	1233 KCM ACSR
71	0128 JUG STREET	SMITHS MILL	138.00	138.00	1	0.16	0	1	795 KCM ACSR
72	0132 NOTTINGHAM	FREEBRYD	138.00	138.00	1	0.44	0	1	1033 KCM ACSR
73	0132 NOTTINGHAM	FREEBRYD	138.00	138.00	3	4.43	0	1	1033 KCM ACSR
74	0133 Bell Ridge Sw	Rouse Sw	138.00	138.00	1	3.63	0	1	795 KCM ACSR
75	0133 Bell Ridge Sw	Rouse Sw	138.00	138.00	2	8.90	0	1	795 KCM ACSR
76	0135 SOUTH CALDWELL	SOUTH OLIVE SW	138.00	138.00	1	4.84	0	1	1033 KCM ACSR
77	0136 SOUTH OLIVE SW	MACKSBURG	138.00	138.00	1	3.27	0	1	1033 KCM ACSR
78	0137 CORNER	PARKERSBURG (APS)	138.00	138.00	2	6.40	0	1	1033 KCM ACSR
79	0138 BELPRE LOOP		138.00	138.00	1	0.47	0	1	1033 KCM ACSR
80	0139 SWITZER EXT SOUTH		138.00	138.00	1	0.04	0	1	556 KCM ACSR
81	0141 SWITZER EXT NORTH		138.00	138.00	1	0.06	0	1	556 KCM ACSR
82	0142 MELMORE	TIFFIN CENTER	138.00	138.00	1	7.10	0	2	477 KCM ACSR
83	0145 BRITTON	DAVIDSON	138.00	138.00	1	0.87	0	2	1033 KCM ACSR
84	0146 COLE	AMLIN	138.00	138.00	1	0.87	0	1	(2) 954 KCM ACSR
85	0146 COLE	AMLIN	138.00	138.00	3	0.00	12	1	(2) 954 KCM ACSR
86	0149 YAGER	AZALEA	138.00	138.00	2	4.25	0	1	1033 KCM ACSR
87	0150 YAGER	LEESVILLE	138.00	138.00	1	3.59	0	1	1033 KCM ACSR
88	0153 SPARROW	CORNERSTONE PIPELINE	69.00	138.00	1	0.08	0	1	1590 KCM ACSR
89	0153 SPARROW	CORNERSTONE PIPELINE	69.00	138.00	1	0.73	0	1	1033 KCM ACSR
90	0156 DENNISON	YAGER	69.00	138.00	1	2.21	0	1	1033 KCM ACSR
91	0156 DENNISON	YAGER	69.00	138.00	1	1.81	0	2	1033 KCM ACSR
92	0157 YAGER	DESERT ROAD	69.00	138.00	1	0.12	0	1	1033 KCM ACSR
93	0157 YAGER	DESERT ROAD	69.00	138.00	1	6.65	0	2	1033 KCM ACSR
94	0157 YAGER	DESERT ROAD	69.00	138.00	2	0.17	0	2	1033 KCM ACSR
95	0158 NORTH PROCTORVILLE	BUS TIE	138.00	138.00	1	0.09	0	1	(2) 1590 KCM ACSR
96	0160 LEVEE EXTENSION		138.00	138.00	1	0.18	0	1	1033 KCM ACSR
97	0161 Buell Extension		138.00	138.00	1	2.51	0	2	1033 KCM ACSR
98	0162 MACKSBURG	ARENDS RIDGE SW	138.00	138.00	1	8.13	0	1	1033 KCM ACSR
99	0162 MACKSBURG	ARENDS RIDGE SW	138.00	138.00	2	1.92	0	1	1033 KCM ACSR
100	0164 FREEBYRD	SOUTH CADIZ	138.00	138.00	2	2.30	0	1	1033 KCM ACSR
101	0164 FREEBYRD	SOUTH CADIZ	138.00	138.00	2	1.40	0	2	1033 KCM ACSR
102	0165 ARENDS RIDGE SW	DEVOLA	138.00	138.00	1	3.42	0	1	1033 KCM ACSR
103	0168 DEVOLA	MILL CREEK	138.00	138.00	1	0.41	0	1	1033 KCM ACSR
104	0174 REXFORD EXT		69.00	138.00	1	0.76	0	2	1033 KCM ACSR
105	0174 REXFORD EXT		69.00	138.00	1	0.05	0	1	1033 KCM ACSR
106	0175 POSTON	GOOD HOPE SW	138.00	138.00	1	3.20	0	1	1033 KCM ACSR
107	0175 POSTON	GOOD HOPE SW	138.00	138.00	2	21.90	0	1	1033 KCM ACSR
108	0176 GOOD HOPE SW	HARRISON	138.00	138.00	1	1.55	0	1	1033 KCM ACSR
109	0176 GOOD HOPE SW	HARRISON	138.00	138.00	2	28.45	0	1	1033 KCM ACSR
110	0179 FIREBRICK EXT - EAST		138.00	138.00	1	0.79	0	1	1590 KCM ACSR
111	0180 FIREBRICK EXT - WEST		138.00	138.00	1	0.75	0	1	1590 KCM ACSR
112	0182 SOUTH CANTON	WEST CANTON	138.00	138.00	3	2.58	0	2	795 KCM ACSR
113	0183 LAMPING	ROUSE (WEC)	138.00	138.00	1	5.04	0	1	795 KCM ACSR
114	0183 LAMPING	ROUSE (WEC)	138.00	138.00	2	0.33	0	1	795 KCM ACSR
115	0184 HANGING ROCK EXT		138.00	138.00	3	0.00	4	1	636 KCM ACSR
116	0186 GLENCOE	WEST BELLAIRE	138.00	138.00	1	5.59	0	2	1033 KCM ACSR
117	0186 GLENCOE	WEST BELLAIRE	138.00	138.00	4	0.15	0	2	4000 KCM Segmenta
118	0187 WEST BELLAIRE	BRUES	138.00	138.00	3	3.95	0	1	556 KCM ACSR
119	0188 GEORGE WASHINGTON	DILLES BOTTOM	138.00	138.00	1	0.05	0	2	1233 KCM ACSS
120	0188 GEORGE WASHINGTON	DILLES BOTTOM	138.00	138.00	3	0.15	0	2	1233 KCM ACSS
121	0189 DILLES BOTTOM	FE CORRIDOR	138.00	138.00	1	0.22	0	2	1233 KCM ACSS/TW
122	0189 DILLES BOTTOM	FE CORRIDOR	138.00	138.00	3	1.05	0	2	1233 KCM ACSS/TW
123	0192 WEST MOUNT VERNON	NORTH WALDO	138.00	138.00	1	2.43	0	1	1033 KCM ACSR
124	0192 WEST MOUNT VERNON	NORTH WALDO	138.00	138.00	2	29.73	0	2	1033 KCM ACSR
125	0193 NORTH WALDO	SOUTH KENTON	138.00	138.00	1	0.25	0	1	477 KCM ACSR
126	0193 NORTH WALDO	SOUTH KENTON	138.00	138.00	2	0.14	0	1	477 KCM ACSR
127	0197 HAVILAND	NORTH DELPHOS	138.00	138.00	1	31.60	0	2	1033 KCM ACSR
128	0202 HERLAN	BLUE RACER	138.00	138.00	1	0.49	0	1	1033 KCM ACSR
129	0202 HERLAN	BLUE RACER	138.00	138.00	2	2.76	0	1	1033 KCM ACSR
130	0203 SUMMERFIELD	BERNE	138.00	138.00	1	3.35	0	1	1033 KCM ACSR
131	0207 WEST BELLAIRE EXT		69.00	138.00	1	0.58	0	1	1033 KCM ACSR
132	0209 SOUTH KENTON	WESTMINSTER	138.00	138.00	2	3.73	0	1	636 KCM ACSR
133	0209 SOUTH KENTON	WESTMINSTER	138.00	138.00	2	3.35	0	1	477 KCM ACSR
134	0211 CLOUSE EXTENSION	EAST	138.00	138.00	1	0.19	0	1	1033 KCM ACSR
135	0212 CLOUSE EXTENSION	WEST	138.00	138.00	1	0.19	0	1	1033 KCM ACSR
136	0213 RAIDER EXT		69.00	138.00	1	0.05	0	2	1033 KCM ACSR
137	0214 MILES AVE EXT NORTH		138.00	138.00	1	0.05	0	1	795 KCM ACSR
138	0215 TRIMBLE EXTENSION		138.00	138.00	1	1.25	0	2	1033 KCM ACSR
139	0216 SOUTH OLIVE SW	SOUTH OLIVE (WEC) TAP	138.00	138.00	1	0.07	0	1	1033 KCM ACSR
140	0219 GABLE EXTENSION		138.00	138.00	1	0.94	0	1	1233 KCM ACSS
141	0222 Seaman	Adams	138.00	138.00	1	7.57	0	2	1033 KCM ACSR
142	0222 Seaman	Adams	138.00	138.00	2	0.39	0	2	1033 KCM ACSR
143	0222 Seaman	Adams	69.00	138.00	1	0.26	0	1	1033 KCM ACSR
144	0223 ADAMS	WAVERLY	138.00	138.00	2	24.80	0	1	1033 KCM ACSR
145	0236 LAMPING BUS TIE		138.00	138.00	1	0.17	0	1	(2) 795 KCM ACSR
146	0245 ROSS	HEPPNER	69.00	138.00	1	0.20	0	1	1033 KCM ACSR
147	0245 Ross	Heppner	69.00	138.00	2	7.11	0	1	1033 KCM ACSR
148	0246 HEPPNER	RHODES	69.00	138.00	1	0.19	0	2	1033 KCM ACSR
149	0246 HEPPNER	RHODES	69.00	138.00	1	0.63	0	1	1033 KCM ACSR
150	0246 HEPPNER	RHODES	69.00	138.00	2	3.78	0	1	1033 KCM ACSR
151	0247 HEPPNER	LICK	69.00	138.00	1	3.10	0	1	1033 KCM ACSR
152	0247 HEPPNER	LICK	69.00	138.00	1	0.76	0	2	1033 KCM ACSR
153	0247 HEPPNER	LICK	69.00	138.00	2	0.23	0	1	1033 KCM ACSR
154	0247 HEPPNER	LICK	69.00	138.00	2	0.11	0	2	1033 KCM ACSR
155	0254 BLUE RACER	TEXAS EASTERN BERNE	138.00	138.00	1	0.19	0	1	1033 KCM ACSR
156	0269 BABBITT LOOP		138.00	138.00	1	0.12	0	2	(2) 954 KCM ACSR
157	0271 SARDINIA EXTENSION		138.00	138.00	1	3.80	0	2	556 KCM ACSR
158	0275 June Road EXT North		138.00	138.00	1	0.12	0	1	1351 KCM ACSR
159	0276 June Road EXT South		138.00	138.00	1	0.12	0	1	1351 KCM ACSR
160	0277 Summerfield Bus Tie		138.00	138.00	1	0.06	0	1	1033 KCM ACSR
161	0278 HUTCHINGS TAP	MIDDLEBORO SW	138.00	138.00	1	0.04	0	2	1033 KCM ACSR
162	0278 HUTCHINGS TAP	MIDDLEBORO SW	138.00	138.00	2	15.00	0	1	1033 KCM ACSR
163	0279 MIDDLEBORO SW	CLINTON COUNTY (DUKE)	138.00	138.00	2	5.10	0	1	1033 KCM
164	0280 Clinton County (Duke)	Hillsboro	138.00	138.00	1	17.30	0	2	1033 KCM ACSR
165	0281 MINK EXTENSION		138.00	138.00	1	0.11	0	1	1272 KCM ACSR
166	0282 BRICE EXTENSION		138.00	138.00	1	0.58	0	2	795 KCM ACSR
167	0287 NEWBERY EXT		138.00	138.00	1	0.56	0	3	1033 KCM ACSR
168	0288 AULT SWITCH	GINGER	69.00	138.00	2	0.06	0	1	1033 KCM ACSR
169	0290 GEMINI	GRISTMILL	138.00	138.00	1	3.97	0	1	795 KCM ACSR
170	0290 GEMINI	GRISTMILL	138.00	138.00	2	0.18	0	1	795 KCM ACSR
171	0294 Isabella Extension, No		138.00	138.00	1	0.22	0	1	795 KCM ACSR
172	0295 Isabella Extension, So		138.00	138.00	1	0.19	0	1	795 KCM ACSR
173	0296 BETHEL	SAWMILL	138.00	138.00	1	2.20	0	1	1590 KCM ACSR
174	0296 BETHEL	SAWMILL	138.00	138.00	1	3.00	0	2	1590 KCM ACSR
175	0307 Reno Extension		138.00	138.00	1	0.02	0	1	954 KCM ACSR
176	0316 ANGUIN	BABBITT	138.00	138.00	1	1.69	0	2	1033 KCM ACSR
177	0321 Astor Extension		138.00	138.00	1	0.18	0	1	795 KCM ACSR
178	0330 Hyatt	Delaware	138.00	138.00	1	0.10	0	1	795 KCM ACSS
179	0330 Hyatt	Delaware	138.00	138.00	2	4.20	0	1	795 KCM ACSS
180	0343 Babbitt Bus Tie No. 1		138.00	138.00	1	0.13	0	1	(2) 1033 KCM ACSS
181	0344 Babbitt Bus Tie No. 2		138.00	138.00	1	0.23	0	1	(2) 1033 KCM ACSS
182	0347 Babbitt EXT No. 1		138.00	138.00	1	0.31	0	1	(2) 954 KCM ACSR
183	0377 Culbertson Extension		138.00	138.00	1	0.52	0	2	795 KCM ACSR
184	07-0095 PORTSMOUTH	TRENTON NO. 1	138.00	138.00	1	4.25	0	1	1033 KCM ACSR
185	07-0193 TIFFIN CENTER	FREMONT CENTER	138.00	138.00	1	12.60	0	2	959 KCM ACSR
186	0827 Philo	Howard	138.00	138.00	1	0.17	0	2	556 KCM ACSR
187	8008 GROVES ROAD	BEXLEY	138.00	138.00	1	4.35	0	1	1926 KCM ACSR
188	8011 WEST LANCASTER	BIXBY	138.00	138.00	1	19.10	0	1	1033 KCM ACSR
189	8012 POSTON	ROSS	138.00	138.00	1	43.06	0	1	1033 KCM ACSR
190	8019 BIXBY	GROVES ROAD-ASTOR	138.00	138.00	1	4.35	0	2	1926 KCM ACSR
191	8020 POSTON	HARRISON	138.00	138.00	1	0.02	0	1	636 KCM ACSR
192	8026 POSTON	LICK	138.00	138.00	1	3.93	0	1	1233 KCM ACSS
193	8026 POSTON	LICK	138.00	138.00	2	17.11	0	1	1233 KCM ACSS
194	8044 TRENT	DELAWARE	138.00	138.00	1	0.72	0	2	1272 KCM ACSR
195	8044 TRENT	DELAWARE	138.00	138.00	3	12.66	0	0	1272 KCM ACSR
196	8096 POSTON	WEST LANCASTER	138.00	138.00	1	19.46	0	1	1033 KCM ACSR
197	8096 POSTON	WEST LANCASTER	138.00	138.00	2	15.66	0	1	1033 KCM ACSR
198	C797 ROBERTS	OSU	138.00	138.00	1	0.12	0	1	1272 KCM ACSR
199	C797 ROBERTS	OSU	138.00	138.00	4	5.55	0	1	2500 MCM XLPE
200	Lines Under 138KV					628.08
201	COMMONLY OWNED: (A)
202	FULLY OWNED TRANS LINES:
203	Line Costs and expenses are	not available by individual								76,043,359	2,458,583,333	2,534,626,692	118,391	1,593,272		1,711,663
204	transmission line.	Total shown in column j-p
36	TOTAL					1,490.89	16.00	255		76,043,358.86	2,458,583,333.22	2,534,626,692.08	118,391.13	1,593,271.56	0.00	1,711,662.69

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

TRANSMISSION LINES ADDED DURING YEAR
Report below the information called for concerning Transmission lines added or altered during the year. It is not necessary to report minor revisions of lines. Provide separate subheadings for overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (l) to (o), it is permissible to report in these columns the costs. Designate, however, if estimated amounts are reported. Include costs of Clearing Land and Rights-of-Way, and Roads and Trails, in column (l) with appropriate footnote, and costs of Underground Conduit in column (m). If design voltage differs from operating voltage, indicate such fact by footnote; also where line is other than 60 cycle, 3 phase, indicate such other characteristic.
	LINE DESIGNATION			SUPPORTING STRUCTURE		CIRCUITS PER STRUCTURE		CONDUCTORS				LINE COST
Line No.	TransmissionLineStartPoint From	TransmissionLineEndPoint To	LengthOfTransmissionLineAdded Line Length in Miles	SupportingStructureOfTransmissionLineType Type	AverageNumberOfSupportingStructuresOfTransmissionLinePerMiles Average Number per Miles	NumberOfTransmissionCircuitsPerStructurePresent Present	NumberOfTransmissionCircuitsPerStructureUltimate Ultimate	ConductorSize Size	ConductorSpecification Specification	ConductorConfigurationAndSpacing Configuration and Spacing	OperatingVoltageOfTransmissionLine Voltage KV (Operating)	CostOfLandAndLandRightsTransmissionLinesAdded Land and Land Rights	CostOfPolesTowersAndFixturesTransmissionLinesAdded Poles, Towers and Fixtures	CostOfConductorsAndDevicesTransmissionLinesAdded Conductors and Devices	Asset Retire. Costs	CostOfTransmissionLinesAdded Total	SupportingStructureConstructionType Construction
	(a)	(b)	(c)	(d)	(e)	(f)	(g)	(h)	(i)	(j)	(k)	(l)	(m)	(n)	(o)	(p)	(q)
1	0347 Babbitt 138kV Extension No. 1		0.31	1	1.00	1	1	954	ACSR		138		876,411			876,411
2	0343 Babbitt Bus Tie No. 1		0.13	1	1.00	1	1	1033	ACSS		138		522,863			522,863
3	0344 Babbitt Bus Tie No. 2		0.23	1	1.00	1	1	1033	ACSS		138		1,054,846			1,054,846
4	0133 Bell Ridge Sw	Rouse Sw	3.63	1	1.00	1	1	795	ACSR		138
5	0133 Bell Ridge Sw	Rouse Sw	8.90	2	2.00	1	1	795	ACSR		138	3,053,580	23,474,404	258		26,528,242
6	0280 Clinton County (Duke)	Hillsboro	17.30	1	1.00	2	2	1033	ACSR		138		21,345,378	14,202,724		35,548,102
7	0377 Culbertson 138kV Extension		0.52	1	1.00	2	2	795	ACSR		138	46,829	1,119,641	258,130		1,424,600
8	0330 Hyatt	Delaware	4.20	2	2.00	1	1	795	ACSS		138
9	0330 Hyatt	Delaware	0.10	1	1.00	1	1	795	ACSS		138		4,173,737	1,260,368		5,434,105
10	0275 June Road 138kV Extension, North		0.12	1	1.00	1	1	1351	ACSR		138		185,863	82,191		268,054
11	0276 June Road 138kV Extension, South		0.12	1	1.00	1	1	1351	ACSR		138		183,743	80,315		264,058
12	0359 Marysville	Peoria	0.17	1	1.00	1	1	954	ACSR		345	17,234	635,130	296,720		949,084
13	0827 Philo	Howard	0.17	1	1.00	2	2	556	ACSR		138			154,245		154,245
14	0222 Seaman	Adams	7.57	1	1.00	2	2	1033	ACSR		138
15	0222 Seaman	Adams	0.26	1	1.00	1	1	1033	ACSR		138
16	0222 Seaman	Adams	0.39	2	2.00	2	2	1033	ACSR		138		11,591,938	3,269,787		14,861,725
44	TOTAL		44		19	21	21					3,117,643	65,163,954	19,604,738		87,886,335

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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	ADAMS (CSP) - OH	Transmission		138.00	69.00	13.00	60.00	4
2	ADAMS (CSP) - OH	Transmission		138.00	69.00	13.09	60.00	4
3	ADOBE SWITCH - OH	Transmission		69.00						STATCAP	1	28.80
4	ANGUIN - OH	Transmission		138.00						STATCAP	2
5	AZALEA SW STATION - OH	Transmission		138.00						STATCAP	1	28.80
6	BABBITT - OH	Transmission		345.00	138.00	34.50		1
7	BABBITT - OH	Transmission		138.00						STATCAP	1
8	BABBITT - OH	Transmission		138.00						AIR CORE REACTOR	3
9	BEATTY ROAD - OH	Transmission		345.00	138.00	34.50	675.00		1
10	BEATTY ROAD - OH	Transmission		345.00	138.00	13.80	450.00		1
11	BEATTY ROAD - OH	Transmission		345.00	138.00	34.50	405.00	1
12	BEATTY ROAD - OH	Transmission		138.00	70.50	13.80	54.00	1
13	BERRYWOOD - OH	Transmission		138.00	70.50	13.09	78.00	1
14	BIERS RUN - OH	Transmission		138.00	69.00	12.00		1
15	BIERS RUN - OH	Transmission		345.00	138.00	34.00	675.00	1
16	BIERS RUN - OH	Transmission					0.00			STATCAP	2
17	BIXBY - OH	Transmission		345.00	138.00		1350.00	6
18	BIXBY - OH	Transmission		345.00	138.00	34.50	2700.00	12
19	BIXBY - OH	Transmission		345.00			675.00	3
20	BIXBY - OH	Transmission		345.00		34.50	1350.00	6
21	BLUE RACER - OH	Transmission		138.00	0.00	0.00	0.00			STATCAP	1	28.80
22	BOUTWELL - OH	Transmission		138.00	70.50	36.20	54.00	1
23	CANTON CENTRAL - OH	Transmission		345.00	138.00	13.80	900.00	2
24	CARROLLTON - OH	Distribution		138.00	70.50	36.20	130.00	1
25	CIRCLEVILLE - OH	Transmission		138.00			0.00			STATCAP	1
26	CLOUSE - OH	Distribution		138.00	69.00	13.09	130.00	1
27	CLOUSE - OH	Distribution		69.00						STATCAP	3	86.40
28	COLE (CS) - OH	Transmission		345.00	138.00	34.50	405.00	1
29	COLE (CS) - OH	Transmission		138.00	13.80		50.00	1
30	COLE (CS) - OH	Transmission		138.00	70.50	36.20	54.00	1
31	CONTINENTAL - OH	Distribution		69.00						STATCAP	1	14.40
32	CORRIDOR - OH	Transmission		345.00	138.00	34.50	405.00	1
33	DESERT ROAD SW - OH	Transmission		69.00						STATCAP	1	14.40
34	DILLES BOTTOM - OH	Distribution		138.00						STATCAP	1
35	DON MARQUIS (OP-CS) (OVEC) - OH	Transmission		765.00	345.00	34.50	2250.00	3
36	EAST WILLARD - OH	Distribution		69.00						STATCAP	1
37	EBERSOLE - OH	Transmission		138.00	70.50	36.20	90.00	1
38	ELLIOTT - OH	Transmission		138.00	70.50	13.09	78.00	1
39	FIREBRICK - OH	Transmission		138.00	69.00	13.80	54.00	1
40	FOSTORIA CENTRAL - OH	Transmission		345.00	138.00	34.50	675.00		1
41	FOSTORIA CENTRAL - OH	Transmission		345.00	138.00	13.80	450.00	1
42	FREEBYRD - OH	Transmission		138.00						STATCAP	1	28.80
43	GAVIN 138KV - OH	Transmission		138.00	70.50	13.09	130.00	1
44	GAVIN 765KV - OH	Transmission		765.00						REACTOR	3	300.00
45	GLENCOE SW - OH	Transmission		138.00	69.00	13.09	130.00	1
46	GLENCOE SW - OH	Transmission		138.00						STATCAP	1
47	GRISTMILL - OH	Transmission		345.00	138.00	13.80		1
48	HANGING ROCK 765KV - OH	Transmission		765.00						REACTOR	1
49	HANGING ROCK 765KV - OH	Transmission		765.00						REACTOR	3	300.00
50	HARRISON - OH	Transmission		138.00	70.50	13.09	54.00	1
51	HARRISON - OH	Transmission		69.00						REACTIVE SPECIAL	3
52	HERLAN SWITCH - OH	Transmission		138.00						STATCAP	2	57.60
53	HIGHLAND (CS) - OH	Distribution		138.00	69.00	12.00	90.00	1
54	HOLLOWAY - OH	Transmission		345.00	138.00	34.50	405.00	1
55	HYATT - OH	Transmission		345.00	138.00	13.80		2
56	JUNE ROAD - OH	Transmission		138.00	69.00	13.09	360.00	4
57	KILLBUCK - OH	Distribution		34.50			0.00			STATCAP	1	4.80
58	KIRK - OH	Transmission		345.00	138.00	34.50		1
59	LAMPING - OH	Transmission		345.00	138.00	13.80	450.00	1
60	LEMASTER - OH	Transmission		138.00						STATCAP	2	57.60
61	MARYSVILLE - OH	Transmission		765.00	345.00	34.50	2250.00	3
62	MARYSVILLE - OH	Transmission		765.00						REACTOR	11	1,100.00
63	MILLER SW - TRANSCO - OH	Transmission		69.00						STATCAP	1	14.40
64	MUSKINGUM RIVER 345KV - OH	Transmission		345.00	138.00	34.50	675.00	2
65	NEW LIBERTY - OH	Transmission		138.00	70.50	36.20	432.00	8
66	NEWCOMERSTOWN - OH	Transmission		138.00	70.50	13.09	78.00	1
67	NORTH PORTSMOUTH - OH	Transmission		138.00	70.50	13.09	432.00	8
68	NORTH PROCTORVILLE - OH	Transmission		765.00	138.00	13.80	1000.00	4
69	NORTHEAST CANTON - OH	Transmission		138.00	70.50	13.09	54.00	1
70	NORTHEAST CANTON - OH	Transmission		69.00						STATCAP	1
71	NOTTINGHAM SWITCH - OH	Transmission		138.00						STATCAP	1	43.20
72	OHIO CENTRAL - OH	Transmission		345.00	138.00	13.80	450.00		1
73	OHIO CENTRAL - OH	Transmission		345.00	138.00	34.50	405.00		1
74	OHIO CENTRAL - OH	Transmission		345.00	138.00	34.50	675.00	1
75	OHIO CENTRAL - OH	Transmission		138.00	70.50	13.09	54.00	1
76	RHODES - OH	Transmission		138.00	69.00	13.09	720.00	8
77	ROSS - OH	Transmission		138.00	69.00	13.09	54.00	1
78	SAINT CLAIR AVENUE (CS) - OH	Distribution		138.00	11.50		300.00	2
79	SEAMAN - OH	Transmission		138.00						STATCAP	1	28.80
80	SOUTH BALTIMORE - OH	Transmission		138.00	70.50	13.09	90.00	1
81	SOUTH FULTONHAM - OH	Distribution								STATCAP	1	14.40
82	SOUTHEAST CANTON - OH	Transmission		345.00	138.00	34.50	675.00	1
83	SOUTHWEST LIMA - OH	Transmission		345.00	138.00	13.80	450.00	1
84	SPARROW SWITCH - OH	Transmission		69.00						STATCAP	1	14.40
85	STEAMTOWN - OH	Transmission		138.00						STATCAP	1	57.60
86	STERLING - OH	Transmission		138.00						STATCAP	1	28.80
87	STERLING - OH	Transmission		34.50						STATCAP	1	14.40
88	SUNNYSIDE - OH	Transmission		138.00	70.50	13.09	130.00	1
89	SWITZER - OH	Transmission		138.00	69.00	34.50	50.00	1
90	TIDD 345KV - OH	Transmission		138.00						AIR CORE REACTOR	3
91	TIDD 345KV - OH	Transmission		345.00	137.50	13.80	270.00	1
92	TRABUE - OH	Distribution		138.00						STATCAP	1
93	VASSELL - OH	Transmission		765.00	345.00	34.50	2250.00	3
94	VASSELL - OH	Transmission		138.00	35.40	13.80	30.00	1
95	VASSELL - OH	Transmission		345.00	138.00	34.50	675.00	1
96	WEST BELLAIRE - OH	Transmission		345.00	138.00	34.50	675.00	1
97	WEST CAMBRIDGE - OH	Transmission		138.00	70.50	13.09	54.00	1
98	WEST END FOSTORIA - OH	Transmission		138.00	70.50	13.09	90.00	1
99	WOLF CREEK (CSP) - OH	Transmission		138.00						STATCAP	1	28.80
100	YAGER - OH	Transmission		69.00						STATCAP	1	14.40
101	YAGER - OH	Transmission		138.00	69.00	36.20	120.00	1
102	TotalTransmissionSubstationMember											2,310
103	Total											2,310

Name of Respondent:

AEP Ohio Transmission Company, Inc.

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

05/19/2022

Year/Period of Report

End of:

2021

/

Q4

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 & General - Maintenance	OPCo	935	373,346
3	Administrative and General Expenses - Maintenance	AEPSC	935	500,020
4	Administrative and General Expenses - Operation	AEPSC	920, 921, 923, 925, 926, 928, 930.1, 930.2, 931	1,945,306
5	Corporate Planning & Budgeting	AEPSC	920, 923	349,569
6	Audit Services	AEPSC	920, 923	527,461
7	Research and Other Services	AEPSC	183, 186, 188	409,077
8	Bus Ops & Perf Assurance	AEPSC	920, 923	482,338
9	Civil & Political Activities and other Svcs	AEPSC	426.1, 426.3, 426.4, 426.5	374,529
10	Construction Services	AEPSC	107, 108	79,106,300
11	Construction Services	OPCO	107	1,585,030
12	Corporate Accounting	AEPSC	920,923	725,500
13	Corporate Communications	AEPSC	920, 923	533,865
14	Corporate Human Resources	AEPSC	920, 923	331,813
15	Fuel & Storeroom Services	AEPSC	152, 163	3,810,072
16	Information Technology	AEPSC	920, 923	1,811,028
17	Legal GC/Administration	AEPSC	920, 923	922,900
18	Physical & Cyber Security	AEPSC	920, 923	360,724
19	Real Estate & Workplace Svcs	AEPSC	920, 923	863,082
20	Regulatory Services	AEPSC	920, 923	459,576
21	Strategy & Transformation	AEPSC	920, 923	424,324
22	Tax Services	AEPSC	920, 923	418,323
23	Transmission Expenses - Maintenance	AEPSC	568, 569, 569.1, 569.2, 570, 571, 572, 573	3,675,318
24	Transmission Expenses - Operation	AEPSC	560, 561.2, 561.5, 562, 563, 564, 565, 566, 920, 923	21,124,023
25	Treasury & Risk	AEPSC	920, 923	611,402
26	Use of Jointly Owned Facility	OPCo	567	4,591,145
19
20	Non-power Goods or Services Provided for Affiliated
21	Building and Property Leases	AEPSC	454	12,611,886
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

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Purpose

Who Must Submit

What and Where to Submit

When to Submit

Where to Send Comments on Public Reporting Burden.

GENERAL INSTRUCTIONS

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