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FERC FINANCIAL REPORT
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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
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Exact Legal Name of Respondent (Company) |
Year/Period of Report End of: |
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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 |
| FERC FORM NO.
REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER |
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IDENTIFICATION |
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01 Exact Legal Name of Respondent
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02 Year/ Period of Report
End of: |
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03 Previous Name and Date of Change (If name changed during year)
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04 Address of Principal Office at End of Period (Street, City, State, Zip Code)
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05 Name of Contact Person
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06 Title of Contact Person
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07 Address of Contact Person (Street, City, State, Zip Code)
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08 Telephone of Contact Person, Including Area Code
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09 This Report is An Original / A Resubmission
(1)
☐ An Original ☑ A Resubmission |
10 Date of Report (Mo, Da, Yr)
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| 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. | ||||
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03 Signature
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04 Date Signed (Mo, Da, Yr)
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| 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. | ||||
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Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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LIST OF SCHEDULES (Electric Utility) |
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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". |
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| Line No. |
Title of Schedule (a) |
Reference Page No. (b) |
Remarks (c) |
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ScheduleIdentificationAbstract Identification |
1 | ||
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ScheduleListOfSchedulesAbstract List of Schedules |
2 | ||
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1 |
ScheduleGeneralInformationAbstract General Information |
101 | |
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2 |
ScheduleControlOverRespondentAbstract Control Over Respondent |
102 | |
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3 |
ScheduleCorporationsControlledByRespondentAbstract Corporations Controlled by Respondent |
103 | |
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4 |
ScheduleOfficersAbstract Officers |
104 | |
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5 |
ScheduleDirectorsAbstract Directors |
105 | |
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6 |
ScheduleInformationOnFormulaRatesAbstract Information on Formula Rates |
106 | |
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7 |
ScheduleImportantChangesDuringTheQuarterYearAbstract Important Changes During the Year |
108 | |
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8 |
ScheduleComparativeBalanceSheetAbstract Comparative Balance Sheet |
110 | |
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9 |
ScheduleStatementOfIncomeAbstract Statement of Income for the Year |
114 | |
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10 |
ScheduleRetainedEarningsAbstract Statement of Retained Earnings for the Year |
118 | |
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12 |
ScheduleStatementOfCashFlowsAbstract Statement of Cash Flows |
120 | |
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12 |
ScheduleNotesToFinancialStatementsAbstract Notes to Financial Statements |
122 | |
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13 |
ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract Statement of Accum Other Comp Income, Comp Income, and Hedging Activities |
122a | |
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14 |
ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep |
200 | |
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15 |
ScheduleNuclearFuelMaterialsAbstract Nuclear Fuel Materials |
202 | |
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16 |
ScheduleElectricPlantInServiceAbstract Electric Plant in Service |
204 | |
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17 |
ScheduleElectricPropertyLeasedToOthersAbstract Electric Plant Leased to Others |
213 | |
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18 |
ScheduleElectricPlantHeldForFutureUseAbstract Electric Plant Held for Future Use |
214 | |
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19 |
ScheduleConstructionWorkInProgressElectricAbstract Construction Work in Progress-Electric |
216 | |
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20 |
ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract Accumulated Provision for Depreciation of Electric Utility Plant |
219 | |
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21 |
ScheduleInvestmentsInSubsidiaryCompaniesAbstract Investment of Subsidiary Companies |
224 | |
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22 |
ScheduleMaterialsAndSuppliesAbstract Materials and Supplies |
227 | |
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23 |
ScheduleAllowanceInventoryAbstract Allowances |
228 | |
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24 |
ScheduleExtraordinaryPropertyLossesAbstract Extraordinary Property Losses |
230a | |
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25 |
ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract Unrecovered Plant and Regulatory Study Costs |
230b | |
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26 |
ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract Transmission Service and Generation Interconnection Study Costs |
231 | |
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27 |
ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets |
232 | |
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28 |
ScheduleMiscellaneousDeferredDebitsAbstract Miscellaneous Deferred Debits |
233 | |
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29 |
ScheduleAccumulatedDeferredIncomeTaxesAbstract Accumulated Deferred Income Taxes |
234 | |
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30 |
ScheduleCapitalStockAbstract Capital Stock |
250 | |
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31 |
ScheduleOtherPaidInCapitalAbstract Other Paid-in Capital |
253 | |
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32 |
ScheduleCapitalStockExpenseAbstract Capital Stock Expense |
254b | |
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33 |
ScheduleLongTermDebtAbstract Long-Term Debt |
256 | |
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34 |
ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax |
261 | |
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35 |
ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract Taxes Accrued, Prepaid and Charged During the Year |
262 | |
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36 |
ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract Accumulated Deferred Investment Tax Credits |
266 | |
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37 |
ScheduleOtherDeferredCreditsAbstract Other Deferred Credits |
269 | |
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38 |
ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract Accumulated Deferred Income Taxes-Accelerated Amortization Property |
272 | |
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39 |
ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract Accumulated Deferred Income Taxes-Other Property |
274 | |
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40 |
ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract Accumulated Deferred Income Taxes-Other |
276 | |
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41 |
ScheduleOtherRegulatoryLiabilitiesAbstract Other Regulatory Liabilities |
278 | |
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42 |
ScheduleElectricOperatingRevenuesAbstract Electric Operating Revenues |
300 | |
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43 |
ScheduleRegionalTransmissionServiceRevenuesAbstract Regional Transmission Service Revenues (Account 457.1) |
302 | |
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44 |
ScheduleSalesOfElectricityByRateSchedulesAbstract Sales of Electricity by Rate Schedules |
304 | |
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45 |
ScheduleSalesForResaleAbstract Sales for Resale |
310 | |
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46 |
ScheduleElectricOperationsAndMaintenanceExpensesAbstract Electric Operation and Maintenance Expenses |
320 | |
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47 |
SchedulePurchasedPowerAbstract Purchased Power |
326 | |
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48 |
ScheduleTransmissionOfElectricityForOthersAbstract Transmission of Electricity for Others |
328 | |
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49 |
ScheduleTransmissionOfElectricityByIsoOrRtoAbstract Transmission of Electricity by ISO/RTOs |
331 | |
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50 |
ScheduleTransmissionOfElectricityByOthersAbstract Transmission of Electricity by Others |
332 | |
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51 |
ScheduleMiscellaneousGeneralExpensesAbstract Miscellaneous General Expenses-Electric |
335 | |
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52 |
ScheduleDepreciationDepletionAndAmortizationAbstract Depreciation and Amortization of Electric Plant (Account 403, 404, 405) |
336 | |
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53 |
ScheduleRegulatoryCommissionExpensesAbstract Regulatory Commission Expenses |
350 | |
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54 |
ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract Research, Development and Demonstration Activities |
352 | |
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55 |
ScheduleDistributionOfSalariesAndWagesAbstract Distribution of Salaries and Wages |
354 | |
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56 |
ScheduleCommonUtilityPlantAndExpensesAbstract Common Utility Plant and Expenses |
356 | |
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57 |
ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract Amounts included in ISO/RTO Settlement Statements |
397 | |
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58 |
SchedulePurchasesSalesOfAncillaryServicesAbstract Purchase and Sale of Ancillary Services |
398 | |
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59 |
ScheduleMonthlyTransmissionSystemPeakLoadAbstract Monthly Transmission System Peak Load |
400 | |
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60 |
ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract Monthly ISO/RTO Transmission System Peak Load |
400a | |
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61 |
ScheduleElectricEnergyAccountAbstract Electric Energy Account |
401a | |
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62 |
ScheduleMonthlyPeakAndOutputAbstract Monthly Peaks and Output |
401b | |
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63 |
ScheduleSteamElectricGeneratingPlantStatisticsAbstract Steam Electric Generating Plant Statistics |
402 | |
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64 |
ScheduleHydroelectricGeneratingPlantStatisticsAbstract Hydroelectric Generating Plant Statistics |
406 | |
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65 |
SchedulePumpedStorageGeneratingPlantStatisticsAbstract Pumped Storage Generating Plant Statistics |
408 | |
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66 |
ScheduleGeneratingPlantStatisticsAbstract Generating Plant Statistics Pages |
410 | |
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ScheduleEnergyStorageOperationsLargePlantsAbstract Energy Storage Operations (Large Plants) |
414 | |
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67 |
ScheduleTransmissionLineStatisticsAbstract Transmission Line Statistics Pages |
422 | |
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68 |
ScheduleTransmissionLinesAddedAbstract Transmission Lines Added During Year |
424 | |
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69 |
ScheduleSubstationsAbstract Substations |
426 | |
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70 |
ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract Transactions with Associated (Affiliated) Companies |
429 | |
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71 |
FootnoteDataAbstract Footnote Data |
450 | |
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StockholdersReportsAbstract Stockholders' Reports (check appropriate box) |
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Stockholders' Reports Check appropriate box:
☐ Two copies will be submitted ☐ No annual report to stockholders is prepared |
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Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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GENERAL INFORMATION |
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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.
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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.
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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.
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4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated.
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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 |
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Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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CONTROL OVER RESPONDENT |
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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. |
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American Electric Power Company, Inc., a registered holding company, owns 100% of the Respondent's outstanding shares of Common Stock. |
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Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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CORPORATIONS CONTROLLED BY RESPONDENT |
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NameOfCompanyControlledByRespondent Name of Company Controlled (a) |
CompanyControlledByRespondentKindOfBusinessDescription Kind of Business (b) |
VotingStockOwnedByRespondentPercentage Percent Voting Stock Owned (c) |
FootnoteReferences Footnote Ref. (d) |
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Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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OFFICERS |
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| 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) |
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Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| 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.
(1) 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.
(2) 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.
(3) The amounts shown in this column reflect annual incentive compensation paid for the year shown.
(4) 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 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.
(5) 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:
(6) 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.
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Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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DIRECTORS |
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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) |
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Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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INFORMATION ON FORMULA RATES |
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Does the respondent have formula rates? |
☐ Yes ☑ No |
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RateScheduleTariffNumber FERC Rate Schedule or Tariff Number (a) |
ProceedingDocketNumber FERC Proceeding (b) |
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Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding |
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Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)? |
☐ Yes ☑ No (Checked by default - Not explicitly defined) |
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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) |
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Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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INFORMATION ON FORMULA RATES - Formula Rate Variances |
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PageNumberOfFormulaRateVariances Page No(s). (a) |
ScheduleOfFormulaRateVariances Schedule (b) |
ColumnOfFormulaRateVariances Column (c) |
LineNumberOfFormulaRateVariances Line No. (d) |
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Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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IMPORTANT CHANGES DURING THE QUARTER/YEAR |
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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.
|
||||
|
No Franchise Renewals for 2021 |
||||
|
None |
||||
|
None |
||||
|
None |
||||
|
None |
||||
|
SWEPCo issued a Senior Unsecured Notes of $500,000,000 on March 10, 2021, maturing on March 15, 2026. FERC Authority Docket No. ES20-31-000 SWEPCo issued a Green Senior Unsecured Notes of $650,000,000 on Nov 03, 2021, maturing on November 1, 2051. FERC Authority Docket No. ES21-41-000 |
||||
|
None |
||||
|
Wage agreements, effective September 1, 2021, resulted in general increase of 2.5% settlement for certain represented employees. |
||||
|
Please refer to the Notes to Financial Statements Pages 122-123 |
||||
|
None |
||||
|
Not Used |
||||
|
Sloat, elected as Chief Financial Officer and Director 01/01/2021 Julie A Sherwood, elected as Treasurer 01/01/2021 Daniel E Mueller, elected as Assistant Vice President - Tax 03/24/2021 A Malcolm Smoak, elected as Director 05-02-2021 Scott P Moore, elected as Vice President 05-19-2021 Wade A Smith, resigned on 05-01-2021 Therace M Risch, elected as Vice President and Director 07/03/2021 Brian X Tierney, resigned as Vice President and Director 07/01/2021 Charles E Zebula, elected as Vice President 07/03/2021 Mark C McCullough, resigned as Vice President and Director 07/30/2021 Toby L Thomas, elected as Vice President and Director 07/31/2021 |
||||
|
Proprietary capital ratio exceeds 30% |
||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
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 |
|
|
|
3 |
ConstructionWorkInProgress Construction Work in Progress (107) |
200 |
|
|
|
4 |
UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3) |
|
|
|
|
5 |
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115) |
200 |
|
|
|
6 |
UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5) |
|
|
|
|
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) |
|
|
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|
15 |
OtherElectricPlantAdjustments Utility Plant Adjustments (116) |
|
|
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|
16 |
GasStoredUndergroundNoncurrent Gas Stored Underground - Noncurrent (117) |
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|
17 |
OtherPropertyAndInvestmentsAbstract OTHER PROPERTY AND INVESTMENTS |
|||
|
18 |
NonutilityProperty Nonutility Property (121) |
|
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|
19 |
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122) |
|
|
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|
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) |
|
|
|
|
25 |
SinkingFunds Sinking Funds (125) |
|||
|
26 |
DepreciationFund Depreciation Fund (126) |
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|
27 |
AmortizationFundFederal Amortization Fund - Federal (127) |
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|
28 |
OtherSpecialFunds Other Special Funds (128) |
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|
29 |
SpecialFunds Special Funds (Non Major Only) (129) |
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|
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) |
|
|
|
|
33 |
CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS |
|||
|
34 |
CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130) |
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|
35 |
Cash Cash (131) |
|
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|
|
36 |
SpecialDeposits Special Deposits (132-134) |
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|
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|
37 |
WorkingFunds Working Fund (135) |
|||
|
38 |
TemporaryCashInvestments Temporary Cash Investments (136) |
|||
|
39 |
NotesReceivable Notes Receivable (141) |
|||
|
40 |
CustomerAccountsReceivable Customer Accounts Receivable (142) |
|
|
|
|
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) |
|
|
|
|
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 |
|
|
|
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) |
(a) |
|
|
|
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) |
|
|
|
|
68 |
DeferredDebitsAbstract DEFERRED DEBITS |
|||
|
69 |
UnamortizedDebtExpense Unamortized Debt Expenses (181) |
|
|
|
|
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 |
|
|
|
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 |
|
|
|
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 |
|
(b) |
|
83 |
UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191) |
|||
|
84 |
DeferredDebits Total Deferred Debits (lines 69 through 83) |
|
|
|
|
85 |
AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84) |
|
|
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: Prepayments | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Formula Rate uses 13 month average.
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: AccumulatedDeferredIncomeTaxes | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Formula Rate uses 13 month average.
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
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 |
|
|
|
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 |
|
|
|
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) |
(a) |
|
|
|
17 |
LongTermDebtAbstract LONG-TERM DEBT |
|||
|
18 |
Bonds Bonds (221) |
256 |
||
|
19 |
ReacquiredBonds (Less) Reaquired Bonds (222) |
256 |
||
|
20 |
AdvancesFromAssociatedCompanies Advances from Associated Companies (223) |
256 |
||
|
21 |
OtherLongTermDebt Other Long-Term Debt (224) |
256 |
|
|
|
22 |
UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225) |
|||
|
23 |
UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226) |
|
|
|
|
24 |
LongTermDebt Total Long-Term Debt (lines 18 through 23) |
(b) |
|
|
|
25 |
OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES |
|||
|
26 |
ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227) |
|
|
|
|
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) |
|
|
|
|
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) |
|
|
|
|
36 |
CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES |
|||
|
37 |
NotesPayable Notes Payable (231) |
|||
|
38 |
AccountsPayable Accounts Payable (232) |
|
|
|
|
39 |
NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233) |
|
||
|
40 |
AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234) |
|
|
|
|
41 |
CustomerDeposits Customer Deposits (235) |
|
|
|
|
42 |
TaxesAccrued Taxes Accrued (236) |
262 |
|
|
|
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) |
|
|
|
|
49 |
ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243) |
|
|
|
|
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) |
|
|
|
|
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 |
|
|
|
60 |
OtherRegulatoryLiabilities Other Regulatory Liabilities (254) |
278 |
|
|
|
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) |
|
|
|
|
64 |
AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283) |
|
(c) |
|
|
65 |
DeferredCredits Total Deferred Credits (lines 56 through 64) |
|
|
|
|
66 |
LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65) |
|
|
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: ProprietaryCapital |
Formula Rate uses 13 month average.
|
| (b) Concept: LongTermDebt |
| (c) Concept: AccumulatedDeferredIncomeTaxesOther |
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
STATEMENT OF INCOME |
|||||||||||||
|
Quarterly
Annual or Quarterly if applicable
|
|||||||||||||
| Line No. |
Title of Account (a) |
(Ref.) Page No. (b) |
Total Current Year to Date Balance for Quarter/Year (c) |
Total Prior Year to Date Balance for Quarter/Year (d) |
Current 3 Months Ended - Quarterly Only - No 4th Quarter (e) |
Prior 3 Months Ended - Quarterly Only - No 4th Quarter (f) |
Electric Utility Current Year to Date (in dollars) (g) |
Electric Utility Previous Year to Date (in dollars) (h) |
Gas Utiity Current Year to Date (in dollars) (i) |
Gas Utility Previous Year to Date (in dollars) (j) |
Other Utility Current Year to Date (in dollars) (k) |
Other Utility Previous Year to Date (in dollars) (l) |
|
|
1 |
UtilityOperatingIncomeAbstract UTILITY OPERATING INCOME |
||||||||||||
|
2 |
OperatingRevenues Operating Revenues (400) |
300 |
|
|
|
|
|||||||
|
3 |
OperatingExpensesAbstract Operating Expenses |
||||||||||||
|
4 |
OperationExpense Operation Expenses (401) |
320 |
|
|
|
|
|||||||
|
5 |
MaintenanceExpense Maintenance Expenses (402) |
320 |
|
|
|
|
|||||||
|
6 |
DepreciationExpense Depreciation Expense (403) |
336 |
|
|
|
|
|||||||
|
7 |
DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1) |
336 |
|
|
|
|
|||||||
|
8 |
AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405) |
336 |
|
|
|
|
|||||||
|
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 |
|
|
|
|
|||||||
|
15 |
IncomeTaxesOperatingIncome Income Taxes - Federal (409.1) |
262 |
|
|
|
|
|||||||
|
16 |
IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1) |
262 |
|
|
|
|
|||||||
|
17 |
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1) |
234, 272 |
|
|
|
|
|||||||
|
18 |
ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1) |
234, 272 |
|
|
|
|
|||||||
|
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) |
|
|
|
|
||||||||
|
27 |
NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25) |
|
|
|
|
||||||||
|
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) |
|
|
||||||||||
|
36 |
EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1) |
119 |
|
|
|||||||||
|
37 |
InterestAndDividendIncome Interest and Dividend Income (419) |
|
|
||||||||||
|
38 |
AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1) |
|
|
||||||||||
|
39 |
MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421) |
|
|
||||||||||
|
40 |
GainOnDispositionOfProperty Gain on Disposition of Property (421.1) |
|
|||||||||||
|
41 |
OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40) |
|
|
||||||||||
|
42 |
OtherIncomeDeductionsAbstract Other Income Deductions |
||||||||||||
|
43 |
LossOnDispositionOfProperty Loss on Disposition of Property (421.2) |
|
|||||||||||
|
44 |
MiscellaneousAmortization Miscellaneous Amortization (425) |
||||||||||||
|
45 |
Donations Donations (426.1) |
|
|
||||||||||
|
46 |
LifeInsurance Life Insurance (426.2) |
||||||||||||
|
47 |
Penalties Penalties (426.3) |
|
|
||||||||||
|
48 |
ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4) |
|
|
||||||||||
|
49 |
OtherDeductions Other Deductions (426.5) |
|
|
||||||||||
|
50 |
OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49) |
|
|
||||||||||
|
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 |
|
|
|||||||||
|
54 |
IncomeTaxesOther Income Taxes-Other (409.2) |
262 |
|
|
|||||||||
|
55 |
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2) |
234, 272 |
|
|
|||||||||
|
56 |
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions (Less) Provision for Deferred Income Taxes-Cr. (411.2) |
234, 272 |
|
|
|||||||||
|
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) |
|
|
||||||||||
|
60 |
NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59) |
|
|
||||||||||
|
61 |
InterestChargesAbstract Interest Charges |
||||||||||||
|
62 |
InterestOnLongTermDebt Interest on Long-Term Debt (427) |
|
|
||||||||||
|
63 |
AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428) |
|
|
||||||||||
|
64 |
AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1) |
|
|
||||||||||
|
65 |
AmortizationOfPremiumOnDebtCredit (Less) Amort. of Premium on Debt-Credit (429) |
||||||||||||
|
66 |
AmortizationOfGainOnReacquiredDebtCredit (Less) Amortization of Gain on Reaquired Debt-Credit (429.1) |
|
|||||||||||
|
67 |
InterestOnDebtToAssociatedCompanies Interest on Debt to Assoc. Companies (430) |
|
|
||||||||||
|
68 |
OtherInterestExpense Other Interest Expense (431) |
|
|
||||||||||
|
69 |
AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432) |
|
|
||||||||||
|
70 |
NetInterestCharges Net Interest Charges (Total of lines 62 thru 69) |
|
|
||||||||||
|
71 |
IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70) |
|
|
||||||||||
|
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) |
|
|
||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
STATEMENT OF RETAINED EARNINGS |
||||
|
||||
| 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 |
|
|
|
|
2 |
ChangesAbstract Changes |
|||
|
3 |
AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439) |
|||
|
4 |
AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit |
|||
|
9 |
AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439) |
|||
|
10 |
AdjustmentsToRetainedEarningsDebitAbstract Adjustments to Retained Earnings Debit |
|||
|
10.1 |
AdjustmentsToRetainedEarningsDebit |
|
||
|
15 |
AdjustmentsToRetainedEarningsDebit TOTAL Debits to Retained Earnings (Acct. 439) |
|
||
|
16 |
BalanceTransferredFromIncome Balance Transferred from Income (Account 433 less Account 418.1) |
|
|
|
|
17 |
AppropriationsOfRetainedEarningsAbstract Appropriations of Retained Earnings (Acct. 436) |
|||
|
22 |
AppropriationsOfRetainedEarnings TOTAL Appropriations of Retained Earnings (Acct. 436) |
|||
|
23 |
DividendsDeclaredPreferredStockAbstract Dividends Declared-Preferred Stock (Account 437) |
|||
|
29 |
DividendsDeclaredPreferredStock TOTAL Dividends Declared-Preferred Stock (Acct. 437) |
|||
|
30 |
DividendsDeclaredCommonStockAbstract Dividends Declared-Common Stock (Account 438) |
|||
|
30.1 |
DividendsDeclaredCommonStock |
|||
|
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) |
|
|
|
|
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) |
|
|
|
|
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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
STATEMENT OF CASH FLOWS |
||||||||||||
|
||||||||||||
| 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) |
|
|
|||||||||
|
3 |
NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income: |
|||||||||||
|
4 |
DepreciationAndDepletion Depreciation and Depletion |
|
|
|||||||||
|
5 |
NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details) |
|||||||||||
|
5.1 |
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription |
|
|
|||||||||
|
8 |
DeferredIncomeTaxesNet Deferred Income Taxes (Net) |
|
|
|||||||||
|
9 |
InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net) |
|
|
|||||||||
|
10 |
NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables |
|
|
|||||||||
|
11 |
NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory |
|
|
|||||||||
|
12 |
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory |
|
|
|||||||||
|
13 |
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses |
|
|
|||||||||
|
14 |
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets |
|
|
|||||||||
|
15 |
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities |
|
|
|||||||||
|
16 |
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction |
|
|
|||||||||
|
17 |
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies |
|
|
|||||||||
|
18 |
OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote): |
|||||||||||
|
18.1 |
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription (a) |
|
|
|||||||||
|
18.2 |
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription |
|
|
|||||||||
|
22 |
NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21) |
|
|
|||||||||
|
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) |
|
|
|||||||||
|
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 |
|
|
|||||||||
|
31 |
OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote): |
|||||||||||
|
31.1 |
OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription |
|
|
|||||||||
|
34 |
CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33) |
|
|
|||||||||
|
36 |
AcquisitionOfOtherNoncurrentAssets Acquisition of Other Noncurrent Assets (d) |
|||||||||||
|
37 |
ProceedsFromDisposalOfNoncurrentAssets Proceeds from Disposal of Noncurrent Assets (d) |
|
|
|||||||||
|
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 (b) |
|
|
|||||||||
|
53.2 |
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription |
|
|
|||||||||
|
53.3 |
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription |
|
||||||||||
|
57 |
CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55) |
|
|
|||||||||
|
59 |
CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities: |
|||||||||||
|
60 |
ProceedsFromIssuanceAbstract Proceeds from Issuance of: |
|||||||||||
|
61 |
ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b) |
|
||||||||||
|
62 |
ProceedsFromIssuanceOfPreferredStockFinancingActivities Preferred Stock |
|||||||||||
|
63 |
ProceedsFromIssuanceOfCommonStockFinancingActivities Common Stock |
|||||||||||
|
64 |
OtherAdjustmentsToCashFlowsFromFinancingActivities Other (provide details in footnote): |
|||||||||||
|
64.1 |
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription |
|||||||||||
|
64.2 |
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription |
|
|
|||||||||
|
66 |
NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c) |
|||||||||||
|
67 |
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote): |
|||||||||||
|
67.1 |
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities (c) |
|
|
|||||||||
|
67.2 |
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities |
|
||||||||||
|
67.3 |
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities |
|
||||||||||
|
70 |
CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69) |
|
|
|||||||||
|
72 |
PaymentsForRetirementAbstract Payments for Retirement of: |
|||||||||||
|
73 |
PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b) |
|
|
|||||||||
|
74 |
PaymentsForRetirementOfPreferredStockFinancingActivities Preferred Stock |
|||||||||||
|
75 |
PaymentsForRetirementOfCommonStockFinancingActivities Common Stock |
|||||||||||
|
76 |
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities Other (provide details in footnote): |
|||||||||||
|
76.1 |
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities |
|||||||||||
|
76.2 |
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities |
|
||||||||||
|
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) |
|
|
|||||||||
|
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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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| (b) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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INDEX OF NOTES TO FINANCIAL STATEMENTS
GLOSSARY OF TERMS FOR NOTES When the following terms and abbreviations appear in the text of this report, they have the meanings indicated below.
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1. ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES ORGANIZATION As a public utility, SWEPCo engages in the generation and purchase of electric power, and the subsequent sale, transmission and distribution of that power to approximately 548,000 retail customers in its service territory in northeastern and the panhandle of Texas, northwestern Louisiana and western Arkansas. SWEPCo sells electric power at wholesale to other utilities, municipalities and electric cooperatives. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Rates and Service Regulation SWEPCo’s rates are regulated by the FERC and the APSC, LPSC and PUCT. The FERC also regulates SWEPCo’s affiliated transactions, including AEPSC intercompany service billings which are generally at cost, under the 2005 Public Utility Holding Company Act and the Federal Power Act. The FERC also has jurisdiction over certain issuances and acquisitions of securities of the public utility subsidiaries, the acquisition or sale of certain utility assets and mergers with another electric utility or holding company. The state regulatory commissions also regulate certain intercompany transactions under various orders and affiliate statutes. Both the FERC and state regulatory commissions are permitted to review and audit the relevant books and records of companies within a public utility holding company system. The FERC regulates wholesale power markets and wholesale power transactions. SWEPCo’s wholesale power transactions are generally market-based. Wholesale power transactions are cost-based regulated when a cost-based contract is negotiated and filed with the FERC or the FERC determines that SWEPCo has “market power” in the region where the transaction occurs. Wholesale power supply contracts have been entered into with various municipalities and cooperatives that are FERC-regulated, cost-based contracts. These contracts are generally formula rate mechanisms, which are trued-up to actual costs annually. The APSC, LPSC and PUCT regulate all of the retail distribution operations and rates of SWEPCo’s retail public utility subsidiaries on a cost basis. The APSC, LPSC and PUCT also regulate the retail generation/power supply operations and rates. The FERC also regulates SWEPCo’s wholesale transmission operations and rates. Retail transmission rates are based upon the FERC OATT rate when retail rates are unbundled in connection with restructuring. In addition, the FERC regulates the SIA, Operating Agreement and TCA, all of which allocate shared system costs and revenues among the utility subsidiaries that are parties to each agreement. See Note 15 - Related Party Transactions for additional information. Basis of Accounting SWEPCo’s accounting is subject to the requirements of the APSC, LPSC, PUCT and the FERC. The financial statements have been prepared in accordance with the Uniform System of Accounts prescribed by the FERC. The principal differences from GAAP include:
Accounting for the Effects of Cost-Based Regulation SWEPCo’s financial statements reflect the actions of regulators that result in the recognition of certain revenues and expenses in different time periods than enterprises that are not rate-regulated. In accordance with accounting guidance for “Regulated Operations,” regulatory assets (deferred expenses) and regulatory liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of regulation in the same accounting period by matching expenses with their recovery through regulated revenues and by matching income with its passage to customers in cost-based regulated rates. Use of Estimates The preparation of these financial statements requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. These estimates include, but are not limited to, inventory valuation, allowance for doubtful accounts, long-lived asset impairment, unbilled electricity revenue, valuation of long-term energy contracts, the effects of regulation, long-lived asset recovery, storm costs, the effects of contingencies and certain assumptions made in accounting for pension and postretirement benefits. The estimates and assumptions used are based upon management’s evaluation of the relevant facts and circumstances as of the date of the financial statements. Actual results could ultimately differ from those estimates. Cash and Cash Equivalents Cash and Cash Equivalents include Cash, Working Fund and Temporary Cash Investments on the balance sheets with original maturities of three months or less. Supplementary Information
Special Deposits Special Deposits include funds held by trustees primarily for margin deposits for risk management activities. Inventory Fossil fuel inventories and materials and supplies inventories are carried at average cost. Accounts Receivable Customer accounts receivable primarily include receivables from wholesale and retail energy customers, receivables from energy contract counterparties related to risk management activities and customer receivables primarily related to other revenue-generating activities. Revenue is recognized over time as the performance obligations of delivering energy to customers are satisfied. To the extent that deliveries have occurred but a bill has not been issued, SWEPCo accrues and recognizes, as Accrued Utility Revenues on the balance sheets, an estimate of the revenues for energy delivered since the last billing. AEP Credit factors accounts receivable on a daily basis, excluding receivables from risk management activities, through purchase agreements with SWEPCo. AEP Credit has a receivables securitization agreement with bank conduits. Under the securitization agreement, AEP Credit receives financing from bank conduits for the interest in the billed and unbilled receivables they acquire from affiliated utility subsidiaries. See “Securitized Accounts Receivable – AEP Credit” section of Note 14 for additional information. Allowance for Uncollectible Accounts Generally, AEP Credit records bad debt expense based upon a 12-month rolling average of bad debt write-offs in proportion to gross accounts receivable purchased from SWEPCo. The assessment is performed by SWEPCo, which inherently contemplates any differences in geographical risk characteristics for the allowance. For customer accounts receivables relating to risk management activities, accounts receivables are reviewed for bad debt reserves at a specific counterparty level basis. For miscellaneous accounts receivable, bad debt expense is recorded based upon a 12-month rolling average of bad debt write-offs in proportion to gross accounts receivable, unless specifically identified. In addition to these processes, management contemplates available current information, as well as any reasonable and supportable forecast information, to determine if allowances for uncollectible accounts should be further adjusted in accordance with the accounting guidance for “Credit Losses.” Management’s assessments contemplate expected losses over the life of the accounts receivable. Concentrations of Credit Risk and Significant Customers SWEPCo does not have any significant customers that comprise 10% or more of its operating revenues for the years ended December 31, 2021 and 2020. SWEPCo monitors credit levels and the financial condition of its customers on a continuous basis to minimize credit risk. The APSC, LPSC and PUCT allow recovery in rates for a reasonable level of bad debt costs. Management believes adequate provisions for credit loss have been made in the accompanying financial statements. Property, Plant and Equipment Electric utility property, plant and equipment for rate-regulated operations are stated at original cost. Additions, major replacements and betterments are added to the plant accounts. Under the group composite method of depreciation, continuous interim routine replacements of items such as boiler tubes, pumps, motors, etc. result in original cost retirements, less salvage, being charged to accumulated depreciation. The group composite method of depreciation assumes that on average, asset components are retired at the end of their useful lives and thus there is no gain or loss. The equipment in each primary electric plant account is identified as a separate group. The depreciation rates that are established take into account the past history of interim capital replacements and the amount of removal cost incurred and salvage received. These rates and the related lives are subject to periodic review. Removal costs accrued are charged to accumulated depreciation. The costs of labor, materials and overhead incurred to operate and maintain plant and equipment are included in operating expenses. Long-lived assets are required to be tested for impairment when it is determined that the carrying value of the assets may no longer be recoverable or when the assets meet the held-for-sale criteria under the accounting guidance for “Impairment or Disposal of Long-Lived Assets.” When it becomes probable that an asset in-service or an asset under construction will be abandoned and regulatory cost recovery has been disallowed or is not probable, the cost of that asset shall be removed from plant-in-service or CWIP and charged to expense. The fair value of an asset is the amount at which that asset could be bought or sold in a current transaction between willing parties, as opposed to a forced or liquidation sale. Quoted market prices in active markets are the best evidence of fair value and are used as the basis for the measurement, if available. In the absence of quoted prices for identical or similar assets in active markets, fair value is estimated using various internal and external valuation methods including cash flow analysis and appraisals. Investment in Subsidiary Companies SWEPCo has two wholly-owned subsidiaries, DHLC, which is engaged in lignite-mining operations and Southwest Arkansas Utilities Corporation, which is engaged in right of way acquisition. Investment in the net assets of DHLC is carried at cost plus equity in its undistributed earnings since acquisition. Investment in the net assets of Southwest Arkansas Utilities Corporation is carried at cost. Allowance for Funds Used During Construction AFUDC represents the estimated cost of borrowed and equity funds used to finance construction projects that is capitalized and recovered through depreciation over the service life of regulated electric utility plant. Valuation of Nonderivative Financial Instruments The book values of Cash, Special Deposits, Working Fund, Notes Receivable from Associated Companies, Notes Payable to Associated Companies, accounts receivable and accounts payable approximate fair value because of the short-term maturity of these instruments. Fair Value Measurements of Assets and Liabilities The accounting guidance for “Fair Value Measurements and Disclosures” establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2. When quoted market prices are not available, pricing may be completed using comparable securities, dealer values, operating data and general market conditions to determine fair value. Valuation models utilize various inputs such as commodity, interest rate and, to a lesser degree, volatility and credit that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, market corroborated inputs (i.e. inputs derived principally from, or correlated to, observable market data) and other observable inputs for the asset or liability. For commercial activities, exchange-traded derivatives, namely futures contracts, are generally fair valued based on unadjusted quoted prices in active markets and are classified as Level 1. Level 2 inputs primarily consist of OTC broker quotes in moderately active or less active markets, as well as exchange-traded derivatives where there is insufficient market liquidity to warrant inclusion in Level 1. Management verifies price curves using these broker quotes and classifies these fair values within Level 2 when substantially all of the fair value can be corroborated. Management typically obtains multiple broker quotes, which are nonbinding in nature but are based on recent trades in the marketplace. When multiple broker quotes are obtained, the quoted bid and ask prices are averaged. In certain circumstances, a broker quote may be discarded if it is a clear outlier. Management uses a historical correlation analysis between the broker quoted location and the illiquid locations. If the points are highly correlated, these locations are included within Level 2 as well. Certain OTC and bilaterally executed derivative instruments are executed in less active markets with a lower availability of pricing information. Illiquid transactions, complex structured transactions, FTRs and counterparty credit risk may require nonmarket-based inputs. Some of these inputs may be internally developed or extrapolated and utilized to estimate fair value. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized as Level 3. The main driver of contracts being classified as Level 3 is the inability to substantiate energy price curves in the market. A portion of the Level 3 instruments have been economically hedged which limits potential earnings volatility. AEP utilizes its trustee’s external pricing service to estimate the fair value of the underlying investments held in the benefit plan trusts. AEP’s investment managers review and validate the prices utilized by the trustee to determine fair value. AEP’s management performs its own valuation testing to verify the fair values of the securities. AEP receives audit reports of the trustee’s operating controls and valuation processes. Assets in the benefits trusts are classified using the following methods. Equities are classified as Level 1 holdings if they are actively traded on exchanges. Items classified as Level 1 are investments in money market funds, fixed income and equity mutual funds and equity securities. They are valued based on observable inputs, primarily unadjusted quoted prices in active markets for identical assets. Items classified as Level 2 are primarily investments in individual fixed income securities. Fixed income securities generally do not trade on exchanges and do not have an official closing price but their valuation inputs are based on observable market data. Pricing vendors calculate bond valuations using financial models and matrices. The models use observable inputs including yields on benchmark securities, quotes by securities brokers, rating agency actions, discounts or premiums on securities compared to par prices, changes in yields for U.S. Treasury securities, corporate actions by bond issuers, prepayment schedules and histories, economic events and, for certain securities, adjustments to yields to reflect changes in the rate of inflation. Other securities with model-derived valuation inputs that are observable are also classified as Level 2 investments. Investments with unobservable valuation inputs are classified as Level 3 investments. Investments classified as Other are valued using Net Asset Value as a practical expedient. Items classified as Other are primarily cash equivalent funds, common collective trusts, commingled funds, structured products, private equity, real estate, infrastructure and alternative credit investments. These investments do not have a readily determinable fair value or they contain redemption restrictions which may include the right to suspend redemptions under certain circumstances. Redemption restrictions may also prevent certain investments from being redeemed at the reporting date for the underlying value. Deferred Fuel Costs The cost of fuel and related emission allowances and emission control chemicals/consumables is charged to Operation Expenses when the fuel is burned or the allowance or consumable is utilized. Fuel cost over-recoveries (the excess of fuel-related revenues over applicable fuel costs incurred) are generally deferred as regulatory liabilities and under-recoveries (the excess of applicable fuel costs incurred over fuel-related revenues) are generally deferred as regulatory assets. These deferrals are amortized when refunded or when billed to customers in later months with the APSC’s, LPSC’s and PUCT’s review and approval. The amount of an over-recovery or under-recovery can also be affected by actions of the APSC, LPSC and PUCT. On a routine basis, the APSC, LPSC and PUCT review and/or audit SWEPCo’s fuel procurement policies and practices, the fuel cost calculations and FAC deferrals. FAC deferrals are adjusted when costs are no longer probable of recovery or when refunds of fuel reserves are probable. SWEPCo shares the majority of its Off-system Sales margins to customers either through an active FAC or other rate mechanisms. Where the FAC or Off-system Sales sharing mechanism is capped, frozen or non-existent, changes in fuel costs or sharing of off-system sales impact earnings. Revenue Recognition Regulatory Accounting SWEPCo’s financial statements reflect the actions of regulators that can result in the recognition of revenues and expenses in different time periods than enterprises that are not rate-regulated. Regulatory assets (deferred expenses or alternative revenues recognized in accordance with the guidance for “Regulated Operations”) and regulatory liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of regulation in the same accounting period by matching expenses with their recovery through regulated revenues and by matching revenue with its passage to customers in cost-based regulated rates. When regulatory assets are probable of recovery through regulated rates, assets are recorded on the balance sheets. Regulatory assets are reviewed for probability of recovery at each balance sheet date or whenever new events occur. Examples of new events include the issuance of a regulatory commission order or passage of new legislation. If it is determined that recovery of a regulatory asset is no longer probable, the regulatory asset is derecognized as a charge against income. Retail and Wholesale Supply and Delivery of Electricity SWEPCo recognizes revenues from customers for retail and wholesale electricity sales and electricity transmission and distribution delivery services. SWEPCo recognizes such revenues on the statements of income as the performance obligations of delivering energy to customers are satisfied. Recognized revenues include both billed and unbilled amounts. In accordance with the APSC’s, LPSC’s and PUCT’s regulatory treatment, SWEPCo does not include the fuel portion in unbilled revenue, but rather recognizes such revenues when billed to customers. Wholesale transmission revenue is based on FERC-approved formula rate filings made for each calendar year using estimated costs. Revenues initially recognized per the annual rate filing are compared to actual costs, resulting in the subsequent recognition of an over or under-recovered amount, with interest, that is refunded or recovered, respectively, in a future year’s rates. These annual true-ups meet the definition of alternative revenues in accordance with the accounting guidance for “Regulated Operations”, and are recognized by SWEPCo in the second quarter of each calendar year following the filing of annual FERC reports. Any portion of the true-ups applicable to an affiliated company is recorded as Accounts Receivable from Associated Companies or Accounts Payable to Associated Companies on the balance sheets. Any portion of the true-ups applicable to third-parties is recorded as regulatory assets or regulatory liabilities on the balance sheets. See Note 17 - Revenue from Contracts with Customers for additional information. Gross versus Net Presentation of Certain Electricity Supply and Delivery Activities Most of the power produced at the generation plants is sold to SPP. SWEPCo also purchases power from SPP to supply power to customers. Generally, these power sales and purchases are reported on a net basis as revenues on the statements of income. However, purchases of power in excess of sales to SPP, on an hourly net basis, used to serve retail load are recorded gross as Operation Expenses on the statements of income. Physical energy purchases arising from non-derivative contracts are accounted for on a gross basis in Operation Expenses on the statements of income. Energy purchases arising from non-trading derivative contracts are recorded based on the transaction’s facts and circumstances. Purchases under non-trading derivatives used to serve accrual based obligations are recorded in Operation Expenses on the statements of income. All other non-trading derivative purchases are recorded net in revenues. In general, SWEPCo records expenses when purchased electricity is received and when expenses are incurred. SWEPCo defers unrealized MTM amounts as regulatory assets (for losses) and regulatory liabilities (for gains). Energy Marketing and Risk Management Activities SWEPCo engages in power, capacity and, to a lesser extent, natural gas marketing as a major power producer and participant in electricity and natural gas markets. SWEPCo also engages in power, capacity, coal, natural gas and, to a lesser extent, heating oil, gasoline and other commodity risk management activities focused on markets where the AEP System owns assets and on adjacent markets. These activities include the purchase-and-sale of energy under forward contracts at fixed and variable prices. These contracts include physical transactions, exchange-traded futures, and to a lesser extent, OTC swaps and options. Certain energy marketing and risk management transactions are with RTOs. SWEPCo recognizes revenues from marketing and risk management transactions that are not derivatives as the performance obligation of delivering the commodity is satisfied. Expenses from marketing and risk management activities that are not derivatives are also recognized upon delivery of the commodity. SWEPCo uses MTM accounting for marketing and risk management transactions that are derivatives unless the derivative is designated in a qualifying cash flow hedge relationship or elected normal under the normal purchase normal sale election. Unrealized MTM gains and losses are included on SWEPCo balance sheets as Derivative Instrument Assets or Liabilities, as appropriate, and on the statements of income in Operating Revenues. Realized gains and losses on marketing and risk management transactions are included in revenues or expenses based on the transaction’s facts and circumstances. However, in regulated jurisdictions subject to cost-based regulation, unrealized MTM amounts and some realized gains and losses are deferred as regulatory assets (for losses) and regulatory liabilities (for gains). Certain qualifying marketing and risk management derivatives transactions are designated as hedges of variability in future cash flows as a result of forecasted transactions (cash flow hedge). In the event SWEPCo designates a cash flow hedge, the cash flow hedge’s gain or loss is initially recorded as a component of AOCI. When the forecasted transaction is realized and affects net income, SWEPCo subsequently reclassifies the gain or loss on the hedge from AOCI into revenues or expenses within the same financial statement line item as the forecasted transaction on their statements of income. See “Accounting for Cash Flow Hedging Strategies” section of Note 10 for additional information. Maintenance SWEPCo expenses maintenance costs as incurred. If it becomes probable that SWEPCo will recover specifically-incurred costs through future rates, a regulatory asset is established to match the expensing of those maintenance costs with its recovery in cost-based regulated revenues. SWEPCo defers costs above the level included in base rates and amortizes those deferrals commensurate with recovery through rate riders. Income Taxes and Investment and Production Tax Credits SWEPCo uses the liability method of accounting for income taxes. Under the liability method, deferred income taxes are provided for all temporary differences between the book and tax basis of assets and liabilities which will result in a future tax consequence. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which the temporary differences are expected to be recovered or settled. When the flow-through method of accounting for temporary differences is required by a regulator to be reflected in regulated revenues (that is, when deferred taxes are not included in the cost-of-service for determining regulated rates for electricity), deferred income taxes are recorded and related regulatory assets and liabilities are established to match the regulated revenues and tax expense. SWEPCo applies the deferral methodology for the recognition of ITCs. Deferred ITCs are amortized to income tax expense over the life of the asset that generated the credit. Amortization of deferred ITCs begins when the asset is placed in-service, except where regulatory commissions reflect ITCs in the rate-making process, then amortization begins when the cash tax benefit is recognized. Alternatively, PTCs reduce income tax expense as they are earned. PTCs are earned when electricity is produced. SWEPCo accounts for uncertain tax positions in accordance with the accounting guidance for “Income Taxes.” SWEPCo classifies interest expense or income related to uncertain tax positions as interest expense or income as appropriate and classifies penalties as Penalties on the statements of income. Excise Taxes As an agent for some state and local governments, SWEPCo collects from customers certain excise taxes levied by those state or local governments on customers. SWEPCo does not record these taxes as revenue or expense. Debt Gains and losses from the reacquisition of debt used to finance regulated electric utility plants are deferred and amortized over the remaining term of the reacquired debt in accordance with their rate-making treatment unless the debt is refinanced. If the reacquired debt associated with the regulated business is refinanced, the reacquisition costs attributable to the portions of the business that are subject to cost-based regulatory accounting are generally deferred and amortized over the term of the replacement debt consistent with its recovery in rates. Debt discount or premium and debt issuance expenses are deferred and amortized generally utilizing the straight-line method over the term of the related debt. The straight-line method approximates the effective interest method and is consistent with the treatment in rates for regulated operations. Pension and OPEB Plans SWEPCo participates in an AEP sponsored qualified pension plan and two unfunded nonqualified pension plan. Substantially all SWEPCo employees are covered by the qualified plan or both the qualified and a nonqualified pension plan. SWEPCo also participates in OPEB plans sponsored by AEP to provide health and life insurance benefits for retired employees. SWEPCo is allocated a proportionate share of benefit costs and account for their participation in these plans as multiple-employer plans. See Note 8 - Benefit Plans for additional information including significant accounting policies associated with the plans. Investments Held in Trust for Future Liabilities AEP has several trust funds with significant investments intended to provide for future payments of pension and OPEB benefits. All of the trust funds’ investments are diversified and managed in compliance with all laws and regulations. The investment strategy for the trust funds is to use a diversified portfolio of investments to achieve an acceptable rate of return while managing the investment risk of the assets relative to the associated liabilities. To minimize investment risk, the trust funds are broadly diversified among classes of assets, investment strategies and investment managers. Management regularly reviews the actual asset allocations and periodically rebalances the investments to targeted allocations when appropriate. Investment policies and guidelines allow investment managers in approved strategies to use financial derivatives to obtain or manage market exposures and to hedge assets and liabilities. The investments are reported at fair value under the “Fair Value Measurements and Disclosures” accounting guidance. Benefit Plans All benefit plan assets are invested in accordance with each plan’s investment policy. The investment policy outlines the investment objectives, strategies and target asset allocations by plan. The investment philosophies for AEP’s benefit plans support the allocation of assets to minimize risks and optimize net returns. Strategies used include: •Maintaining a long-term investment horizon. •Diversifying assets to help control volatility of returns at acceptable levels. •Managing fees, transaction costs and tax liabilities to maximize investment earnings. •Using active management of investments where appropriate risk/return opportunities exist. •Keeping portfolio structure style-neutral to limit volatility compared to applicable benchmarks. •Using alternative asset classes such as real estate and private equity to maximize return and provide additional portfolio diversification. The objective of the investment policy for the pension fund is to maintain the funded status of the plan while providing for growth in the plan assets to offset the growth in the plan liabilities. The current target asset allocations are as follows:
The investment policy for each benefit plan contains various investment limitations. The investment policies establish concentration limits for securities and prohibit the purchase of securities issued by AEP (with the exception of proportionate and immaterial holdings of AEP securities in passive index strategies or certain commingled funds). However, the investment policies do not preclude the benefit trust funds from receiving contributions in the form of AEP securities, provided that the AEP securities acquired by each plan may not exceed the limitations imposed by law. For equity investments, the concentration limits are generally as follows: •No security in excess of 5% of all equities. •Cash equivalents must be less than 10% of an investment manager’s equity portfolio. •No individual stock may be more than 10% and 7% for pension and OPEB investments, respectively, of each manager’s equity portfolio. •No securities may be bought or sold on margin or other use of leverage. For fixed income investments, each investment manager’s portfolio is compared to investment grade, diversified long and intermediate benchmark indices. A portion of the pension assets is invested in real estate funds to provide diversification, add return and hedge against inflation. Real estate properties are illiquid, difficult to value and not actively traded. The pension plan uses external real estate investment managers to invest in commingled funds that hold real estate properties. To mitigate investment risk in the real estate portfolio, commingled real estate funds are used to ensure that holdings are diversified by region, property type and risk classification. Real estate holdings include core, value-added and opportunistic classifications. A portion of the pension assets is invested in private equity. Private equity investments add return and provide diversification and typically require a long-term time horizon to evaluate investment performance. Private equity is classified as an alternative investment because it is illiquid, difficult to value and not actively traded. The pension plan uses limited partnerships to invest across the private equity investment spectrum. The private equity holdings are with multiple general partners who help monitor the investments and provide investment selection expertise. The holdings are currently comprised of venture capital, buyout and hybrid debt and equity investments. AEP participates in a securities lending program with BNY Mellon to provide incremental income on idle assets and to provide income to offset custody fees and other administrative expenses. AEP lends securities to borrowers approved by BNY Mellon in exchange for collateral. All loans are collateralized by at least 102% of the loaned asset’s market value and the collateral is invested. The difference between the rebate owed to the borrower and the collateral rate of return determines the earnings on the loaned security. The securities lending program’s objective is to provide modest incremental income with a limited increase in risk. As of December 31, 2021 and 2020, the fair value of securities on loan as part of the program was $137 million and $177 million, respectively. Cash and securities obtained as collateral exceeded the fair value of the securities loaned as of December 31, 2021 and 2020. Trust owned life insurance (TOLI) underwritten by The Prudential Insurance Company is held in the OPEB plan trusts. The strategy for holding life insurance contracts in the taxable Voluntary Employees’ Beneficiary Association trust is to minimize taxes paid on the asset growth in the trust. Earnings on plan assets are tax-deferred within the TOLI contract and can be tax-free if held until claims are paid. Life insurance proceeds remain in the trust and are used to fund future retiree medical benefit liabilities. With consideration to other investments held in the trust, the cash value of the TOLI contracts is invested in two diversified funds. A portion is invested in a commingled fund with underlying investments in stocks that are actively traded on major international equity exchanges. The other portion of the TOLI cash value is invested in a diversified, commingled fixed income fund with underlying investments in government bonds, corporate bonds and asset-backed securities. Cash and cash equivalents are held in each trust to provide liquidity and meet short-term cash needs. Cash equivalent funds are used to provide diversification and preserve principal. The underlying holdings in the cash funds are investment grade money market instruments including commercial paper, certificates of deposit, treasury bills and other types of investment grade short-term debt securities. The cash funds are valued each business day and provide daily liquidity. Comprehensive Income (Loss) Comprehensive income (loss) is defined as the change in equity (net assets) of a business enterprise during a period from transactions and other events and circumstances from non-owner sources. It includes all changes in equity during a period except those resulting from investments by owners and distributions to owners. Subsequent Events Management has evaluated the impact of events occurring after December 31, 2021 through February 24, 2022, the date that AEP’s Form 10-K was issued, and has updated such evaluation for disclosure purposes through April 14, 2022. These financial statements include all necessary adjustments and disclosures resulting from these evaluations. 2. NEW ACCOUNTING STANDARDS During the FASB’s standard-setting process and upon issuance of final standards, management reviews the new accounting literature to determine its relevance, if any, to SWEPCo’s business. There are no new standards expected to have a material impact on SWEPCo’s financial statements. 3. COMPREHENSIVE INCOME Presentation of Comprehensive Income The following tables provide the components of changes in AOCI and details of reclassifications from AOCI for the years ended December 31, 2021 and 2020. The amortization of pension and OPEB AOCI components are included in the computation of net periodic pension and OPEB costs. See Note 8 - Benefit Plans for additional information.
(a)Amounts reclassified to the referenced line item on the statements of income. 4. RATE MATTERS SWEPCo is involved in rate and regulatory proceedings at the FERC and the APSC, LPSC and PUCT. Rate matters can have a material impact on net income, cash flows and possibly financial condition. SWEPCo’s recent significant rate orders and pending rate filings are addressed in this note. 2012 Texas Base Rate Case In 2012, SWEPCo filed a request with the PUCT to increase annual base rates primarily due to the completion of the Turk Plant. In 2013, the PUCT issued an order affirming the prudence of the Turk Plant but determined that the Turk Plant’s Texas jurisdictional capital cost cap established in a previous Certificate of Convenience and Necessity case also limited SWEPCo’s recovery of AFUDC in addition to limits on its recovery of cash construction costs. Upon rehearing in 2014, the PUCT reversed its initial ruling and determined that AFUDC was excluded from the Turk Plant’s Texas jurisdictional capital cost cap. As a result, SWEPCo reversed $114 million of a previously recorded regulatory disallowance in 2013. In 2017, the Texas District Court upheld the PUCT’s 2014 order and intervenors filed appeals with the Texas Third Court of Appeals. In July 2018, the Texas Third Court of Appeals reversed the PUCT’s judgment affirming the prudence of the Turk Plant and remanded the issue back to the PUCT. In January 2019, SWEPCo and the PUCT filed petitions for review with the Texas Supreme Court. In March 2021, the Texas Supreme Court issued an opinion reversing the July 2018 judgment of the Texas Third Court of Appeals and agreeing with the PUCT’s judgment affirming the prudence of the Turk Plant. In addition, the Texas Supreme Court remanded the AFUDC dispute back to the Texas Third Court of Appeals. No parties filed a motion for rehearing with the Texas Supreme Court. In August 2021, the Texas Third Court of Appeals reversed the Texas District Court judgement affirming the PUCT’s order on AFUDC, concluding that the language of the PUCT’s original 2008 order intended to include AFUDC in the Texas jurisdictional capital cost cap, and remanded the case to the PUCT for future proceedings. SWEPCo disagrees with the Court of Appeals decision and submitted a Petition for Review with the Texas Supreme Court in November 2021. The Texas Supreme Court requested responses to the Petition for Review, which are due by the end of March 2022. If SWEPCo is ultimately unable to recover capitalized Turk Plant costs, including AFUDC in excess of the Texas jurisdictional capital cost cap, it would be expected to result in a pretax net disallowance ranging from $80 million to $100 million. In addition, if AFUDC is ultimately determined to be included in the Texas jurisdictional capital cost cap, SWEPCo estimates it may be required to make customer refunds ranging from $0 to $160 million related to revenues collected from February 2013 through December 2021 and such determination may reduce SWEPCo’s future revenues by approximately $15 million on an annual basis. 2016 Texas Base Rate Case In 2016, SWEPCo filed a request with the PUCT for a net increase in Texas annual revenues of $69 million based upon a 10% ROE. In January 2018, the PUCT issued a final order approving a net increase in Texas annual revenues of $50 million based upon a ROE of 9.6%, effective May 2017. The final order also included: (a) approval to recover the Texas jurisdictional share of environmental investments placed in- service, as of June 30, 2016, at various plants, including Welsh Plant, Units 1 and 3, (b) approval of recovery of, but no return on, the Texas jurisdictional share of the net book value of Welsh Plant, Unit 2, (c) approval of $2 million in additional vegetation management expenses and (d) the rejection of SWEPCo’s proposed transmission cost recovery mechanism. As a result of the final order, in 2017 SWEPCo: (a) recorded an impairment charge of $19 million, which included $7 million associated with the lack of return on Welsh Plant, Unit 2 and $12 million related to other disallowed plant investments, (b) recognized $32 million of additional revenues, for the period of May 2017 through December 2017, that was surcharged to customers in 2018 and (c) recognized an additional $7 million of expenses consisting primarily of depreciation expense and vegetation management expense, offset by the deferral of rate case expense. SWEPCo implemented new rates in February 2018 billings. The $32 million of additional 2017 revenues was collected during 2018. In March 2018, the PUCT clarified and corrected portions of the final order, without changing the overall decision or amounts of the rate change. The order has been appealed by various intervenors. The appeal will move forward following the conclusion of the 2012 Texas Base Rate Case. If certain parts of the PUCT order are overturned, it could reduce future net income and cash flows and impact financial condition. 2020 Texas Base Rate Case In October 2020, SWEPCo filed a request with the PUCT for a $105 million annual increase in Texas base rates based upon a proposed 10.35% ROE. The request would move transmission and distribution interim revenues recovered through riders into base rates. Eliminating these riders would result in a net annual requested base rate increase of $90 million primarily due to increased investments. The proposed net annual increase: (a) includes $5 million related to vegetation management to maintain and improve the reliability of SWEPCo’s Texas jurisdictional distribution system, (b) requests a $10 million annual depreciation increase and (c) seeks $2 million annually to establish a storm catastrophe reserve. In addition, SWEPCo also requested recovery of the Texas jurisdictional share of the Dolet Hills Power Station of $45 million which was retired in December 2021. SWEPCo subsequently filed a request with the PUCT lowering the requested annual increase in Texas base rates to $100 million which would result in an $85 million net annual base rate increase after moving the proposed riders to rate base. In January 2022, the PUCT issued a final order approving an annual revenue increase of $39 million based upon a 9.25% ROE. The order also includes: (a) rates implemented retroactively back to March 18, 2021, (b) $5 million of the proposed increase related to vegetation management, (c) $2 million annually to establish a storm catastrophe reserve (d) the creation of a rider that would recover the Dolet Hills Power Station as if it were in rate base until its retirement at the end of 2021 and starting in 2022 the remaining net book value would be recovered as a regulatory asset through 2046. As a result of the final order, SWEPCo recorded a disallowance of $12 million associated with the lack of return on the Dolet Hills Power Station. In February 2022, SWEPCo filed a motion for rehearing with the PUCT challenging several errors in the order, which include challenges of the approved ROE, the denial of a reasonable return or carrying costs on the Dolet Hills Power Station and the calculation of the Texas jurisdictional share of the storm catastrophe reserve. 2020 Louisiana Base Rate Case In December 2020, SWEPCo filed a request with the LPSC for a $134 million annual increase in Louisiana base rates based upon a proposed 10.35% ROE. SWEPCo subsequently revised the requested annual increase to $114 million to reflect removing hurricane storm restoration costs from the base case filing. The hurricane costs have been requested in a separate storm filing. See “2021 Louisiana Storm Cost Filing” below for more information. The base case filing would extend the formula rate plan for five years and includes modifications to the formula rate plan to allow for forward-looking transmission costs, reflects the impact of net operating losses associated with the acceleration of certain tax benefits and incorporates future federal corporate income tax changes. The proposed net annual increase requests a $32 million annual depreciation increase to recover Louisiana’s share of the Dolet Hills Power Station, Pirkey Power Plant and Welsh Plant, all of which are expected to be retired early. In July 2021, the LPSC staff filed testimony supporting a $6 million annual increase in base rates based upon a ROE of 9.1% while other intervenors recommended a ROE ranging from 9.35% to 9.8%. The primary differences between SWEPCo’s requested annual increase in base rates and the LPSC staff’s recommendation include: (a) a reduction in depreciation expense, (b) recovery of Dolet Hills Power Station and Pirkey Power Plant in a separate rider mechanism, (c) the rejection of SWEPCo’s proposed adjustment to include a stand-alone net operating loss carryforward deferred tax asset in rate base and (d) a reduction in the proposed ROE. In September 2021, SWEPCo filed rebuttal testimony supporting a revised requested annual increase in base rates of $95 million. The primary differences in the rebuttal testimony from the previous revised request of $114 million are modifications to the proposed recovery of the Dolet Hills Power Station and revisions to various proposed amortizations. LPSC staff and intervenor responses to SWEPCo’s rebuttal testimony were filed in October 2021. The procedural schedule for the case is on hold due to ongoing settlement discussions. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. 2021 Arkansas Base Rate Case In July 2021, SWEPCo filed a request with the APSC for an $85 million annual increase in Arkansas base rates based upon a proposed 10.35% ROE with a capital structure of 48.7% debt and 51.3% common equity. The proposed annual increase includes: (a) a $41 million revenue requirement for the North Central Wind Facilities, (b) a $14 million annual depreciation increase primarily due to recovery of the Dolet Hills Power Station through 2026 and Pirkey Plant and Welsh Plant, Units 1 and 3 through 2037 and (c) a $6 million increase due to SPP costs. SWEPCo requested that rates become effective in June 2022. APSC staff filed testimony supporting a $47 million annual increase in base rates based upon a ROE of 9.3% while other intervenors recommended a ROE ranging from 8.75% to 9.25%. The primary differences between SWEPCo’s requested annual increase in base rates and the APSC staff’s recommendation include: (a) recovery of the Dolet Hills Power Station through 2046 with no debt or equity return, (b) a reduction in the proposed ROE with a capital structure of 55.5% debt and 44.5% common equity and (c) lower depreciation rates. The APSC staff also recommended future generating facility retirements be treated similar to the Dolet Hills Power Station recommendation of recovery with no debt or equity return. Also, an intervenor recommended no debt or equity return on the Pirkey Power Plant after its retirement, which is currently expected to be in 2023. SWEPCo filed rebuttal testimony in January 2022 revising the requested annual increase in Arkansas base rates to $81 million with rates to be effective in June 2022. A hearing will be held at the APSC in March 2022. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. 2021 Louisiana Storm Cost Filing In 2020, Hurricanes Laura and Delta caused power outages and extensive damage to the SWEPCo service territories, primarily impacting the Louisiana jurisdiction. Following both hurricanes, the LPSC issued orders allowing Louisiana utilities, including SWEPCo, to establish regulatory assets to track and defer expenses associated with these storms. In February 2021, severe winter weather impacted the Louisiana jurisdiction and in March 2021, the LPSC approved the deferral of incremental storm restoration expenses related to the winter storm. In October 2021, SWEPCo filed a request with the LPSC for recovery of $145 million in deferred storm costs associated with the three storms. As part of the filing, SWEPCo requested recovery of the carrying charges on the deferred regulatory asset at a weighted average cost of capital through a rider beginning in January 2022. LPSC staff testimony is due to the LPSC in May 2022 and an order is expected before the end of 2022. If any of the storm costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. February 2021 Severe Winter Weather Impacts in SPP As discussed in the “PSO Rate Matters” section above, severe winter weather had a significant impact in SPP, resulting in significantly increased market prices for natural gas power plants to meet reliability needs for the SPP electric system. For the time period of February 9, 2021, to February 20, 2021, SWEPCo’s natural gas expenses and purchases of electricity still to be recovered from customers are $430 million as of December 31, 2021, of which $103 million, $148 million and $179 million is related to the Arkansas, Louisiana and Texas jurisdictions, respectively. In March 2021, the APSC issued an order authorizing recovery of the Arkansas jurisdictional share of the retail customer fuel costs over five years, with the appropriate carrying charge to be determined at a later date. Subsequently, SWEPCo began recovery of these fuel costs. SWEPCo is currently recovering the fuel costs at an interim carrying charge of 0.3%. In April 2021, SWEPCo filed testimony supporting a five-year recovery with a carrying charge of 6.05%, which has been supported by APSC staff. Various other parties have recommended recovery periods ranging from 5-20 years with a carrying charge of 1.65%. The APSC ordered more testimony regarding the option of utilizing securitization to recover the fuel costs. SWEPCo is awaiting a decision from the APSC. The prudence of these fuel costs is expected to be addressed in a separate proceeding. In March 2021, the LPSC approved a special order granting a temporary modification to the FAC and shortly after SWEPCo began recovery of its Louisiana jurisdictional share of these fuel costs based on a five-year recovery period inclusive of an interim carrying charge of 3.25%. SWEPCo will work with the LPSC to finalize the actual recovery period and determine the appropriate carrying charge in future proceedings. In August 2021, SWEPCo filed an application with the PUCT to implement a net interim fuel surcharge for the Texas jurisdictional share of these retail fuel costs. The application requested a five-year recovery with a carrying charge of 7.18%. In October 2021, various intervenors filed testimony supporting a five-year recovery with a carrying charge ranging from 0.82% to 1.625%. In January 2022, an ALJ issued a PFD recommending a four-year recovery with a carrying charge the same as the annually set interest rate used for under-recovered fuel. In February 2022, SWEPCo filed exceptions to the PFD, disagreeing with the short-term interest rate recommended by the ALJ. SWEPCo is awaiting an order from the PUCT. If SWEPCo is unable to recover any of the costs relating to the extraordinary fuel and purchases of electricity, or obtain authorization of a reasonable carrying charge on these costs, it could reduce future net income and cash flows and impact financial condition. FERC Rate Matters FERC SPP Transmission Formula Rate Challenge In May 2021, certain joint customers submitted a formal challenge at the FERC related to the 2020 Annual Update of the 2019 SPP Transmission Formula Rates of the AEP transmission owning subsidiaries within SPP, including SWEPCo. In March 2022, the FERC issued an order on the formal challenge which ruled in favor of the joint customers on certain issues, including an accounting issue in which the FERC determined that SWEPCo should record public service commission fees in FERC account 928 rather than FERC account 408.1. The 2021 FERC Form 1 financial statements reflect the outcome of this order. If any refunds are ordered for previous years they will be processed as part of the annual formula rate filing true-up process. 5. EFFECTS OF REGULATION Coal-Fired Generation Plants Compliance with extensive environmental regulations requires significant capital investment in environmental monitoring, installation of pollution control equipment, emission fees, disposal costs and permits. Management continuously evaluates cost estimates of complying with these regulations which has resulted in, and in the future may result in, a decision to retire coal-fired generating facilities earlier than their currently estimated useful lives. Management is seeking or will seek regulatory recovery, as necessary, for any net book value remaining when the plants are retired. To the extent the net book value of these generation assets are not deemed recoverable, it could materially reduce future net income and cash flows and impact financial condition. Regulated Generating Units that have been Retired In April 2016, Welsh Plant, Unit 2 was retired. As part of the 2016 Texas Base Rate Case, the PUCT authorized recovery of SWEPCo’s Texas jurisdictional share of Welsh Plant, Unit 2, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $7 million in 2017. See “2016 Texas Base Rate Case” section of Note 4 for additional information. As part of the 2019 Arkansas Base Rate Case, SWEPCo received approval from the APSC to recover the Arkansas jurisdictional share of Welsh Plant, Unit 2. In December 2020, SWEPCo filed a request with the LPSC to recover the Louisiana jurisdictional share of Welsh Plant, Unit 2. See “2020 Louisiana Base Rate Case” section of Note 4 for additional information. As of December 31, 2021, SWEPCo has plant retirement costs pending approval recorded on its balance sheet of $35 million related to the Louisiana jurisdictional share of Welsh Plant, Unit 2. In December 2021, the Dolet Hills Power Station was retired. As part of the 2020 Texas Base Rate Case, the PUCT authorized recovery of SWEPCo’s Texas jurisdictional share of the Dolet Hills Power Station, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $12 million in December 2021. SWEPCo has also requested recovery of the Dolet Hills Power Station in the Arkansas and Louisiana jurisdictions through base rate cases. See “2020 Texas Base Rate Case”, “2020 Louisiana Base Rate Case” and “2021 Arkansas Base Rate Case” sections of Note 4 for additional information. The Dolet Hills Power Station is currently being recovered through 2026 in the Louisiana jurisdiction and through 2046 in the Arkansas and Texas jurisdictions. As of December 31, 2021, SWEPCo has plant retirement costs for the Dolet Hills Power Station pending approval recorded on its balance sheet of $72 million related to the Arkansas and Louisiana jurisdictional shares. Regulated Generating Units to be Retired In November 2020, management announced plans to retire Pirkey Power Plant in 2023 and that it will cease using coal at the Welsh Plant in 2028. As a result of the announcement, SWEPCo began recording accelerated depreciation. The table below summarizes the net book value including CWIP, before cost of removal and materials and supplies, as of December 31, 2021, of generating facilities planned for early retirement:
(a)Represents the amount of annual depreciation that has been collected from customers over the prior 12-month period. (b)Pirkey Power Plant is currently being recovered through 2025 in the Louisiana jurisdiction and through 2045 in the Arkansas and Texas jurisdictions. (c)Includes Welsh Plant, Unit 2, which was retired in 2016. Removal of Welsh Plant, Unit 2, will be performed with Welsh Plant, Units 1 and 3, after retirement. (d)Unit 1 is being recovered through 2027 in the Louisiana jurisdiction and through 2037 in the Arkansas and Texas jurisdictions. Unit 3 is being recovered through 2032 in the Louisiana jurisdiction and through 2042 in the Arkansas and Texas jurisdictions. Dolet Hills Power Station and Related Fuel Operations In 2020, management of SWEPCo and CLECO determined DHLC would not proceed developing additional Oxbow Lignite Company (Oxbow) mining areas for future lignite extraction and ceased extraction of lignite at the mine in May 2020. In April 2020, SWEPCo and CLECO jointly filed a notification letter to the LPSC providing notice of the cessation of lignite mining. In December 2021, the Dolet Hills Power Station was retired. The Dolet Hills Power Station non-fuel costs are recoverable by SWEPCo through base rates. As of December 31, 2021, SWEPCo’s share of the net investment in the Dolet Hills Power Station is $108 million, including materials and supplies, net of cost of removal collected in rates. Fuel costs incurred by the Dolet Hills Power Station are recoverable by SWEPCo through active fuel clauses. As of December 31, 2021, SWEPCo had a net under-recovered fuel balance of $144 million, excluding impacts of the February 2021 severe winter weather event, which includes fuel consumed at the Dolet Hills Power Station. Additional reclamation and other land-related costs incurred by DHLC and Oxbow will be billed to SWEPCo and included in existing fuel clauses. In June 2020, SWEPCo filed a fuel reconciliation with the PUCT for its retail operations in Texas, including Dolet Hills, for the reconciliation period of March 1, 2017 to December 31, 2019. See “2020 Texas Fuel Reconciliation” below for additional information. In March 2021, the LPSC issued an order allowing SWEPCo to recover up to $20 million of fuel costs in 2021 and defer approximately $30 million of additional costs with a recovery period to be determined at a later date. In November 2021, the LPSC issued a directive which deferred the issues regarding modification of the level and timing of recovery of the Dolet Hills Power Station from SWEPCo’s pending rate case to a separate existing docket. In addition, the recovery of the deferred fuel costs are planned to be addressed. In March 2021, the APSC approved fuel rates that provide recovery of the Arkansas share of the 2021 Dolet Hills Power Station fuel costs over five years through the existing fuel clause. In the Arkansas base case, Staff proposed an extension of the recovery period to 25 years. See “2021 Arkansas Base Rate Case” section of Note 4 for additional information. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. Pirkey Power Plant and Related Fuel Operations In 2020, management announced plans to retire the Pirkey Power Plant in 2023. The Pirkey Power Plant non-fuel costs are recoverable by SWEPCo through base rates and fuel costs are recovered through active fuel clauses. As of December 31, 2021, SWEPCo’s share of the net investment in the Pirkey Power Plant is $207 million, including CWIP, before cost of removal. Sabine is a mining operator providing mining services to the Pirkey Power Plant. Under the provisions of the mining agreement, SWEPCo is required to pay, as part of the cost of lignite delivered, an amount equal to mining costs plus a management fee. SWEPCo expects fuel deliveries, including billings of all fixed and operating costs, from Sabine to cease during the first quarter of 2023. Under the fuel agreements, SWEPCo’s fuel inventory and unbilled fuel costs from mining related activities were $91 million as of December 31, 2021. Also, as of December 31, 2021, SWEPCo had a net under-recovered fuel balance of $144 million, excluding impacts of the February 2021 severe winter weather event, which includes fuel consumed at the Pirkey Power Plant. Additional operational, reclamation and other land-related costs incurred by Sabine will be billed to SWEPCo and included in existing fuel clauses. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. 2020 Texas Fuel Reconciliation In June 2020, SWEPCo filed a fuel reconciliation with the PUCT for its retail operations in Texas for the reconciliation period of March 1, 2017 to December 31, 2019. The fuel reconciliation included total fuel costs of $1.7 billion ($616 million of which is related to the Texas jurisdiction). In January 2021, various parties filed testimony recommending fuel cost disallowances totaling $125 million relating to the Texas jurisdiction. Also in January 2021, SWEPCo filed rebuttal testimony disputing the recommended disallowances. In February 2021, SWEPCo and various parties reached a settlement in principle which resulted in a $10 million reduction in recoverable fuel costs for the reconciliation period, which was recognized in SWEPCo’s 2020 financial statements. In November 2021, the settlement was approved by the PUCT. Regulatory Assets and Liabilities Regulatory assets and liabilities are comprised of the following items:
(a)2021 amount includes Arkansas, Louisiana and Texas jurisdictions. 2020 amount includes Louisiana jurisdiction. (b)Unrecovered Winter Storm Fuel Costs are pending final regulatory approval as of December 31, 2021. The current asset balance represents amounts expected to be recovered in the Arkansas and Louisiana jurisdictions over the next 12 months. See “February 2021 Severe Winter Weather Impacts in SPP” section of SWEPCo Rate Matters in Note 4 for additional information.
(a)Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b)2020 amount includes Arkansas and Texas jurisdictions. (c)Refunded using ARAM. 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES SWEPCo is subject to certain claims and legal actions arising in the ordinary course of business. In addition, SWEPCo’s business activities are subject to extensive governmental regulation related to public health and the environment. The ultimate outcome of such pending or potential litigation cannot be predicted. Management accrues contingent liabilities only when management concludes that it is both probable that a liability has been incurred at the date of the financial statements and the amount of loss can be reasonably estimated. When management determines that it is not probable, but rather reasonably possible that a liability has been incurred at the date of the financial statements, management discloses such contingencies and the possible loss or range of loss if such estimate can be made. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may not represent the maximum possible loss exposure. Circumstances change over time and actual results may vary significantly from estimates. For current proceedings not specifically discussed below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on the financial statements. COMMITMENTS SWEPCo has substantial commitments for fuel, energy and capacity contracts as part of the normal course of business. Certain contracts contain penalty provisions for early termination. In accordance with the accounting guidance for “Commitments”, the following table summarizes SWEPCo’s actual contractual commitments as of December 31, 2021:
(a)Represents contractual commitments to purchase coal, natural gas and other consumables as fuel for electric generation along with related transportation of the fuel. GUARANTEES Liabilities for guarantees are recorded in accordance with the accounting guidance for “Guarantees.” There is no collateral held in relation to any guarantees. In the event any guarantee is drawn, there is no recourse to third-parties unless specified below. Indemnifications and Other Guarantees Contracts SWEPCo enters into certain types of contracts which require indemnifications. Typically these contracts include, but are not limited to, sale agreements, lease agreements, purchase agreements and financing agreements. Generally, these agreements may include, but are not limited to, indemnifications around certain tax, contractual and environmental matters. With respect to sale agreements, exposure generally does not exceed the sale price. As of December 31, 2021, there were no material liabilities recorded for any indemnifications. AEPSC conducts power purchase-and-sale activity on behalf of PSO and SWEPCo, who are jointly and severally liable for activity conducted on their behalf. Lease Obligations SWEPCo leases equipment under master lease agreements. See “Master Lease Agreements” section of Note 13 for additional information. ENVIRONMENTAL CONTINGENCIES The Comprehensive Environmental Response Compensation and Liability Act (Superfund) and State Remediation By-products from the generation of electricity include materials such as ash, slag and sludge. Coal combustion by-products, which constitute the overwhelming percentage of these materials, are typically treated and deposited in captive disposal facilities or are beneficially utilized. In addition, the generation plants and transmission and distribution facilities have used asbestos, polychlorinated biphenyls and other hazardous and non-hazardous materials. SWEPCo currently incurs costs to dispose of these substances safely. Superfund addresses clean-up of hazardous substances that are released to the environment. The Federal EPA administers the clean-up programs. Several states enacted similar laws. As of December 31, 2021, SWEPCo was named as a Potentially Responsible Party (PRP) for one site by the Federal EPA for which alleged liability is unresolved. There are three additional sites for which SWEPCo received information requests which could lead to PRP designation. In those instances where a PRP or defendant has been named, disposal or recycling activities were in accordance with the then-applicable laws and regulations. Superfund does not recognize compliance as a defense, but imposes strict liability on parties who fall within its broad statutory categories. Liability has been resolved for a number of sites with no significant effect on net income. Management evaluates the potential liability for each Superfund site separately, but several general statements can be made about potential future liability. Allegations that materials were disposed at a particular site are often unsubstantiated and the quantity of materials deposited at a site can be small and often non-hazardous. Although Superfund liability has been interpreted by the courts as joint and several, typically many parties are named as PRPs for each site and several of the parties are financially sound enterprises. As of December 31, 2021, management’s estimates do not anticipate material clean-up costs for identified Superfund sites. OPERATIONAL CONTINGENCIES Insurance and Potential Losses SWEPCo maintains insurance coverage normal and customary for electric utilities, subject to various deductibles. SWEPCo also maintains property and casualty insurance that may cover certain physical damage or third-party injuries caused by cyber security incidents. Insurance coverage includes all risks of physical loss or damage to nonnuclear assets, subject to insurance policy conditions and exclusions. Covered property generally includes power plants, substations, facilities and inventories. Excluded property generally includes transmission and distribution lines, poles and towers. The insurance programs also generally provide coverage against loss arising from certain claims made by third-parties and are in excess of retentions absorbed by SWEPCo. Coverage is generally provided by a combination of the protected cell of EIS and/or various industry mutual and/or commercial insurance carriers. Some potential losses or liabilities may not be insurable or the amount of insurance carried may not be sufficient to meet potential losses and liabilities, including, but not limited to, liabilities relating to a cyber security incident. Future losses or liabilities, if they occur, which are not completely insured, unless recovered from customers, could reduce future net income and cash flows and impact financial condition. Claims Challenging Transition of American Electric Power System Retirement Plan to Cash Balance Formula Four participants in The American Electric Power System Retirement Plan (the Plan) filed a class action complaint in December 2021 in the U.S. District Court for the Southern District of Ohio against AEPSC and the Plan. When the Plan’s benefit formula was changed in the year 2000, AEP provided a special provision for employees hired before January 1, 2001, allowing them to continue benefit accruals under the then benefit formula for a full 10 years alongside of the new cash balance benefit formula then being implemented. Employees who were hired on or after January 1, 2001 accrued benefits only under the new cash balance benefit formula. The Plaintiffs assert a number of claims on behalf of themselves and the purported class, including that: (a) the Plan violates the requirements under the Employee Retirement Income Security Act (ERISA) intended to preclude back-loading the accrual of benefits to the end of a participant’s career, (b) the Plan violates the age discrimination prohibitions of ERISA and the Age Discrimination in Employment Act and (c) AEP failed to provide required notice regarding the changes to the Plan. Among other relief, the Complaint seeks reformation of the Plan to provide additional benefits and the recovery of plan benefits for former employees under such reformed plan. The Plaintiffs previously had submitted claims for additional plan benefits to AEP, which were denied. On February 15, 2022, AEPSC and the Plan filed a motion to dismiss the complaint for failure to state a claim. AEP will continue to defend against the claims. Management is unable to determine a range of potential losses that is reasonably possible of occurring. 7. ACQUISITIONS AND IMPAIRMENTS ACQUISITIONS North Central Wind Energy Facilities In 2020, PSO and SWEPCo received regulatory approvals to acquire the NCWF, comprised of three Oklahoma wind facilities totaling 1,484 MWs, on a fixed cost turn-key basis at completion. PSO and SWEPCo will own undivided interests of 45.5% and 54.5% of the NCWF, respectively. In total, the three wind facilities will cost approximately $2 billion and consist of Traverse (998 MW), Maverick (287 MW) and Sundance (199 MW). Output from the NCWF will serve retail load in PSO’s Oklahoma service territory and both retail and FERC wholesale load in SWEPCo’s service territories in Arkansas and Louisiana. The Oklahoma and Louisiana portions of the NCWF revenue requirement, net of PTC benefit, are recoverable through authorized riders beginning at commercial operation and until such time as amounts are reflected in base rates. Recovery of the Arkansas portion of the NCWF revenue requirement is requested in SWEPCo’s pending 2021 Arkansas Base Rate Case. The NCWF are subject to various regulatory performance requirements. If these performance requirements are not met, SWEPCo would recognize a regulatory liability to refund retail customers. As of December 31, 2021 SWEPCo has not incurred a material regulatory liability related to performance requirements for NCWF. In April 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Sundance during its development and construction for $270 million, the first of the three NCWF acquisitions. Immediately following the acquisition, PSO and SWEPCo liquidated the entity and simultaneously distributed the Sundance assets in proportion to their undivided ownership interests. Sundance was placed in-service in April 2021. In September 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Maverick during its development and construction for $383 million, the second of the three NCWF acquisitions. Immediately following the acquisition, PSO and SWEPCo liquidated the entity and simultaneously distributed the Maverick assets in proportion to their undivided ownership interests. Maverick was placed in-service in September 2021. In accordance with the guidance for “Business Combinations,” management determined that the acquisitions of Sundance and Maverick represent asset acquisitions. As of December 31, 2021, SWEPCo had approximately $378 million, of gross Utility Plant on the balance sheet, respectively, related to the Sundance and Maverick NCWF projects. On an ongoing basis, management further determined that PSO and SWEPCo should apply the joint plant accounting model to account for their respective undivided interests in the assets, liabilities, revenues and expenses of Sundance and Maverick. The Purchase and Sale Agreement (PSA) includes collective interests in numerous land contracts, as originally executed between the nonaffiliated party and the respective owners of the properties as defined in the contracts. These contracts provide for easement and access rights to the land that Sundance and Maverick were built upon. These interests as lessee in each of the land contracts were transferred to Sundance and Maverick (and subsequently to PSO and SWEPCo) as a part of the closing of the PSA. As of December 31, 2021, the Noncurrent Obligations Under Operating Leases for Sundance and Maverick were $15 million and $22 million, respectively, on the balance sheet for SWEPCo. IMPAIRMENTS 2020 Texas Base Rate Case In January 2022, the PUCT issued a final order adopting the PFD with certain modifications which included a return of investment only for the recovery of the Dolet Hills Power Station. As a result of the final order, SWEPCo recorded a disallowance of $12 million associated with the lack of return on the Dolet Hills Power Station. In February 2022, SWEPCo filed a motion for rehearing with the PUCT challenging the denial of reasonable return or carrying costs on the Dolet Hills Power Station. See “2020 Texas Base Rate Case” section of Note 4 for additional information. 8. BENEFIT PLANS For a discussion of investment strategy, investment limitations, target asset allocations and the classification of investments within the fair value hierarchy, see “Fair Value Measurements of Assets and Liabilities” and “Investments Held in Trust for Future Liabilities” sections of Note 1. SWEPCo participates in an AEP sponsored qualified pension plan and two unfunded nonqualified pension plans. Substantially all employees are covered by the qualified plan or both the qualified and a nonqualified pension plan. SWEPCo, also participates in OPEB plans sponsored by AEP to provide health and life insurance benefits for retired employees. SWEPCo recognizes the funded status associated with defined benefit pension and OPEB plans on the balance sheets. Disclosures about the plans are required by the “Compensation – Retirement Benefits” accounting guidance. SWEPCo recognizes an asset for a plan’s overfunded status or a liability for a plan’s underfunded status, and recognize, as a component of other comprehensive income, the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost. SWEPCo records a regulatory asset instead of other comprehensive income for qualifying benefit costs of regulated operations that for rate-making purposes are deferred for future recovery. The cumulative funded status adjustment is equal to the remaining unrecognized deferrals for unamortized actuarial losses or gains, prior service costs and transition obligations, such that remaining deferred costs result in an AOCI equity reduction or regulatory asset and deferred gains result in an AOCI equity addition or regulatory liability. Actuarial Assumptions for Benefit Obligations The weighted-average assumptions used in the measurement of benefit obligations are shown in the following table:
(a)Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees. NA Not applicable. A duration-based method is used to determine the discount rate for the plans. A hypothetical portfolio of high quality corporate bonds is constructed with cash flows matching the benefit plan liability. The composite yield on the hypothetical bond portfolio is used as the discount rate for the plan. For 2021, the rate of compensation increase assumed varies with the age of the employee, ranging from 3% per year to 11.5% per year, with the average increase shown in the table above. Actuarial Assumptions for Net Periodic Benefit Costs The weighted-average assumptions used in the measurement of benefit costs are shown in the following table:
(a)Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees. NA Not applicable. The expected return on plan assets was determined by evaluating historical returns, the current investment climate (yield on fixed income securities and other recent investment market indicators), rate of inflation, third-party forecasts and current prospects for economic growth. The health care trend rate assumptions used for OPEB plans measurement purposes are shown below:
Significant Concentrations of Risk within Plan Assets In addition to establishing the target asset allocation of plan assets, the investment policy also places restrictions on securities to limit significant concentrations within plan assets. The investment policy establishes guidelines that govern maximum market exposure, security restrictions, prohibited asset classes, prohibited types of transactions, minimum credit quality, average portfolio credit quality, portfolio duration and concentration limits. The guidelines were established to mitigate the risk of loss due to significant concentrations in any investment. Management monitors the plans to control security diversification and ensure compliance with the investment policy. As of December 31, 2021, the assets were invested in compliance with all investment limits. See “Investments Held in Trust for Future Liabilities” section of Note 1 for limit details. Benefit Plan Obligations, Plan Assets, Funded Status and Amounts Recognized on the Balance Sheets For the year ended December 31, 2021, the pension plans had an actuarial gain primarily due to an increase in the discount rate, partially offset by less favorable demographic experience than expected, resulting from the updated census information as of January 1, 2021. For the year ended December 31, 2021, the OPEB plans had an actuarial gain primarily due to an increase in the discount rate and an update of the projected reimbursements from the Employer Group Waiver Program under Medicare Part D. For the year ended December 31, 2020, the pension plans had an actuarial loss primarily due to a decrease in the discount rate, partially offset by a decrease in the assumed rate used to convert account balances to annuities. For the year ended December 31, 2020, the OPEB plans had an actuarial loss primarily due to a decrease in the discount rate and an update to the health care trend assumption, partially offset by updated projected per capita claims costs due to rate negotiations for Medicare advantage premium rates. The following tables provide a reconciliation of the changes in the plans’ benefit obligations, fair value of plan assets, funded status and the presentation on the balance sheets. The benefit obligation for the defined benefit pension and OPEB plans are the projected benefit obligation and the accumulated benefit obligation, respectively.
Amounts Included in Regulatory Assets, Deferred Income Taxes and AOCI The following tables show the components of the plans included in regulatory assets, Accumulated Deferred Income Taxes, AOCI and income tax expense and the items attributable to the change in these components:
Determination of Pension Expense The determination of pension expense or income is based on a market-related valuation of assets which reduces year-to-year volatility. This market-related valuation recognizes investment gains or losses over a five-year period from the year in which they occur. Investment gains or losses for this purpose are the difference between the expected return calculated using the market-related value of assets and the actual return. Pension and OPEB Assets The fair value tables within Pension and OPEB Assets present the classification of assets for AEP within the fair value hierarchy. All Level 1, 2, 3 and Other amounts can be allocated to SWEPCo using the percentages in the table below:
The following table presents the classification of pension plan assets for AEP within the fair value hierarchy as of December 31, 2021:
(a)Includes investment securities loaned to borrowers under the securities lending program. See the “Investments Held in Trust for Future Liabilities” section of Note 1 for additional information. (b)Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. (c)Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. The following table presents the classification of OPEB plan assets for AEP within the fair value hierarchy as of December 31, 2021:
(a)Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. (b)Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. The following table presents the classification of pension plan assets for AEP within the fair value hierarchy as of December 31, 2020:
(a)Includes investment securities loaned to borrowers under the securities lending program. See the “Investments Held in Trust for Future Liabilities” section of Note 1 for additional information. (b)Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. (c)Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. The following table presents the classification of OPEB plan assets for AEP within the fair value hierarchy as of December 31, 2020:
(a)Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. (b)Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. Accumulated Benefit Obligation The accumulated benefit obligation for the pension plans is as follows:
Obligations in Excess of Fair Values The tables below show the underfunded pension plans that had obligations in excess of plan assets. Projected Benefit Obligation
Accumulated Benefit Obligation
Estimated Future Benefit Payments and Contributions SWEPCo expects contributions and payments for the pension plans of $7 million during 2021. For the pension plans, this amount includes the payment of unfunded nonqualified benefits plus contributions to the qualified trust fund of at least the minimum amount required by the Employee Retirement Income Security Act. For the qualified pension plan, SWEPCo may also make additional discretionary contributions to maintain the funded status of the plan. The table below reflects the total benefits expected to be paid from the plan or from SWEPCo’s assets. The payments include the participants’ contributions to the plan for their share of the cost. Future benefit payments are dependent on the number of employees retiring, whether the retiring employees elect to receive pension benefits as annuities or as lump sum distributions, future integration of the benefit plans with changes to Medicare and other legislation, future levels of interest rates and variances in actuarial results. The estimated payments for the pension benefits and OPEB are as follows:
Components of Net Periodic Benefit Cost The following table provides the components of net periodic benefit cost (credit) for the plans:
American Electric Power System Retirement Savings Plan SWEPCo participates in an AEP sponsored defined contribution retirement savings plan, the American Electric Power System Retirement Savings Plan, for substantially all employees. This qualified plan offers participants an opportunity to contribute a portion of their pay, includes features under Section 401(k) of the Internal Revenue Code and provides for company matching contributions. The matching contributions to the plan are 100% of the first 1% of eligible employee contributions and 70% of the next 5% of contributions. The cost for matching contributions to the retirement savings plans for the years ended December 31, 2021 and 2020 were $6 million and $7 million, respectively. 9. BUSINESS SEGMENTS SWEPCo has one reportable segment, an electricity generation, transmission and distribution business. SWEPCo’s other activities are insignificant. 10. DERIVATIVES AND HEDGING OBJECTIVES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS AEPSC is agent for and transacts on behalf of SWEPCo. SWEPCo is exposed to certain market risks as major power producer and participant in the electricity, capacity, natural gas, coal and emission allowance markets. These risks include commodity price risks which may be subject to capacity risk, interest rate risk and credit risk. These risks represent the risk of loss that may impact SWEPCo due to changes in the underlying market prices or rates. Management utilizes derivative instruments to manage these risks. STRATEGIES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS TO ACHIEVE OBJECTIVES Risk Management Strategies The strategy surrounding the use of derivative instruments primarily focuses on managing risk exposures, future cash flows and creating value utilizing both economic and formal hedging strategies. The risk management strategies also include the use of derivative instruments for trading purposes which focus on seizing market opportunities to create value driven by expected changes in the market prices of the commodities. To accomplish these objectives, SWEPCo primarily employs risk management contracts including physical and financial forward purchase-and-sale contracts and, to a lesser extent, OTC swaps and options. Not all risk management contracts meet the definition of a derivative under the accounting guidance for “Derivatives and Hedging.” Derivative risk management contracts elected normal under the normal purchases and normal sales scope exception are not subject to the requirements of this accounting guidance. SWEPCo utilizes power, capacity, coal, natural gas, interest rate and, to a lesser extent, heating oil, gasoline and other commodity contracts to manage the risk associated with the energy business. SWEPCo utilizes interest rate derivative contracts in order to manage the interest rate exposure associated with the commodity portfolio. For disclosure purposes, such risks are grouped as “Commodity,” as these risks are related to energy risk management activities. SWEPCo also utilizes derivative contracts to manage interest rate risk associated with debt financing. For disclosure purposes, these risks are grouped as “Interest Rate.” The amount of risk taken is determined by the Commercial Operations, Energy Supply and Finance groups in accordance with established risk management policies as approved by the Finance Committee of the Board of Directors. The following table represents the gross notional volume of outstanding derivative contracts:
Cash Flow Hedging Strategies SWEPCo utilizes cash flow hedges on certain derivative transactions for the purchase-and-sale of power (“Commodity”) in order to manage the variable price risk related to forecasted purchases and sales. Management monitors the potential impacts of commodity price changes and, where appropriate, enters into derivative transactions to protect profit margins for a portion of future electricity sales and purchases. SWEPCo does not hedge all commodity price risk. SWEPCo utilizes a variety of interest rate derivative transactions in order to manage interest rate risk exposure. SWEPCo also utilizes interest rate derivative contracts to manage interest rate exposure related to future borrowings of fixed-rate debt. SWEPCo does not hedge all interest rate exposure. ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND THE IMPACT ON THE FINANCIAL STATEMENTS The accounting guidance for “Derivatives and Hedging” requires recognition of all qualifying derivative instruments as either assets or liabilities on the balance sheets at fair value. The fair values of derivative instruments accounted for using MTM accounting or hedge accounting are based on exchange prices and broker quotes. If a quoted market price is not available, the estimate of fair value is based on the best information available including valuation models that estimate future energy prices based on existing market and broker quotes and other assumptions. In order to determine the relevant fair values of the derivative instruments, SWEPCo applies valuation adjustments for discounting, liquidity and credit quality. Credit risk is the risk that a counterparty will fail to perform on the contract or fail to pay amounts due. Liquidity risk represents the risk that imperfections in the market will cause the price to vary from estimated fair value based upon prevailing market supply and demand conditions. Since energy markets are imperfect and volatile, there are inherent risks related to the underlying assumptions in models used to fair value risk management contracts. Unforeseen events may cause reasonable price curves to differ from actual price curves throughout a contract’s term and at the time a contract settles. Consequently, there could be significant adverse or favorable effects on future net income and cash flows if market prices are not consistent with management’s estimates of current market consensus for forward prices in the current period. This is particularly true for longer term contracts. Cash flows may vary based on market conditions, margin requirements and the timing of settlement of risk management contracts. According to the accounting guidance for “Derivatives and Hedging,” SWEPCo reflects the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, SWEPCo is required to post or receive cash collateral based on third-party contractual agreements and risk profiles. The netted cash collateral from third-parties against short-term and long-term risk management assets and netted cash collateral paid to third-parties against short-term and long-term risk management liabilities were immaterial as of December 31, 2021 and 2020.The following tables represent the gross fair value of SWEPCo’s derivative activity on the balance sheets:
(a)Derivative instruments within these categories are disclosed as gross. These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.” (b)Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.” (c)All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position. The table below presents the activity of derivative risk management contracts:
(a)Represents realized and unrealized gains and losses subject to regulatory accounting treatment. Certain qualifying derivative instruments have been designated as normal purchase or normal sale contracts, as provided in the accounting guidance for “Derivatives and Hedging.” Derivative contracts that have been designated as normal purchases or normal sales under that accounting guidance are not subject to MTM accounting treatment and are recognized on the statements of income on an accrual basis. The accounting for the changes in the fair value of a derivative instrument depends on whether it qualifies for and has been designated as part of a hedging relationship and further, on the type of hedging relationship. Depending on the exposure, management designates a hedging instrument as a fair value hedge or a cash flow hedge. For contracts that have not been designated as part of a hedging relationship, the accounting for changes in fair value depends on whether the derivative instrument is held for trading purposes. Unrealized and realized gains and losses on derivative instruments held for trading purposes are included in revenues on a net basis on the statements of income. Unrealized and realized gains and losses on derivative instruments not held for trading purposes are included in revenues or expenses on the statements of income depending on the relevant facts and circumstances. Certain derivatives that economically hedge future commodity risk are recorded in the same line item on the statements of income as that of the associated risk being hedged. However, unrealized and some realized gains and losses for both trading and non-trading derivative instruments are recorded as regulatory assets (for losses) or regulatory liabilities (for gains) in accordance with the accounting guidance for “Regulated Operations.” Accounting for Cash Flow Hedging Strategies For cash flow hedges (i.e. hedging the exposure to variability in expected future cash flows that is attributable to a particular risk), SWEPCo initially reports the gain or loss on the derivative instrument as a component of Accumulated Other Comprehensive Income on the balance sheets until the period the hedged item affects Net Income. Realized gains and losses on derivative contracts for the purchase and sale of power designated as cash flow hedges are included in Operating Revenues or Operation Expenses on the statements of income or in Other Regulatory Assets or Other Regulatory Liabilities on the balance sheets, depending on the specific nature of the risk being hedged. During the years ended 2021 and 2020, SWEPCo did not apply cash flow hedging to outstanding power derivatives. SWEPCo reclassifies gains and losses on interest rate derivative hedges related to debt financings from Accumulated Other Comprehensive Income on the balance sheets into Interest on Long-term Debt on the statements of income in those periods in which hedged interest payments occur. During the years ended 2021 and 2020, SWEPCo did not apply cash flow hedging to outstanding interest rate derivatives. For details on effective cash flow hedges included in Accumulated Other Comprehensive Income on the balance sheets and the reasons for changes in cash flow hedges, see Note 3 - Comprehensive Income. Cash flow hedges included in Accumulated Other Comprehensive Income on the balance sheets were: Impact of Cash Flow Hedges on the Balance Sheets
The actual amounts reclassified from Accumulated Other Comprehensive Income to Net Income can differ from the estimate above due to market price changes. Credit Risk Management mitigates credit risk in wholesale marketing and trading activities by assessing the creditworthiness of potential counterparties before entering into transactions with them and continuing to evaluate their creditworthiness on an ongoing basis. Management uses credit agency ratings and current market-based qualitative and quantitative data as well as financial statements to assess the financial health of counterparties on an ongoing basis. Master agreements are typically used to facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Collateral requirements in the form of cash, letters of credit, surety bonds and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. Some master agreements include margining, which requires a counterparty to post cash or letters of credit in the event exposure exceeds the established threshold. The threshold represents an unsecured credit limit which may be supported by a parental/affiliate guaranty, as determined in accordance with AEP’s credit policy. In addition, master agreements allow for termination and liquidation of all positions in the event of a default including a failure or inability to post collateral when required. Collateral Triggering Events Credit Downgrade Triggers A limited number of derivative contracts include collateral triggering events, which include a requirement to maintain certain credit ratings. On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these collateral triggering events in contracts. SWEPCo has not experienced a downgrade below a specified credit rating threshold that would require the posting of additional collateral. SWEPCo had no derivative contracts with collateral triggering events in a net liability position as of December 31, 2021 and 2020. Cross-Default Triggers In addition, a majority of SWEPCo’s non-exchange-traded commodity contracts contain cross-default provisions that, if triggered, would permit the counterparty to declare a default and require settlement of the outstanding payable. These cross-default provisions could be triggered if there was a non-performance event by Parent or the obligor under outstanding debt or a third-party obligation that is $50 million or greater. On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these cross-default provisions in the contracts. Amounts for SWEPCo were immaterial for years ended December 31, 2021 and 2020. 11. FAIR VALUE MEASUREMENTS Fair Value Measurements of Long-Term Debt The fair values of Long-Term Debt are based on quoted market prices, without credit enhancements, for the same or similar issues and the current interest rates offered for instruments with similar maturities classified as Level 2 measurement inputs. These instruments are not marked-to-market. The estimates presented are not necessarily indicative of the amounts that could be realized in a current market exchange. The book values and fair values of Long-Term Debt are summarized in the following table:
Fair Value Measurements of Financial Assets and Liabilities For a discussion of fair value accounting and the classification of assets and liabilities within the fair value hierarchy, see the “Fair Value Measurements of Assets and Liabilities” section of Note 1. The following tables set forth, by level within the fair value hierarchy, SWEPCo’s financial assets and liabilities that were accounted for at fair value on a recurring basis. As required by the accounting guidance for “Fair Value Measurements and Disclosures,” financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Management’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. There have not been any significant changes in management’s valuation techniques.
(a)Amounts in “Other” column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.” (b)Substantially comprised of power contracts. The following tables set forth a reconciliation of changes in the fair value of net trading derivatives classified as Level 3 in the fair value hierarchy:
(a)Included in revenues on the statements of income. (b)Represents the change in fair value between the beginning of the reporting period and the settlement of the risk management commodity contract. (c)Relates to the net gains (losses) of those contracts that are not reflected on the statements of income. These changes in fair value are recorded as regulatory liabilities for net gains and as regulatory assets for net losses or accounts payable. The following tables quantify the significant unobservable inputs used in developing the fair value of Level 3 positions:
(a)Represents market prices in dollars per MMBtu. (b)Represents market prices in dollars per MWh. (c)The weighted-average is the product of the forward market price of the underlying commodity and volume weighted by term. The following table provides the measurement uncertainty of fair value measurements to increases (decreases) in significant unobservable inputs related to Natural Gas Contracts and FTRs as of December 31, 2021 and 2020: Uncertainty of Fair Value Measurements
12. INCOME TAXES Income Tax Expense (Benefit) The details of SWEPCO’s Income Tax Expense (Benefit) as reported are as follows:
The following is a reconciliation between the federal income taxes computed by multiplying pretax income by the federal statutory tax rate and the income taxes reported:
Net Deferred Tax Asset The following table shows elements of SWEPCO’s net deferred tax asset and significant temporary differences:
Tax Credit Carryforward As of December 31, 2021, SWEPCO has federal tax credit carryforwards in the amount of $7.9 million. If these credits are not utilized, federal general business tax credits will expire in the years 2036 through 2041. SWEPCO anticipates future federal taxable income will be sufficient to realize the tax benefits of the federal tax credits before they expire unused. AEP System Tax Allocation Agreement SWEPCO 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 SWEPCO and other AEP subsidiaries originally filed federal return has expired for tax years 2016 and earlier. In the third quarter of 2019, SWEPCO and other AEP subsidiaries elected to amend the 2014 through 2017 federal returns. In the first quarter of 2020, the IRS notified SWEPCO 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 SWEPCO and other AEP subsidiaries claimed on the amended returns. SWEPCO 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. SWEPCO and other AEP subsidiaries file income tax returns in various state and local jurisdictions. These taxing authorities routinely examine the tax returns, and SWEPCO 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. Net Income Tax Operating Loss Carryforward SWEPCo has state net income tax operating loss carryforwards as of December 31, 2021 as indicated in the table below:
(a) NOL's generated beginning in 2001 can be carried forward indefinitely, effective January 1, 2022 Federal and State Tax Legislation IRS Notice 2021-41 was issued in June 2021 by the IRS providing further extension of the continuity safe harbor for PTC and ITC-eligible projects and revising the facts and circumstances rules. For PTC and ITC-eligible projects for which construction began in calendar years 2016 through 2019, the continuity safe harbor is extended to six years. Prior guidance (IRS Notice 2020-41) had only extended the safe harbor for projects beginning in 2016 and 2017 to 5 years. Furthermore, for PTC and ITC-eligible projects for which construction began in 2020, the continuity safe harbor is extended to five years. Under a facts and circumstances analysis, the continuity requirement may be satisfied under either the continuous construction test or the continuous efforts test, regardless of whether the physical work test or the five percent safe harbor is used. In May 2021, Oklahoma enacted HB 2960. HB 2960 reduces the Oklahoma corporate income tax rate from 6% to 4%. During 2021, AEP recorded an immaterial amount of Income Tax Benefit as a result of remeasuring Oklahoma deferred taxes at the lowered statutory tax rate of 4%. In December 2021, Arkansas enacted HB 1001. HB 1001 reduces the Arkansas corporate income tax rate from 5.9% to 5.7%, with additional reductions to 5.3% contingent upon future events. In the fourth quarter of 2021, AEP recorded an immaterial amount of Income Tax Expense as a result of remeasuring Arkansas deferred taxes at the lowered statutory tax rate of 5.7%. In November 2021, Louisiana approved Constitutional Amendment 2, thereby also enacting HB 292. HB 292 reduces the Louisiana corporate income tax rate from 8% to 7.5%. In the fourth quarter of 2021, AEP recorded an immaterial amount of Income Tax Expense as a result of remeasuring Louisiana deferred taxes at the lowered statutory tax rate of 7.5%. 13. LEASES SWEPCo leases property, plant and equipment including, but not limited to, fleet, information technology and real estate leases. These leases require payments of non-lease components, including related property taxes, operating and maintenance costs. SWEPCo does not separate non-lease components from associated lease components. Many of these leases have purchase or renewal options. Leases not renewed are often replaced by other leases. Options to renew or purchase a lease are included in the measurement of lease assets and liabilities if it is reasonably certain SWEPCo will exercise the option. Lease obligations are measured using the discount rate implicit in the lease when that rate is readily determinable. AEP has visibility into the rate implicit in the lease when assets are leased from selected financial institutions under master leasing agreements. When the implicit rate is not readily determinable, SWEPCo measures its lease obligation using its estimated secured incremental borrowing rate. Incremental borrowing rates are comprised of an underlying risk-free rate and a secured credit spread relative to the lessee on a matched maturity basis. Operating and Finance lease rental costs are generally charged to Operation Expense and Maintenance Expense in accordance with rate-making treatment for regulated operations. Lease costs associated with capital projects are included in Utility Plant on the balance sheets. For regulated operations with finance leases, a finance lease asset and offsetting liability are recorded at the present value of the remaining lease payments for each reporting period. The components of rental costs were as follows:
(a)Excludes variable and short-term lease costs, which were immaterial. Supplemental information related to leases are shown in the tables below:
The following tables show property, plant and equipment under finance leases, operating leases and related obligations recorded on SWEPCo’s balance sheets:
(a) Includes $28 million and $26 million of accumulated provision for depreciation and amortization for the years ended December 31, 2021 and 2020, respectively.
(a) Includes $20 million and $17 million of accumulated provision for depreciation and amortization for the years ended December 31, 2021 and 2020, respectively. Future minimum lease payments consisted of the following as of December 31, 2021:
Master Lease Agreements SWEPCo leases certain equipment under master lease agreements. Under the lease agreements, the lessor is guaranteed a residual value up to a stated percentage of the equipment cost at the end of the lease term. If the actual fair value of the leased equipment is below the guaranteed residual value at the end of the lease term, SWEPCo is committed to pay the difference between the actual fair value and the residual value guarantee. Historically, at the end of the lease term the fair value has been in excess of the amount guaranteed. As of December 31, 2021, the maximum potential loss by SWEPCo for these lease agreements assuming the fair value of the equipment is zero at the end of the lease term was $5 million. Lessor Activity SWEPCo’s lessor activity was immaterial as of and for the twelve months ended December 31, 2021 and December 31, 2020, respectively. 14. FINANCING ACTIVITIES Long-term Debt The following table details long-term debt outstanding:
As of December 31, 2021, long-term debt was payable as follows:
Dividend Restrictions SWEPCo pays dividends to Parent provided funds are legally available. Various financing arrangements and regulatory requirements may impose certain restrictions on the ability of SWEPCo to transfer funds to Parent in the form of dividends. All of the dividends declared by SWEPCo 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. SWEPCo has credit agreements that contain covenants that limit their debt to capitalization ratio to 67.5%. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. The most restrictive dividend limitation for SWEPCo is through the credit agreements. As of December 31, 2021, the maximum amount of restricted net assets of SWEPCo that may not be distributed to the Parent in the form of a loan, advance or dividend was $1.7 billion. The credit agreement covenant restrictions can limit the ability of SWEPCo to pay dividends out of retained earnings. As of December 31, 2021, the amount of any such restrictions was $578 million. Corporate Borrowing Program – AEP System The AEP System uses a corporate borrowing program to meet the short-term borrowing needs of AEP’s subsidiaries. The corporate borrowing program includes a Utility Money Pool, which funds AEP’s utility subsidiaries. The AEP System Utility Money Pool operates in accordance with the terms and conditions of its agreement filed with the FERC. The amounts of outstanding loans to (borrowings from) the Utility Money Pool as of December 31, 2021 and 2020 are included in Notes Receivable from Associated Companies and Notes Payable to Associated Companies, respectively, on the balance sheets. SWEPCo’s money pool activity and corresponding authorized borrowing limits are described in the following table:
The maximum, minimum and average interest rates for funds either borrowed from or loaned to the Utility Money Pool are summarized in the following table:
Interest expense and interest income related to the Utility Money Pool financing relationship are included in Interest on Debt to Associated Companies and Interest and Dividend Income, respectively, on the statements of income. The interest expense and interest income related to the corporate borrowing programs were immaterial for the years ended December 31, 2021 and 2020. Securitized Accounts Receivables – AEP Credit Under this sale of receivables arrangement, SWEPCo sells, without recourse, certain of its customer accounts receivable and accrued utility revenue balances to AEP Credit and is charged a fee based on AEP Credit’s financing costs, administrative costs and uncollectible accounts experience for SWEPCo’s receivables. The costs of customer accounts receivable sold are reported in Other Deductions on SWEPCo’s statements of income. SWEPCo manages and services its customer accounts receivable, which are sold to AEP Credit. AEP Credit securitizes the eligible receivables for SWEPCo and retains the remainder. AEP Credit has a receivables securitization agreement that provides a commitment of $750 million from bank conduits to purchase receivables and was amended in September 2021 to include a $125 million and a $625 million facility, which expire in September 2023 and 2024, respectively. The amount of accounts receivable and accrued utility revenues under the sale of receivables agreement as of December 31, 2021 and 2020 were $153 million and $159 million, respectively. The fees paid to AEP Credit for customer accounts receivable sold were $5 million and $7 million for the years ended December 31, 2021 and 2020, respectively. In 2020, an increase in allowance for doubtful accounts was recognized in response to the anticipated impact of COVID-19 on the collectability of accounts receivable, which caused an increase in fees paid by SWEPCo. In 2021, due to higher than expected collections of accounts receivables, allowance for doubtful accounts was adjusted resulting in the issuance of credits to offset the higher fees previously paid and to lower subsequent fees paid. The proceeds on the sale of receivables to AEP Credit were $1.6 billion and $1.6 billion for the years ended December 31, 2021 and 2020, respectively. 15. RELATED PARTY TRANSACTIONS For other related party transactions, also see “AEP System Tax Allocation Agreement” section of Note 12 in addition to “Corporate Borrowing Program – AEP System” and “Securitized Accounts Receivables – AEP Credit” sections of Note 14. Operating Agreement AEPSC conducts power, capacity, coal, natural gas, interest rate and, to a lesser extent, heating oil, gasoline and other risk management activities on behalf of APCo, I&M, KPCo, PSO, SWEPCo and WPCo. Certain power and natural gas risk management activities for APCo, I&M, KPCo and WPCo are allocated based on the four member companies’ respective equity positions, while power and natural gas risk management activities for PSO and SWEPCo are allocated based on the Operating Agreement. System Integration Agreement Under the SIA, AEPSC allocates physical and financial revenues and expenses from transactions with neighboring utilities, power marketers and other power and natural gas risk management activities based upon the location of such activity. Margins resulting from trading and marketing activities originating in PJM generally accrue to the benefit of APCo, I&M, KPCo and WPCo, while trading and marketing activities originating in SPP generally accrue to the benefit of PSO and SWEPCo. Margins resulting from other transactions are allocated among APCo, I&M, KPCo, PSO, SWEPCo and WPCo based upon the equity positions of these companies. Affiliated Revenues and Purchases The following table shows the revenues derived from direct sales to affiliates, auction sales to affiliates, net transmission agreement sales and other revenues for the years ended December 31, 2021 and 2020:
SPP Transmission Service Charges PSO, SWEPCo and AEPSC are parties to the TCA in connection with the operation of the transmission assets of PSO and SWEPCo. The TCA has been approved by the FERC and establishes a coordinating committee, which is charged with overseeing the coordinated planning of the transmission facilities of the parties to the agreement. This includes the performance of transmission planning studies, the interaction of such companies with independent system operators and other regional bodies interested in transmission planning and compliance with the terms of the OATT filed with the FERC and the rules of the FERC relating to such a tariff. Under the TCA, the parties to the agreement delegated to AEPSC the responsibility of monitoring the reliability of their transmission systems and administering the OATT on their behalf. The allocations have been governed by the FERC-approved OATT for the SPP. Additional costs for transmission services provided by AEPTCo and other transmission affiliates are billed to PSO and SWEPCo through the SPP OATT. SWEPCo’s net expenses allocated among parties to the TCA pursuant to the SPP OATT protocols were $56 million and $31 million for the years ended December 31, 2021 and 2020, respectively. The net expenses were recorded in Operation Expenses on the statements of income. Cook Coal Terminal Cook Coal Terminal also performs railcar maintenance services at cost for SWEPCo. AEGCo billed SWEPCo $3 million and $3 million for the years ended December 31, 2021 and 2020, respectively, for railcar maintenance services. SWEPCo recorded the cost of the railcar maintenance services in Fuel Stock on the balance sheets. Central Machine Shop APCo operates a facility which repairs and rebuilds specialized components for the generation plants across the AEP System. SWEPCo recorded billings from APCo of $3 million and $460 thousand as capital or maintenance expenses depending on the nature of the services received for the years ended December 31, 2021 and 2020, respectively. These billings are recoverable from customers. Sales and Purchases of Property SWEPCo had affiliated sales and purchases of electric property amounting to $100 thousand or more, sales and purchases of meters and transformers, and sales and purchases of transmission property. There were no gains or losses recorded on the transactions. The following table shows the sales and purchases, recorded at net book value:
The amounts above are recorded in Utility Plant on the balance sheets. Sempra Renewables LLC PPAs In April 2019, AEP acquired Sempra Renewables LLC and its ownership interests in 724 MWs of wind generation. The operating wind generation portfolio includes seven wind farms. Prior to the acquisition, one wind farm had an existing PPA with SWEPCo. A joint venture wind farm has a PPA with SWEPCo for a portion of its energy production which totaled $14 million and $14 million of purchased electricity for the years ended December 31, 2021 and 2020, respectively. Intercompany Billings SWEPCo and other AEP subsidiaries perform certain utility services for each other when necessary or practical. The costs of these services are billed on a direct-charge basis, whenever possible, or on reasonable basis of proration for services that benefit multiple companies. The billings for services are made at cost and include no compensation for the use of equity capital. AEPSC AEPSC provides certain managerial and professional services to SWEPCo. The costs of the services are based on a direct charge or on a prorated basis and billed to SWEPCo at AEPSC’s cost. AEPSC and its billings are subject to regulation by the FERC. SWEPCo’s total billings from AEPSC were $169 million and $162 million for the years ended December 31, 2021 and 2020, respectively. Charitable Contributions to AEP Foundation The American Electric Power Foundation is funded by American Electric Power and its utility operating units. The Foundation provides a permanent, ongoing resource for charitable initiatives and multi-year commitments in the communities served by AEP and initiatives outside of AEP’s 11-state service area. Charitable contributions to the AEP Foundation were recorded in Donations on the statements of income. In 2021 and 2020, there were no charitable contributions made to the AEP Foundation. 16. PROPERTY, PLANT AND EQUIPMENT Depreciation SWEPCo provides for depreciation of Utility Plant, on a straight-line basis over the estimated useful lives of property, generally using composite rates by functional class. The following table provides total regulated annual composite depreciation rates by functional class:
The composite depreciation rate generally includes a component for non-ARO removal costs, which is credited to accumulated depreciation on the balance sheets. Actual removal costs incurred are charged to accumulated depreciation. Asset Retirement Obligations SWEPCo records ARO in accordance with the accounting guidance for “Asset Retirement and Environmental Obligations” for legal obligations for asbestos removal and for the retirement of certain ash disposal facilities, wind farms and certain coal-mining facilities. SWEPCo has identified, but not recognized, ARO liabilities related to electric transmission and distribution assets as a result of certain easements on property on which assets are owned. Generally, such easements are perpetual and require only the retirement and removal of assets upon the cessation of the property’s use. The retirement obligation is not estimable for such easements since SWEPCo plans to use its facilities indefinitely. The retirement obligation would only be recognized if and when SWEPCo abandons or ceases the use of specific easements, which is not expected. In 2020, SWEPCo recorded a revision to increase estimated ARO liabilities by $21 million primarily due to the revision in the useful life of DHLC. See Note 5 - Effects of Regulation for additional information. Also in 2020, SWEPCo recorded an $18 million revision due to a reduction in estimated ash pond closure costs. The following is a reconciliation of the 2021 and 2020 aggregate carrying amounts of ARO:
(a)Includes ARO related to ash disposal facilities. (b)Includes ARO related to DHLC. (c)Includes ARO related to asbestos removal. Jointly-owned Electric Facilities SWEPCo has electric facilities that are jointly-owned with affiliated and nonaffiliated companies. Using its own financing, SWEPCo is obligated to pay its share of the costs of these jointly-owned facilities in the same proportion as its ownership interest. SWEPCo’s proportionate share of the operating costs associated with these facilities is included in its statements of income and the investments and accumulated depreciation are reflected in its balance sheets under Utility Plant as follows:
(a)Operated by CLECO, a nonaffiliated company. The Dolet Hills Power Station was retired in December 2021. (b)Operated by SWEPCo. (c)PSO and SWEPCo own undivided interests of 45.5% and 54.5% of the NCWF, respectively. Sundance was placed into service in April 2021. Maverick was placed into service in September 2021. See the “Acquisitions” section of Note 7 for additional information. (d)Operated by PSO. 17. REVENUE FROM CONTRACTS WITH CUSTOMERS Disaggregated Revenues from Contracts with Customers The tables below represent revenues from contracts with customers, net of respective provisions for refund, by type of revenue for SWEPCo:
(a)Amounts include affiliated and nonaffiliated revenues. Performance Obligations SWEPCo 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. SWEPCo 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 SWEPCo are summarized as follows: Retail Revenues SWEPCo has performance obligations to generate, transmit and distribute electricity for sale to rate-regulated retail customers. The performance obligation to deliver electricity is satisfied over time as the customer simultaneously receives and consumes the benefits provided. Revenues are variable as they are subject to the customer’s usage requirements. Rate-regulated retail customers typically have the right to discontinue receiving service at will, therefore these contracts between SWEPCo and their customers for rate-regulated services are generally limited to the services requested and received to date for such arrangements. Retail customers are generally billed on a monthly basis, and payment is typically due within 15 to 20 days after the issuance of the invoice. Wholesale Revenues - Generation SWEPCo has performance obligations to sell electricity to wholesale customers from generation assets in SPP. The performance obligation to deliver electricity from generation assets is satisfied over time as the customer simultaneously receives and consumes the benefits provided. Wholesale generation revenues are variable as they are subject to the customer’s usage requirements. Payments from the RTO for stand ready services are typically received within one week from the issuance of the invoice, which is typically issued weekly. Gross margin resulting from generation sales are primarily subject to margin sharing agreements with customers and vary by state, where the revenues are reflected gross in the disaggregated revenues table above. Wholesale Revenues - Transmission SWEPCo has performance obligations to transmit electricity to wholesale customers through assets owned and operated. The performance obligation to provide transmission services in SPP encompasses a time frame greater than a year, where the performance obligation within each RTO is partially fixed for a period of one year or less. Payments from the RTO for transmission services are typically received within one week from the issuance of the invoice, which is issued monthly for SPP. SWEPCo collects revenues through transmission formula rates. The FERC-approved rates establish the annual transmission revenue requirement (ATRR) and transmission service rates for transmission owners. The formula rates establish rates for a one year period and also include a true-up calculation for the prior year’s billings, allowing for over/under-recovery of the transmission owner’s ATRR. The annual true-ups meet the definition of alternative revenues in accordance with the accounting guidance for “Regulated Operations,” and are therefore presented as such in the disaggregated revenues table above. PSO, SWEPCo and AEPSC are parties to the TCA by and among PSO, SWEPCo and AEPSC, in connection with the operation of the transmission assets of the two AEP utility subsidiaries. Affiliate revenues as a result of the TCA are reflected as Transmission Revenues in the disaggregated revenues table above. Fixed Performance Obligations The following table represents the remaining fixed performance obligations satisfied over time as of December 31, 2021. Fixed performance obligations primarily include wholesale transmission services, electricity sales for fixed amounts of energy. The amounts shown in the table below include affiliated and nonaffiliated revenues.
Contract Assets and Liabilities Contract assets are recognized when SWEPCo 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. SWEPCo did not have any material contract assets as of December 31, 2021 and 2020. When SWEPCo 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. SWEPCo’s contract liabilities typically arise from services provided under joint use agreements for utility poles. SWEPCo 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 SWEPCo’s balance sheets within the Customer Accounts Receivable line item. SWEPCo’s balances for receivables from contracts that are not recognized in accordance with the accounting guidance for “Revenue from Contracts with Customers” included in Customer Accounts Receivable were not material as of December 31, 2021 and 2020. See “Securitized Accounts Receivable - AEP Credit” section of Note 14 for additional information. The amount of affiliated accounts receivable from contracts with customers included in Accounts Receivable from Associated Companies on SWEPCo’s balance sheets were $25 million and $11 million, as of December 31, 2021 and 2020. Contract Costs Contract costs to obtain or fulfill a contract for SWEPCo are accounted for under the guidance for “Other Assets and Deferred Costs” and presented as a single asset and are neither bifurcated nor reclassified between current assets and deferred debits on the balance sheets. Contract costs to acquire a contract are amortized in a manner consistent with the transfer of goods or services to the customer in Operation Expenses on the income statements. SWEPCo did not have material contract costs as of December 31, 2021 and 2020. |
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Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
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Year/Period of Report End of: |
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STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES |
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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) |
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This report is: (1) ☐ An Original (2) ☑ A Resubmission |
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SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION |
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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. |
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Total Company For the Current Year/Quarter Ended (b) |
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Other (Specify) (e) |
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Other (Specify) (g) |
Common (h) |
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UtilityPlantAbstract UTILITY PLANT |
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UtilityPlantInServiceAbstract In Service |
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UtilityPlantInServiceClassified Plant in Service (Classified) |
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UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases |
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UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold |
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UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified |
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UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified |
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UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7) |
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UtilityPlantLeasedToOthers Leased to Others |
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UtilityPlantHeldForFutureUse Held for Future Use |
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ConstructionWorkInProgress Construction Work in Progress |
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UtilityPlantAcquisitionAdjustment Acquisition Adjustments |
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UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12) |
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AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion |
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UtilityPlantNet Net Utility Plant (13 less 14) |
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DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION |
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AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service: |
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DepreciationUtilityPlantInService Depreciation |
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AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService Amortization and Depletion of Producing Natural Gas Land and Land Rights |
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AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService Amortization of Underground Storage Land and Land Rights |
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AmortizationOfOtherUtilityPlantUtilityPlantInService Amortization of Other Utility Plant |
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DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21) |
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DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract Leased to Others |
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DepreciationUtilityPlantLeasedToOthers Depreciation |
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AmortizationAndDepletionUtilityPlantLeasedToOthers Amortization and Depletion |
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DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers Total Leased to Others (24 & 25) |
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DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract Held for Future Use |
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DepreciationUtilityPlantHeldForFutureUse Depreciation |
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AmortizationUtilityPlantHeldForFutureUse Amortization |
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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) |
|
|
|||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157) |
||||||
|
||||||
| 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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106) |
|||||||
|
|||||||
| 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 |
|
|
|
|
||
|
5 |
TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4) |
|
|
|
|
||
|
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 |
|
|
|
|
||
|
48.1 |
(351) Energy Storage Equipment - Transmission |
||||||
|
49 |
(352) Structures and Improvements |
|
|
|
|
||
|
50 |
(353) Station Equipment |
|
|
|
|
||
|
51 |
(354) Towers and Fixtures |
|
|
|
|
||
|
52 |
(355) Poles and Fixtures |
|
|
|
|
||
|
53 |
(356) Overhead Conductors and Devices |
|
|
|
|
||
|
54 |
(357) Underground Conduit |
|
|
|
|
||
|
55 |
(358) Underground Conductors and Devices |
|
|
|
|||
|
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) |
|
|
|
|
||
|
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 |
|
|
|
|||
|
87 |
(390) Structures and Improvements |
|
|
|
|
||
|
88 |
(391) Office Furniture and Equipment |
|
|
|
|
||
|
89 |
(392) Transportation Equipment |
|
|
|
|||
|
90 |
(393) Stores Equipment |
|
|
|
|
||
|
91 |
(394) Tools, Shop and Garage Equipment |
|
|
|
|
||
|
92 |
(395) Laboratory Equipment |
|
|
|
|||
|
93 |
(396) Power Operated Equipment |
|
|
||||
|
94 |
(397) Communication Equipment |
|
|
|
|
||
|
95 |
(398) Miscellaneous Equipment |
|
|
|
|
||
|
96 |
SUBTOTAL (Enter Total of lines 86 thru 95) |
|
|
|
|
||
|
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) |
|
|
|
|
||
|
100 |
TOTAL (Accounts 101 and 106) |
|
|
|
|
|
|
|
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) |
|
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ELECTRIC PLANT HELD FOR FUTURE USE (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 |
|
|
|||||||
| 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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107) |
||
|
||
| Line No. |
ConstructionWorkInProgressProjectDescription Description of Project (a) |
ConstructionWorkInProgress Construction work in progress - Electric (Account 107) (b) |
| 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 | ||
| 50 | ||
| 43 | Total |
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108) |
|||||
|
|||||
| Line No. |
Item (a) |
Total (c + d + e) (b) |
Electric Plant in Service (c) |
Electric Plant Held for Future Use (d) |
Electric Plant Leased To Others (e) |
| Section A. Balances and Changes During Year | |||||
| 1 |
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance Beginning of Year |
|
|
||
| 2 |
Depreciation Provisions for Year, Charged to |
||||
|
3 |
DepreciationExpenseExcludingAdjustments (403) Depreciation Expense |
|
|
||
|
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 | (a) |
||||
| 10 |
DepreciationProvision
TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9) |
|
|
||
| 11 |
Net Charges for Plant Retired: |
||||
|
12 |
BookCostOfRetiredPlant Book Cost of Plant Retired |
|
|
||
|
13 |
CostOfRemovalOfPlant Cost of Removal |
|
(b) |
||
|
14 |
SalvageValueOfRetiredPlant Salvage (Credit) |
|
(c) |
||
|
15 |
NetChargesForRetiredPlant TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14) |
|
|
||
| 16 |
OtherAdjustmentsToAccumulatedDepreciation
Other Debit or Cr. Items (Describe, details in footnote): |
||||
| 17.1 | (d) |
||||
| 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) |
|
|
||
| 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 |
|
|
||
|
26 |
AccumulatedDepreciationDistribution Distribution |
|
|
||
|
27 |
AccumulatedDepreciationRegionalTransmissionAndMarketOperation Regional Transmission and Market Operation |
||||
|
28 |
AccumulatedDepreciationGeneral General |
|
|
||
| 29 |
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
TOTAL (Enter Total of lines 20 thru 28) |
|
|
||
| FOOTNOTE DATA |
| (a) Concept: OtherAccounts | ||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: CostOfRemovalOfPlant | ||||||||||||||||||||||||||||||||||||||||||||||||
Includes $14,811,416 of removal cost in retirement work in progress (RWIP).
| ||||||||||||||||||||||||||||||||||||||||||||||||
| (c) Concept: SalvageValueOfRetiredPlant | ||||||||||||||||||||||||||||||||||||||||||||||||
Includes ($4,602,816) of salvage in retirement work in progress (RWIP).
| ||||||||||||||||||||||||||||||||||||||||||||||||
| (d) Concept: OtherAdjustmentsToAccumulatedDepreciation | ||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
INVESTMENTS IN SUBSIDIARY COMPANIES (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 | ||||||||
| 42 |
Total Cost of Account 123.1 $ |
Total |
|
|
|
|
||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
MATERIALS AND SUPPLIES |
||||
|
||||
| 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) |
|
|
|
| 6 |
Assigned to - Operations and Maintenance |
|||
| 7 |
Production Plant (Estimated) |
|
|
|
| 8 |
Transmission Plant (Estimated) |
|
|
|
| 9 |
Distribution Plant (Estimated) |
|
|
|
| 10 |
Regional Transmission and Market Operation Plant (Estimated) |
|||
| 11 |
Assigned to - Other (provide details in footnote) |
|
(a) |
|
| 12 |
TOTAL Account 154 (Enter Total of lines 5 thru 11) |
|
|
|
| 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 |
|
|
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: PlantMaterialsAndOperatingSuppliesOther |
Assigned to - Other: Includes Customer Accounts and Administrative and General
Expenses (applies to both beginning and ending balances).
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Allowances (Accounts 158.1 and 158.2) |
|||||||||||||
|
|||||||||||||
| 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 |
|||||||||||||
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 |
|||||||||||||
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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Allowances (Accounts 158.1 and 158.2) |
|||||||||||||
|
|||||||||||||
| 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 |
|||||||||||||
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 |
|||||||||||||
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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Transmission Service and Generation Interconnection Study Costs |
|||||
|
|||||
| 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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
OTHER REGULATORY ASSETS (Account 182.3) |
||||||
|
||||||
| 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 | ||||||
| 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 | ||||||
| 44 |
TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
MISCELLANEOUS DEFFERED DEBITS (Account 186) |
||||||
|
||||||
| 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 |
|
|
|
|
|
|
| 2 |
|
|
|
(a) |
|
|
| 3 |
|
|
|
|
|
|
| 4 |
|
|
|
|
|
|
| 5 |
|
|
|
(b) |
|
|
| 6 |
|
|
|
|
|
|
| 7 |
|
|
|
(c) |
|
|
| 8 |
|
|
|
|
|
|
| 9 |
|
|
|
|
|
|
| 10 |
|
|
|
(d) |
|
|
| 11 |
|
|
|
|
|
|
| 47 |
Miscellaneous Work in Progress |
|||||
| 48 |
Deferred Regulatroy Comm. Expenses (See pages 350 - 351) |
|||||
| 49 |
TOTAL |
|
|
|||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged | ||||||
| ||||||
| (b) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged | ||||||
| ||||||
| (c) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged | ||||||
| ||||||
| (d) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged | ||||||
| ||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED DEFERRED INCOME TAXES (Account 190) |
|||
|
|||
| Line No. |
DescriptionOfAccumulatedDeferredIncomeTax Description and Location (a) |
AccumulatedDeferredIncomeTaxes Balance at Beginning of Year (b) |
AccumulatedDeferredIncomeTaxes Balance at End of Year (c) |
| 1 |
Electric |
||
| 2 |
|
|
|
| 3 |
|
|
|
| 4 |
|
|
|
| 5 |
|
|
|
| 6 |
|
|
|
| 7 |
Other |
|
|
| 8 |
TOTAL Electric (Enter Total of lines 2 thru 7) |
|
|
| 9 |
Gas |
||
| 15 |
Other |
||
| 16 |
TOTAL Gas (Enter Total of lines 10 thru 15) |
||
|
17.1 |
|
|
|
| 17 |
Other (Specify) |
||
| 18 |
TOTAL (Acct 190) (Total of lines 8, 16 and 17) |
(a) |
|
| Notes |
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: AccumulatedDeferredIncomeTaxes | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Formula Rate uses 13 month average.
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
CAPITAL STOCKS (Account 201 and 204) |
||||||||||
|
||||||||||
| 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 |
|
|
|
|
|
|||||
|
7 |
Total |
|
|
|
||||||
|
8 |
Preferred Stock (Account 204) |
|||||||||
| 9 | ||||||||||
| 10 | ||||||||||
| 11 | ||||||||||
|
12 |
Total |
|||||||||
| 1 |
Capital Stock (Accounts 201 and 204) - Data Conversion |
|||||||||
| 2 | ||||||||||
| 3 | ||||||||||
| 4 | ||||||||||
|
5 |
Total |
|||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
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.
|
||||||||||||
| Line No. |
Item (a) |
Amount (b) |
||||||||||
|
1 |
DonationsReceivedFromStockholdersAbstract Donations Received from Stockholders (Account 208) |
|||||||||||
|
2 |
DonationsReceivedFromStockholders Beginning Balance Amount |
|||||||||||
|
3.1 |
IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders |
|
||||||||||
|
4 |
DonationsReceivedFromStockholders Ending Balance Amount |
|
||||||||||
|
5 |
ReductionInParOrStatedValueOfCapitalStockAbstract Reduction in Par or Stated Value of Capital Stock (Account 209) |
|||||||||||
|
6 |
ReductionInParOrStatedValueOfCapitalStock Beginning Balance Amount |
|||||||||||
|
7.1 |
IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock |
|||||||||||
|
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 |
|||||||||||
|
12 |
GainOnResaleOrCancellationOfReacquiredCapitalStock Ending Balance Amount |
|
||||||||||
|
13 |
MiscellaneousPaidInCapitalAbstract Miscellaneous Paid-In Capital (Account 211) |
|||||||||||
|
14 |
MiscellaneousPaidInCapital Beginning Balance Amount |
|
||||||||||
|
15.1 |
IncreasesDecreasesDueToMiscellaneousPaidInCapital (a) |
|||||||||||
|
16 |
MiscellaneousPaidInCapital Ending Balance Amount |
|
||||||||||
|
17 |
OtherPaidInCapitalAbstract Historical Data - Other Paid in Capital |
|||||||||||
|
18 |
OtherPaidInCapitalDetail Beginning Balance Amount |
|||||||||||
|
19.1 |
IncreasesDecreasesInOtherPaidInCapital |
|||||||||||
|
20 |
OtherPaidInCapitalDetail Ending Balance Amount |
|||||||||||
|
40 |
OtherPaidInCapital Total |
|
||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: OtherPaidInCapitalDescription |
Effective August 31, 2020, SWEPCo completed a reverse stock split, with each 2,048 shares of Common Stock
issued and outstanding being combined into one share. Par value remains $18/share.
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
CAPITAL STOCK EXPENSE (Account 214) |
||
|
||
| 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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
LONG-TERM DEBT (Account 221, 222, 223 and 224) |
|||||||||||||
|
|||||||||||||
| 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 | |||||||||||||
| 13 | |||||||||||||
| 14 | |||||||||||||
|
15 |
Subtotal | ||||||||||||
16 |
Other Long Term Debt (Account 224) |
||||||||||||
| 17 | |||||||||||||
| 18 | |||||||||||||
| 19 | |||||||||||||
| 20 | |||||||||||||
| 21 | |||||||||||||
| 22 | |||||||||||||
| 23 | |||||||||||||
| 24 | |||||||||||||
| 25 | |||||||||||||
| 26 | |||||||||||||
|
27 |
Subtotal |
|
|||||||||||
| 33 | TOTAL |
|
|
|
|||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES |
||
|
||
| Line No. |
Particulars (Details) (a) |
Amount (b) |
| 1 |
Net Income for the Year (Page 117) |
|
| 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 |
(a) |
| 28 |
Show Computation of Tax: |
|
| 29 | ||
| 30 | ||
| 31 | ||
| 32 | ||
| 33 | ||
| 34 | ||
| 35 | ||
| 36 | ||
| 37 | ||
| 38 | ||
| 39 | ||
| 40 | ||
| 41 | ||
| 42 | ||
| 43 | ||
| 44 | ||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: FederalTaxNetIncome | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
a) Represents the allocation of estimated current year net operating tax income of American Electric Power Company, Inc.
(b) The Company joins in the filing of a consolidated Federal income tax return with its affiliated companies in the AEP system. The allocation of the AEP System's consolidated Federal income tax to the System companies allocates the benefit of the current tax incomes to the System companies giving rise to them in determining their current tax expense. The tax loss of the System parent company, American Electric Power Company, Inc.is allocated to its subsidiaries with taxable income. With exception of the loss of the parent company, the method of allocation approximates a separate return result for each company in the consolidating group
Instruction 2.
* The tax computation above represents an estimate of the Company's allocated portion of the System consolidated Federal Income Tax. The computation of actual 2021 System Federal income taxes will not be available until the consolidated Federal Income tax return is filed by October 2022.The actual allocation of the System consolidated Federal income tax to the members of the consolidated group will not be available until after the Consolidated Federal Income Tax Return is filed.
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR |
|||||||||||||||
|
|||||||||||||||
| 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 | |||||||||||||||
| 2 | Subtotal Federal Tax |
||||||||||||||
| 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 | Subtotal State Tax |
||||||||||||||
| 36 | |||||||||||||||
| 37 | |||||||||||||||
| 38 | |||||||||||||||
| 39 | |||||||||||||||
| 40 | |||||||||||||||
| 41 | |||||||||||||||
| 42 | Subtotal Local Tax |
||||||||||||||
| 43 | |||||||||||||||
| 44 | |||||||||||||||
| 45 | |||||||||||||||
| 46 | |||||||||||||||
| 47 | |||||||||||||||
| 48 | |||||||||||||||
| 49 | |||||||||||||||
| 50 | |||||||||||||||
| 51 | |||||||||||||||
| 52 | |||||||||||||||
| 53 | |||||||||||||||
| 54 | |||||||||||||||
| 55 | |||||||||||||||
| 56 | |||||||||||||||
| 57 | |||||||||||||||
| 58 | |||||||||||||||
| 59 | Subtotal Property Tax |
||||||||||||||
| 60 | |||||||||||||||
| 61 | |||||||||||||||
| 62 | |||||||||||||||
| 63 | |||||||||||||||
| 64 | |||||||||||||||
| 65 | |||||||||||||||
| 66 | Subtotal Unemployment Tax |
||||||||||||||
| 67 | |||||||||||||||
| 68 | |||||||||||||||
| 69 | |||||||||||||||
| 70 | |||||||||||||||
| 71 | |||||||||||||||
| 72 | |||||||||||||||
| 73 | |||||||||||||||
| 74 | |||||||||||||||
| 75 | |||||||||||||||
| 76 | |||||||||||||||
| 77 | |||||||||||||||
| 78 | |||||||||||||||
| 79 | |||||||||||||||
| 80 | Subtotal Sales And Use Tax |
||||||||||||||
| 81 | |||||||||||||||
| 82 | Subtotal Excise Tax |
||||||||||||||
| 83 | |||||||||||||||
| 84 | |||||||||||||||
| 85 | |||||||||||||||
| 86 | Subtotal Federal Insurance Tax |
||||||||||||||
| 87 | |||||||||||||||
| 88 | |||||||||||||||
| 89 | |||||||||||||||
| 90 | |||||||||||||||
| 91 | |||||||||||||||
| 92 | |||||||||||||||
| 93 | |||||||||||||||
| 94 | |||||||||||||||
| 95 | |||||||||||||||
| 96 | |||||||||||||||
| 97 | |||||||||||||||
| 98 | |||||||||||||||
| 99 | |||||||||||||||
| 100 | |||||||||||||||
| 101 | Subtotal Franchise Tax |
||||||||||||||
| 102 | |||||||||||||||
| 103 | |||||||||||||||
| 104 | |||||||||||||||
| 105 | |||||||||||||||
| 106 | Subtotal Other State Tax |
||||||||||||||
| 107 | |||||||||||||||
| 108 | |||||||||||||||
| 109 | |||||||||||||||
| 110 | Subtotal Other License And Fees Tax |
||||||||||||||
| 111 | |||||||||||||||
| 112 | |||||||||||||||
| 113 | |||||||||||||||
| 114 | |||||||||||||||
| 115 | |||||||||||||||
| 116 | |||||||||||||||
| 117 | Subtotal Other Tax |
||||||||||||||
| 40 |
TOTAL |
|
|
|
|
|
|
|
|
||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
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 |
|
||||||||||
| 4 |
|
||||||||||
| 5 |
|
||||||||||
| 6 |
|
||||||||||
| 7 |
|
||||||||||
| 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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
OTHER DEFERRED CREDITS (Account 253) |
||||||
|
||||||
| 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 | ||||||
| 2 | (a) |
|||||
| 3 | (b) |
|||||
| 4 | ||||||
| 5 | ||||||
| 6 | ||||||
| 7 | ||||||
| 8 | ||||||
| 9 | ||||||
| 10 | ||||||
| 11 | ||||||
| 12 | ||||||
| 47 |
TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: DescriptionOfOtherDeferredCredits | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Formula Rate Uses:
SPP Independent Power Producers System Upgrade Credits By Function
YEAR 2021
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: DescriptionOfOtherDeferredCredits | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281) |
||||||||||||
|
||||||||||||
| 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 |
|
|||||||||||
8 |
TOTAL Electric (Enter Total of lines 3 thru 7) |
|
||||||||||
9 |
Gas |
|||||||||||
10 |
Defense Facilities |
|||||||||||
11 |
Pollution Control Facilities |
|||||||||||
12 |
Other |
|||||||||||
12.1 |
|
|||||||||||
15 |
TOTAL Gas (Enter Total of lines 10 thru 14) |
|||||||||||
16 |
Other |
|||||||||||
16.1 |
|
(a) |
||||||||||
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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty | ||||||||||||||||||||||||||||||||||||
Formula Rate uses 13 month average.
| ||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282) |
||||||||||||
|
||||||||||||
| 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 |
|||||||||||
3 |
Gas |
|||||||||||
4 |
Other (Specify) |
|||||||||||
5 |
Total (Total of lines 2 thru 4) |
|||||||||||
| 6 |
|
(a) |
|
|
|
|
|
|||||
| 9 |
TOTAL Account 282 (Total of Lines 5 thru 8) |
|
|
|
|
|
|
|||||
| 10 |
Classification of TOTAL |
|||||||||||
| 11 |
Federal Income Tax |
|
|
|
|
|
|
|||||
| 12 |
State Income Tax |
|||||||||||
| 13 |
Local Income Tax |
|||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: AccumulatedDeferredIncomeTaxesOtherProperty | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283) |
|||||||||||
|
|||||||||||
| 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 |
|
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||||||
| 4 |
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||||||
| 5 |
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||||||
| 6 |
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||||||
| 7 |
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||||||
| 8 |
|
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||||||
| 9 | TOTAL Electric (Total of lines 3 thru 8) |
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||||||
| 10 |
Gas |
||||||||||
| 11 | |||||||||||
| 12 | |||||||||||
| 13 | |||||||||||
| 14 | |||||||||||
| 15 | |||||||||||
| 16 | |||||||||||
| 17 | TOTAL Gas (Total of lines 11 thru 16) | ||||||||||
| 18 | TOTAL Other |
(a) |
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||||
| 19 | TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18) |
(b) |
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|
||||
| 20 |
Classification of TOTAL |
||||||||||
| 21 |
Federal Income Tax |
|
|
|
|
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|
||||
| 22 |
State Income Tax |
|
|
|
|
||||||
| 23 |
Local Income Tax |
||||||||||
|
NOTES |
|||||||||||
| FOOTNOTE DATA |
| (a) Concept: AccumulatedDeferredIncomeTaxesOther | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: AccumulatedDeferredIncomeTaxesOther | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
OTHER REGULATORY LIABILITIES (Account 254) |
||||||
|
||||||
| 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 |
|
|
|
|
|
|
| 2 |
|
|
|
|
|
|
| 3 |
|
|
|
|
|
|
| 4 |
|
|
|
|
|
|
| 5 |
|
|
|
|
|
|
| 6 |
|
|
|
|||
| 7 |
|
|
|
|
|
|
| 8 |
|
|
|
|
|
|
| 9 |
|
|
|
|
|
|
| 10 |
|
|
|
|
|
|
| 11 |
|
|||||
| 41 | TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
Electric Operating Revenues |
|||||||
|
|||||||
| 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 |
|
|
||||
|
14 |
RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds |
|
|
|
|
|
|
|
15 |
OtherOperatingRevenuesAbstract Other Operating Revenues |
||||||
|
16 |
ForfeitedDiscounts (450) Forfeited Discounts |
|
|
||||
|
17 |
MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues |
(a) |
|
||||
|
18 |
SalesOfWaterAndWaterPower (453) Sales of Water and Water Power |
||||||
|
19 |
RentFromElectricProperty (454) Rent from Electric Property |
|
|
||||
|
20 |
InterdepartmentalRents (455) Interdepartmental Rents |
||||||
|
21 |
OtherElectricRevenue (456) Other Electric Revenues |
(b) |
|
||||
|
22 |
RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others |
|
|
||||
|
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 |
|
|
||||
|
27 |
ElectricOperatingRevenues TOTAL Electric Operating Revenues |
|
|
||||
|
Line12, column (b) includes $
|
|||||||
|
Line12, column (d) includes
|
|||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: MiscellaneousServiceRevenues | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: OtherElectricRevenue | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1) |
|||||
|
|||||
| 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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| 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 |
(a) |
|
|
|
|
|
| 2 |
|
|
|
|
|
|
| 3 |
|
|
|
|
|
|
| 4 |
|
|
|
|
|
|
| 5 |
|
|
|
|
|
|
| 6 |
|
|
|
|
|
|
| 7 |
|
|
|
|
|
|
| 8 |
|
|
|
|
|
|
| 9 |
|
|
|
|
|
|
| 10 |
|
|
||||
| 11 |
|
|
||||
| 12 |
|
|
|
|
|
|
| 13 |
|
|
|
|
|
|
| 41 | TOTAL Billed Residential Sales |
|
|
|
||
| 42 | TOTAL Unbilled Rev. (See Instr. 6) |
|
|
|||
| 43 | TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: DescriptionOfNumberAndTitleOfRateSchedule | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| 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 |
|
|
|
|
|
|
| 41 | TOTAL Billed Small or Commercial |
|
|
|
||
| 42 | TOTAL Unbilled Rev. Small or Commercial (See Instr. 6) |
|
|
|||
| 43 | TOTAL Small or Commercial |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| 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 |
|
|
||||
| 41 | TOTAL Billed Large (or Ind.) Sales |
|
|
|
||
| 42 | TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6) |
|
|
|||
| 43 | TOTAL Large (or Ind.) |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| Line No. |
Number and Title of Rate Schedule (a) |
MWh Sold (b) |
Revenue (c) |
Average Number of Customers (d) |
KWh of Sales Per Customer (e) |
Revenue Per KWh Sold (f) |
| 1 | ||||||
| 2 | ||||||
| 3 | ||||||
| 4 | ||||||
| 5 | ||||||
| 6 | ||||||
| 7 | ||||||
| 8 | ||||||
| 9 | ||||||
| 10 | ||||||
| 11 | ||||||
| 12 | ||||||
| 13 | ||||||
| 14 | ||||||
| 15 | ||||||
| 16 | ||||||
| 17 | ||||||
| 18 | ||||||
| 19 | ||||||
| 20 | ||||||
| 21 | ||||||
| 22 | ||||||
| 23 | ||||||
| 24 | ||||||
| 25 | ||||||
| 26 | ||||||
| 27 | ||||||
| 28 | ||||||
| 29 | ||||||
| 30 | ||||||
| 31 | ||||||
| 32 | ||||||
| 33 | ||||||
| 34 | ||||||
| 35 | ||||||
| 36 | ||||||
| 37 | ||||||
| 38 | ||||||
| 39 | ||||||
| 40 | ||||||
| 41 | TOTAL Billed Commercial and Industrial Sales | |||||
| 42 | TOTAL Unbilled Rev. (See Instr. 6) | |||||
| 43 | TOTAL | |||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| 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 |
|
|
|
|
|
|
| 41 | TOTAL Billed Public Street and Highway Lighting |
|
|
|
||
| 42 | TOTAL Unbilled Rev. (See Instr. 6) |
|
|
|||
| 43 | TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| 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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| Line No. |
Number and Title of Rate Schedule (a) |
MWh Sold (b) |
Revenue (c) |
Average Number of Customers (d) |
KWh of Sales Per Customer (e) |
Revenue Per KWh Sold (f) |
| 41 | TOTAL Billed - All Accounts |
|
|
|
||
| 42 | TOTAL Unbilled Rev. (See Instr. 6) - All Accounts |
|
|
|||
| 43 | TOTAL - All Accounts |
|
|
|
||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES FOR RESALE (Account 447) |
|||||||||||
|
|||||||||||
| 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 |
(a) |
|
|
|
|
|
|
|
|
|
|
| 6 |
|
|
|
|
|
|
|
|
|
|
|
| 7 |
|
||||||||||
| 8 |
|
|
|
||||||||
| 9 |
|
|
|
|
|
|
|
|
|
|
|
| 10 |
|
|
|
|
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|
|
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|
|
| 11 |
|
|
|
|
|||||||
| 12 |
|
|
|
|
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|
|
|
|
|
| 13 |
|
|
|
|
|
|
|
||||
| 14 |
|
|
|
|
|
||||||
| 15 |
|
|
|
|
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|
|||||
| 16 |
|
|
|
|
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|
|
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|
|
| 17 |
|
|
|
|
|
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|
||||
| 18 |
|
|
|
||||||||
| 19 |
|
|
|
||||||||
| 20 |
|
||||||||||
| 21 |
|
||||||||||
| 15 |
Subtotal - RQ |
|
|
|
|
||||||
| 16 |
Subtotal-Non-RQ |
|
|
|
|
||||||
| 17 | Total |
|
|
|
|
|
|||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: NameOfCompanyOrPublicAuthorityReceivingElectricityPurchasedForResale |
Includes customer charge
(2)
Wholesale transmission
(3)
Respondent is an affiliated company of American Electric Power Service Corporation
(4)
Bookout margins, net
(5)
Merchant sale
(6)
Net trading purchases & sales within the Electric Reliability Council of Texas
(ERCOT)
(7)
Net trading purchases & sales within the Southwest Power Pool (SPP)
(8)
Realization System Integration Agreement Sharing
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
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 |
|
|
|
67 |
OtherPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 62 thru 67) |
|
|
|
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) |
|
|
|
75 |
OtherPowerSuplyExpensesAbstract E. Other Power Supply Expenses |
||
|
76 |
PurchasedPower (555) Purchased Power |
|
|
|
76.1 |
PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations |
|
|
|
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) |
|
|
|
81 |
TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES |
||
|
82 |
TransmissionExpensesOperationAbstract Operation |
||
|
83 |
OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering |
|
|
|
85 |
LoadDispatchReliability (561.1) Load Dispatch-Reliability |
|
|
|
86 |
LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System |
|
|
|
87 |
LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling |
|
|
|
88 |
SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services |
|
|
|
89 |
ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development |
|
|
|
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 |
|
|
|
93.1 |
OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment |
||
|
94 |
OverheadLineExpense (563) Overhead Lines Expenses |
|
|
|
95 |
UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses |
|
|
|
96 |
TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others |
|
|
|
97 |
MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses |
|
|
|
98 |
RentsTransmissionElectricExpense (567) Rents |
|
|
|
99 |
TransmissionOperationExpense TOTAL Operation (Enter Total of Lines 83 thru 98) |
|
|
|
100 |
TransmissionMaintenanceAbstract Maintenance |
||
|
101 |
MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering |
|
|
|
102 |
MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures |
|
|
|
103 |
MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware |
|
|
|
104 |
MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software |
(a) |
|
|
105 |
MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment |
|
|
|
106 |
MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant |
||
|
107 |
MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment |
|
|
|
107.1 |
MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment |
||
|
108 |
MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines |
|
|
|
109 |
MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines |
|
|
|
110 |
MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant |
|
|
|
111 |
TransmissionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 101 thru 110) |
|
|
|
112 |
TransmissionExpenses TOTAL Transmission Expenses (Total of Lines 99 and 111) |
|
|
|
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 |
|
|
|
182 |
OfficeSuppliesAndExpenses (921) Office Supplies and Expenses |
|
|
|
183 |
AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit |
|
|
|
184 |
OutsideServicesEmployed (923) Outside Services Employed |
|
|
|
185 |
PropertyInsurance (924) Property Insurance |
|
|
|
186 |
InjuriesAndDamages (925) Injuries and Damages |
|
|
|
187 |
EmployeePensionsAndBenefits (926) Employee Pensions and Benefits |
|
|
|
188 |
FranchiseRequirements (927) Franchise Requirements |
||
|
189 |
RegulatoryCommissionExpenses (928) Regulatory Commission Expenses |
|
|
|
190 |
DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr. |
||
|
191 |
GeneralAdvertisingExpenses (930.1) General Advertising Expenses |
|
|
|
192 |
MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses |
|
|
|
193 |
RentsAdministrativeAndGeneralExpense (931) Rents |
|
|
|
194 |
AdministrativeAndGeneralOperationExpense TOTAL Operation (Enter Total of Lines 181 thru 193) |
|
|
|
195 |
AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance |
||
|
196 |
MaintenanceOfGeneralPlant (935) Maintenance of General Plant |
|
|
|
197 |
AdministrativeAndGeneralExpenses TOTAL Administrative & General Expenses (Total of Lines 194 and 196) |
|
|
|
198 |
OperationsAndMaintenanceExpensesElectric TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197) |
|
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: MaintenanceOfComputerSoftwareTransmission |
This footnote applies to both current and prior year.
Allocated maintenance expenses for joint use computer hardware, computer software and communication equipment are determined by using various factors, which include number of remote terminal units, number of radios, number of employees and other factors assigned to each function.
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
PURCHASED POWER (Account 555) |
||||||||||||||
|
||||||||||||||
| Actual Demand (MW) | POWER EXCHANGES | COST/SETTLEMENT OF POWER | ||||||||||||
| Line No. |
NameOfCompanyOrPublicAuthorityProvidingPurchasedPower Name of Company or Public Authority (Footnote Affiliations) (a) |
StatisticalClassificationCode Statistical Classification (b) |
RateScheduleTariffNumber Ferc Rate Schedule or Tariff Number (c) |
AverageMonthlyBillingDemand Average Monthly Billing Demand (MW) (d) |
AverageMonthlyNonCoincidentPeakDemand Average Monthly NCP Demand (e) |
AverageMonthlyCoincidentPeakDemand Average Monthly CP Demand (f) |
MegawattHoursPurchasedOtherThanStorage MegaWatt Hours Purchased (Excluding for Energy Storage) (g) |
MegawattHoursPurchasedForEnergyStorage MegaWatt Hours Purchased for Energy Storage (h) |
EnergyReceivedThroughPowerExchanges MegaWatt Hours Received (i) |
EnergyDeliveredThroughPowerExchanges MegaWatt Hours Delivered (j) |
DemandChargesOfPurchasedPower Demand Charges ($) (k) |
EnergyChargesOfPurchasedPower Energy Charges ($) (l) |
OtherChargesOfPurchasedPower Other Charges ($) (m) |
SettlementOfPower Total (k+l+m) of Settlement ($) (n) |
| 1 | (a) |
|||||||||||||
| 2 | ||||||||||||||
| 3 | ||||||||||||||
| 4 | ||||||||||||||
| 5 | ||||||||||||||
| 6 | ||||||||||||||
| 7 | ||||||||||||||
| 8 | ||||||||||||||
| 9 | ||||||||||||||
| 15 | TOTAL |
|
|
|
|
|
|
|
|
|||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower |
C
apacity
(2)
Cogeneration
(3)
Wind Energy
(4)
Net Trading Purchases & Sales within Southwest Power Pool (SPP)
(5)
Net Trading Purchases & Sales within ERCOT
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling") |
||||||||||||||
|
||||||||||||||
| TRANSFER OF ENERGY | REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS | |||||||||||||
| Line No. |
PaymentByCompanyOrPublicAuthority Payment By (Company of Public Authority) (Footnote Affiliation) (a) |
TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) |
TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) |
StatisticalClassificationCode Statistical Classification (d) |
RateScheduleTariffNumber Ferc Rate Schedule of Tariff Number (e) |
TransmissionPointOfReceipt Point of Receipt (Substation or Other Designation) (f) |
TransmissionPointOfDelivery Point of Delivery (Substation or Other Designation) (g) |
BillingDemand Billing Demand (MW) (h) |
TransmissionOfElectricityForOthersEnergyReceived Megawatt Hours Received (i) |
TransmissionOfElectricityForOthersEnergyDelivered Megawatt Hours Delivered (j) |
Demand Charges ($) (k) |
Energy Charges ($) (l) |
Other Charges ($) (m) |
RevenuesFromTransmissionOfElectricityForOthers Total Revenues ($) (k+l+m) (n) |
| 1 |
|
|
|
|
|
|
|
|||||||
| 2 |
(a) |
|
|
|||||||||||
| 3 |
|
|
|
|||||||||||
| 4 |
|
|
|
|
|
|
|
|
|
|||||
| 5 |
|
|
|
|
|
|
|
|
|
|||||
| 6 |
|
|
|
|
|
|
|
|
|
|||||
| 35 | TOTAL |
|
|
|
|
|
||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: PaymentByCompanyOrPublicAuthority |
Respondent is an affiliated company of American Electric Power Service Corporation
(2)
Facility charge
(3)
Southwest Power Pool base plan funding
(4)
Southwest Power Pool ancillary service schedule 1
(5)
Network Integrated Transmission Service (NITS)
(6)
Prior Year
(7)
Transmission service charge
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
TRANSMISSION OF ELECTRICITY BY ISO/RTOs |
|||||
|
|||||
| 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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565) |
||||||||
|
||||||||
| 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 |
(a) |
|
|
|
||||
| 4 |
|
|
|
|
||||
| 5 |
|
|||||||
| 6 |
|
|
|
|
||||
| 7 |
|
|
|
|
||||
|
TOTAL |
|
|
|
|
|
|
||
| FOOTNOTE DATA |
| (a) Concept: NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers |
Respondent is an affiliated company of American Electric Power Service Corporation
(2)
Facility charge
(3)
Southwest Power Pool base plan funding
(4)
Southwest Power Pool ancillary service schedule 1
(5)
Network Integrated Transmission Service (NITS)
(6)
Prior year
(7)
Transmission service charge
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
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 |
|
|
| 7 |
|
|
| 8 |
|
|
| 9 |
|
|
| 10 |
|
|
| 46 |
MiscellaneousGeneralExpenses
TOTAL
|
|
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Depreciation and Amortization of Electric Plant (Account 403, 404, 405) |
||||||
|
||||||
| 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 |
|
|
|||
| 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 |
|
|
|||
| 8 |
Distribution Plant |
|
|
|||
| 9 |
Regional Transmission and Market Operation |
|||||
| 10 |
General Plant |
|
|
|
||
| 11 |
Common Plant-Electric |
|||||
| 12 |
TOTAL |
|
|
|
|
|
| B. Basis for Amortization Charges | ||||||
|
|
||||||
| 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 | ||||||||
| 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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
REGULATORY COMMISSION EXPENSES |
||||||||||||
|
||||||||||||
| 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 |
|
|||||||||||
| 2 |
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| 3 |
|
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| 4 |
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||||||
| 5 |
|
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| 6 |
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||||||
| 7 |
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||||||
| 8 |
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||||||
| 9 |
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||||||||
| 10 |
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| 11 |
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||||||
| 12 |
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||||||
| 13 |
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||||||||
| 14 |
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||||||
| 15 |
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||||||
| 16 |
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||||||
| 17 |
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||||||
| 18 |
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||||||
| 19 |
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||||||
| 20 |
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||||||
| 21 |
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||||||
| 22 |
|
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||||||
| 23 |
|
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||||||
| 24 |
|
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||||||
| 25 |
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||||||
| 26 |
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||||||
| 27 |
|
|
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|
||||||
| 28 |
|
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||||||
| 29 |
|
|
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||||||
| 30 |
|
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||||||
| 31 |
|
|
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||||||
| 32 |
|
|
|
|
|
|
||||||
| 33 |
|
|
|
|
|
|
||||||
| 46 |
TOTAL |
|
|
|
|
|
|
|
|
|||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES |
|||||||
|
|||||||
| 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 | |||||||
| 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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
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 |
||||
|
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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
COMMON UTILITY PLANT AND EXPENSES |
||||
|
||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS |
|||||
|
|||||
| 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 |
|
|
|||
| 46 | TOTAL |
|
|||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
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.
|
|||||||
| 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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
MONTHLY TRANSMISSION SYSTEM PEAK LOAD |
||||||||||
|
||||||||||
| Line No. |
Month (a) |
Monthly Peak MW - Total (b) |
Day of Monthly Peak (c) |
Hour of Monthly Peak (d) |
Firm Network Service for Self (e) |
Firm Network Service for Others (f) |
Long-Term Firm Point-to-point Reservations (g) |
Other Long-Term Firm Service (h) |
Short-Term Firm Point-to-point Reservation (i) |
Other Service (j) |
NAME OF SYSTEM: 0 |
||||||||||
1 |
January |
(a) |
||||||||
2 |
February |
|||||||||
3 |
March |
|||||||||
4 |
Total for Quarter 1 |
|||||||||
5 |
April |
|||||||||
6 |
May |
|||||||||
7 |
June |
|||||||||
8 |
Total for Quarter 2 |
|||||||||
9 |
July |
|||||||||
10 |
August |
|||||||||
11 |
September |
|||||||||
12 |
Total for Quarter 3 |
|||||||||
13 |
October |
|||||||||
14 |
November |
|||||||||
15 |
December |
|||||||||
16 |
Total for Quarter 4 |
|||||||||
17 |
Total |
(b) |
||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: MonthlyPeakLoadExcludingIsoAndRto |
| (b) Concept: OtherService |
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Monthly ISO/RTO Transmission System Peak Load |
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|
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| 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 |
|||||||||
5 |
April |
|||||||||
6 |
May |
|||||||||
7 |
June |
|||||||||
8 |
Total for Quarter 2 |
|||||||||
9 |
July |
|||||||||
10 |
August |
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11 |
September |
|||||||||
12 |
Total for Quarter 3 |
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13 |
October |
|||||||||
14 |
November |
|||||||||
15 |
December |
|||||||||
16 |
Total for Quarter 4 |
|||||||||
17 |
Total Year to Date/Year |
|||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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) |
|
28 |
TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES |
|
| 10 |
Purchases (other than for Energy Storage) |
|
|||
| 10.1 |
Purchases for Energy Storage |
|
|||
| 11 |
Power Exchanges: |
||||
| 12 |
Received |
|
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| 13 |
Delivered |
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| 14 |
Net Exchanges (Line 12 minus line 13) |
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| 15 |
Transmission For Other (Wheeling) |
||||
| 16 |
Received |
||||
| 17 |
Delivered |
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| 18 |
Net Transmission for Other (Line 16 minus line 17) |
|
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| 19 |
Transmission By Others Losses |
||||
| 20 |
TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19) |
|
|||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
MONTHLY PEAKS AND OUTPUT |
||||||
|
||||||
| 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 |
|
||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Steam Electric Generating Plant Statistics |
|
1. Report data for plant in Service only. |
| Line No. |
Item
(a)
|
Plant Name:
(a) |
Plant Name:
(b) |
Plant Name:
(c) |
Plant Name:
(d) |
Plant Name:
|
Plant Name:
(e) |
Plant Name:
(f) |
Plant Name:
|
Plant Name:
(g) |
Plant Name:
|
Plant Name:
(h) |
| 1 |
PlantKind Kind of Plant (Internal Comb, Gas Turb, Nuclear) |
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| 2 |
PlantConstructionType Type of Constr (Conventional, Outdoor, Boiler, etc) |
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| 3 |
YearPlantOriginallyConstructed Year Originally Constructed |
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| 4 |
YearLastUnitOfPlantInstalled Year Last Unit was Installed |
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| 5 |
InstalledCapacityOfPlant Total Installed Cap (Max Gen Name Plate Ratings-MW) |
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| 6 |
NetPeakDemandOnPlant Net Peak Demand on Plant - MW (60 minutes) |
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| 7 |
PlantHoursConnectedToLoad Plant Hours Connected to Load |
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| 8 |
NetContinuousPlantCapability Net Continuous Plant Capability (Megawatts) |
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| 9 |
NetContinuousPlantCapabilityNotLimitedByCondenserWater When Not Limited by Condenser Water |
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| 10 |
NetContinuousPlantCapabilityLimitedByCondenserWater When Limited by Condenser Water |
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| 11 |
PlantAverageNumberOfEmployees Average Number of Employees |
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| 12 |
NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh |
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| 13 |
CostOfLandAndLandRightsSteamProduction Cost of Plant: Land and Land Rights |
|
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| 14 |
CostOfStructuresAndImprovementsSteamProduction Structures and Improvements |
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| 15 |
CostOfEquipmentSteamProduction Equipment Costs |
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| 16 |
AssetRetirementCostsSteamProduction Asset Retirement Costs |
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| 17 |
CostOfPlant Total cost (total 13 thru 20) |
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| 18 |
CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 17/5) Including |
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| 19 |
OperationSupervisionAndEngineeringExpense Production Expenses: Oper, Supv, & Engr |
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| 20 |
FuelSteamPowerGeneration Fuel |
|
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| 21 |
CoolantsAndWater Coolants and Water (Nuclear Plants Only) |
|
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|||||||||
| 22 |
SteamExpensesSteamPowerGeneration Steam Expenses |
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| 23 |
SteamFromOtherSources Steam From Other Sources |
|
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|||||||||
| 24 |
SteamTransferredCredit Steam Transferred (Cr) |
|
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|||||||||
| 25 |
ElectricExpensesSteamPowerGeneration Electric Expenses |
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| 26 |
MiscellaneousSteamPowerExpenses Misc Steam (or Nuclear) Power Expenses |
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| 27 |
RentsSteamPowerGeneration Rents |
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| 28 |
Allowances Allowances |
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| 29 |
MaintenanceSupervisionAndEngineeringSteamPowerGeneration Maintenance Supervision and Engineering |
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| 30 |
MaintenanceOfStructuresSteamPowerGeneration Maintenance of Structures |
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| 31 |
MaintenanceOfBoilerPlantSteamPowerGeneration Maintenance of Boiler (or reactor) Plant |
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| 32 |
MaintenanceOfElectricPlantSteamPowerGeneration Maintenance of Electric Plant |
|
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| 33 |
MaintenanceOfMiscellaneousSteamPlant Maintenance of Misc Steam (or Nuclear) Plant |
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| 34 |
PowerProductionExpensesSteamPower Total Production Expenses |
|
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| 35 |
ExpensesPerNetKilowattHour Expenses per Net kWh |
|
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| 35 |
FuelKindAxis Plant Name |
*Dolet Hills (3) |
*Dolet Hills (3) |
*Dolet Hills (3) |
*Flint Creek (1) |
*Flint Creek (1) |
*Flint Creek (1) |
*Pirkey (2) |
*Pirkey (2) |
*Pirkey (2) |
Arsenal Hill |
Harry D Mattison |
Knox Lee |
Knox Lee |
Knox Lee |
Lieberman |
Lieberman |
Lieberman |
North Central Wind |
Turk (4) |
Turk (4) |
Turk (4) |
Welsh |
Welsh |
Welsh |
Wilkes |
Wilkes |
Wilkes |
| 36 |
FuelKind Fuel Kind |
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| 37 |
FuelUnit Fuel Unit |
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||||||||||
| 38 |
QuantityOfFuelBurned Quantity (Units) of Fuel Burned |
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||||||||||||
| 39 |
FuelBurnedAverageHeatContent Avg Heat Cont - Fuel Burned (btu/indicate if nuclear) |
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||||||||||||
| 40 |
AverageCostOfFuelPerUnitAsDelivered Avg Cost of Fuel/unit, as Delvd f.o.b. during year |
|
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||||||||||||
| 41 |
AverageCostOfFuelPerUnitBurned Average Cost of Fuel per Unit Burned |
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||||||||||||
| 42 |
AverageCostOfFuelBurnedPerMillionBritishThermalUnit Average Cost of Fuel Burned per Million BTU |
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||||||||||||
| 43 |
AverageCostOfFuelBurnedPerKilowattHourNetGeneration Average Cost of Fuel Burned per kWh Net Gen |
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||||||||||||
| 44 |
AverageBritishThermalUnitPerKilowattHourNetGeneration Average BTU per kWh Net Generation |
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|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: PlantName | ||||||||||||||||||||||||||||||||||||
(3) Dolet Hills Power Station is jointly owned in the percentages shown below:
| ||||||||||||||||||||||||||||||||||||
| (b) Concept: PlantName | ||||||||||||||||||||||||||||||||||||
(1) Flint Creek Power Station is jointly owned in the percentages shown below:
| ||||||||||||||||||||||||||||||||||||
| (c) Concept: PlantName | ||||||||||||||||||||||||||||||||||||
(2) Pirkey Power Station is jointly owned in the percentages shown below:
| ||||||||||||||||||||||||||||||||||||
| (d) Concept: PlantName | ||||||||||||||||||||||||||||||||||||
Arsenal Hill Unit 6 (J. Lamar Stall Unit), a natural gas-fired combustion turbine combined cycle generating unit, became operational in June 2010. Unit 6 consists of 2 combustion turbines feeding one steam turbine.
| ||||||||||||||||||||||||||||||||||||
| (e) Concept: PlantName | ||||||||||||||||||||||||||||||||||||
| (f) Concept: PlantName | ||||||||||||||||||||||||||||||||||||
| (g) Concept: PlantName | ||||||||||||||||||||||||||||||||||||
Turk Plant, a 600MW Ultra-supercritical coal unit, became operational in December 2012.
(4) Turk Power Station is jointly owned in the percentages shown below:
In April 2021, SWEPCo acquired a 54.5% ownership share of Sundance wind facility (199 MW total nameplate capacity) which was placed in-service in April 2021.
In September 2021, SWEPCo acquired a 54.5% ownership share of Maverick wind facility (287 MW total nameplate capacity) which was placed in-service in September 2021.
| ||||||||||||||||||||||||||||||||||||
| (h) Concept: PlantName | ||||||||||||||||||||||||||||||||||||
Lone Star Plant was retired during May 2020 business.
| ||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Hydroelectric Generating Plant Statistics |
|
| Line No. |
Item
(a)
|
FERC Licensed Project No.
Plant Name:
|
| 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: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Pumped Storage Generating Plant Statistics |
|||||||
|
|||||||
| Line No. |
Item
(a)
|
FERC Licensed Project No.
Plant Name:
|
|||||
| 1 |
PlantConstructionType Type of Plant Construction (Conventional or Outdoor) |
||||||
| 2 |
YearPlantOriginallyConstructed Year Originally Constructed |
||||||
| 3 |
YearLastUnitOfPlantInstalled Year Last Unit was Installed |
||||||
| 4 |
InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW) |
||||||
| 5 |
NetPeakDemandOnPlant Net Peak Demaind on Plant-Megawatts (60 minutes) |
|
|||||
| 6 |
PlantHoursConnectedToLoad Plant Hours Connect to Load While Generating |
|
|||||
| 7 |
NetContinuousPlantCapability Net Plant Capability (in megawatts) |
|
|||||
| 8 |
PlantAverageNumberOfEmployees Average Number of Employees |
||||||
| 9 |
NetGenerationExcludingPlantUse Generation, Exclusive of Plant Use - kWh |
|
|||||
| 10 |
EnergyUsedForPumping Energy Used for Pumping |
||||||
| 11 |
NetOutputForLoad Net Output for Load (line 9 - line 10) - Kwh |
|
|||||
| 12 |
CostOfPlantAbstract Cost of Plant |
||||||
| 13 |
CostOfLandAndLandRightsPumpedStoragePlant Land and Land Rights |
||||||
| 14 |
CostOfStructuresAndImprovementsPumpedStoragePlant Structures and Improvements |
|
|||||
| 15 |
CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant Reservoirs, Dams, and Waterways |
|
|||||
| 16 |
CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant Water Wheels, Turbines, and Generators |
|
|||||
| 17 |
CostOfAccessoryElectricEquipmentPumpedStoragePlant Accessory Electric Equipment |
|
|||||
| 18 |
CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant Miscellaneous Powerplant Equipment |
|
|||||
| 19 |
CostOfRoadsRailroadsAndBridgesPumpedStoragePlant Roads, Railroads, and Bridges |
|
|||||
| 20 |
AssetRetirementCostsPumpedStoragePlant Asset Retirement Costs |
|
|||||
| 21 |
CostOfPlant Total cost (total 13 thru 20) |
||||||
| 22 |
CostPerKilowattOfInstalledCapacity Cost per KW of installed cap (line 21 / 4) |
||||||
| 23 |
ProductionExpensesAbstract Production Expenses |
||||||
| 24 |
OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering |
|
|||||
| 25 |
WaterForPower Water for Power |
|
|||||
| 26 |
PumpedStorageExpenses Pumped Storage Expenses |
|
|||||
| 27 |
ElectricExpensesPumpedStoragePlant Electric Expenses |
|
|||||
| 28 |
MiscellaneousPumpedStoragePowerGenerationExpenses Misc Pumped Storage Power generation Expenses |
|
|||||
| 29 |
RentsPumpedStoragePlant Rents |
|
|||||
| 30 |
MaintenanceSupervisionAndEngineeringPumpedStoragePlant Maintenance Supervision and Engineering |
|
|||||
| 31 |
MaintenanceOfStructuresPumpedStoragePlant Maintenance of Structures |
|
|||||
| 32 |
MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant Maintenance of Reservoirs, Dams, and Waterways |
|
|||||
| 33 |
MaintenanceOfElectricPlantPumpedStoragePlant Maintenance of Electric Plant |
|
|||||
| 34 |
MaintenanceOfMiscellaneousPumpedStoragePlant Maintenance of Misc Pumped Storage Plant |
|
|||||
| 35 |
PowerProductionExpenseBeforePumpingExpenses Production Exp Before Pumping Exp (24 thru 34) |
||||||
| 36 |
PumpingExpenses Pumping Expenses |
||||||
| 37 |
PowerProductionExpensesPumpedStoragePlant Total Production Exp (total 35 and 36) |
||||||
| 38 |
ExpensesPerNetKilowattHour Expenses per kWh (line 37 / 9) |
||||||
| 39 |
ExpensesPerNetKilowattHourGenerationAndPumping Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10)) |
|
|||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
GENERATING PLANT STATISTICS (Small Plants) |
|||||||||||||
|
|||||||||||||
| 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) |
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Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
ENERGY STORAGE OPERATIONS (Large Plants) |
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| 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) |
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Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
TRANSMISSION LINE STATISTICS |
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| 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) |
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| 476 | ||||||||||||||||
| 477 | ||||||||||||||||
| 478 | ||||||||||||||||
| 479 | ||||||||||||||||
| 480 | ||||||||||||||||
| 481 | ||||||||||||||||
| 482 | ||||||||||||||||
| 483 | ||||||||||||||||
| 484 | ||||||||||||||||
| 485 | ||||||||||||||||
| 486 | ||||||||||||||||
| 487 | ||||||||||||||||
| 488 | ||||||||||||||||
| 489 | ||||||||||||||||
| 490 | ||||||||||||||||
| 491 | ||||||||||||||||
| 492 | ||||||||||||||||
| 493 | ||||||||||||||||
| 494 | ||||||||||||||||
| 495 | ||||||||||||||||
| 496 | ||||||||||||||||
| 497 | ||||||||||||||||
| 498 | ||||||||||||||||
| 499 | ||||||||||||||||
| 500 | ||||||||||||||||
| 501 | ||||||||||||||||
| 502 | ||||||||||||||||
| 503 | ||||||||||||||||
| 504 | ||||||||||||||||
| 505 | ||||||||||||||||
| 506 | ||||||||||||||||
| 507 | ||||||||||||||||
| 508 | ||||||||||||||||
| 509 | ||||||||||||||||
| 510 | ||||||||||||||||
| 511 | ||||||||||||||||
| 512 | ||||||||||||||||
| 513 | ||||||||||||||||
| 514 | ||||||||||||||||
| 515 | ||||||||||||||||
| 516 | ||||||||||||||||
| 517 | ||||||||||||||||
| 518 | ||||||||||||||||
| 519 | ||||||||||||||||
| 520 | ||||||||||||||||
| 521 | ||||||||||||||||
| 522 | ||||||||||||||||
| 523 | ||||||||||||||||
| 524 | ||||||||||||||||
| 525 | ||||||||||||||||
| 526 | ||||||||||||||||
| 527 | ||||||||||||||||
| 528 | ||||||||||||||||
| 529 | ||||||||||||||||
| 530 | ||||||||||||||||
| 531 | ||||||||||||||||
| 532 | ||||||||||||||||
| 533 | ||||||||||||||||
| 534 | ||||||||||||||||
| 535 | ||||||||||||||||
| 536 | ||||||||||||||||
| 537 | ||||||||||||||||
| 538 | ||||||||||||||||
| 539 | ||||||||||||||||
| 540 | ||||||||||||||||
| 541 | ||||||||||||||||
| 542 | ||||||||||||||||
| 543 | ||||||||||||||||
| 544 | ||||||||||||||||
| 545 | ||||||||||||||||
| 546 | ||||||||||||||||
| 547 | ||||||||||||||||
| 548 | ||||||||||||||||
| 549 | ||||||||||||||||
| 550 | ||||||||||||||||
| 551 | ||||||||||||||||
| 552 | ||||||||||||||||
| 553 | ||||||||||||||||
| 554 | ||||||||||||||||
| 555 | ||||||||||||||||
| 556 | ||||||||||||||||
| 557 | ||||||||||||||||
| 558 | ||||||||||||||||
| 559 | ||||||||||||||||
| 560 | ||||||||||||||||
| 561 | ||||||||||||||||
| 562 | ||||||||||||||||
| 563 | ||||||||||||||||
| 36 | TOTAL |
|
|
|
|
|
|
|
|
|
|
|||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
TRANSMISSION LINES ADDED DURING YEAR |
||||||||||||||||||
|
||||||||||||||||||
| 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 | ||||||||||||||||||
| 44 |
TOTAL |
|
|
|
|
|
|
|
||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
SUBSTATIONS |
||||||||||||
|
||||||||||||
| 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 | ||||||||||||
| 2 | ||||||||||||
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| 4 | ||||||||||||
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| 379 | ||||||||||||
| 380 | ||||||||||||
| 381 | ||||||||||||
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| 386 | ||||||||||||
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| 403 | ||||||||||||
| 404 | ||||||||||||
| 405 | ||||||||||||
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| 407 | ||||||||||||
| 408 | ||||||||||||
| 409 | ||||||||||||
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| 419 | ||||||||||||
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| 423 | ||||||||||||
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| 426 | ||||||||||||
| 427 | ||||||||||||
| 428 | ||||||||||||
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| 430 | ||||||||||||
| 431 | ||||||||||||
| 432 | ||||||||||||
| 433 | ||||||||||||
| 434 | ||||||||||||
| 435 | ||||||||||||
| 436 | ||||||||||||
| 437 | ||||||||||||
| 438 | ||||||||||||
| 439 | ||||||||||||
| 440 | ||||||||||||
| 441 | ||||||||||||
| 442 | ||||||||||||
| 443 | ||||||||||||
| 444 | ||||||||||||
| 445 | ||||||||||||
| 446 | ||||||||||||
| 447 | ||||||||||||
| 448 | ||||||||||||
| 449 | ||||||||||||
| 450 | ||||||||||||
| 451 | ||||||||||||
| 452 | ||||||||||||
| 453 | ||||||||||||
| 454 | ||||||||||||
| 455 | ||||||||||||
| 456 | ||||||||||||
| 457 | ||||||||||||
| 458 | ||||||||||||
| 459 | ||||||||||||
| 460 | ||||||||||||
| 461 | ||||||||||||
| 462 | ||||||||||||
| 463 | ||||||||||||
| 464 | ||||||||||||
| 465 | ||||||||||||
| 466 | ||||||||||||
| 467 | TotalTransmissionSubstationMember |
|||||||||||
| 468 | Total |
|||||||||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES |
||||
|
||||
| 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 | (a) |
|||
| 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 | ||||
| 19 | ||||
| 20 |
Non-power Goods or Services Provided for Affiliated |
|||
| 21 | ||||
| 22 | ||||
| 23 | ||||
| 24 | ||||
| 25 | ||||
| 26 | ||||
| 27 | ||||
| 28 | ||||
| 29 | ||||
| 30 | ||||
| 31 | ||||
| 32 | ||||
| 33 | ||||
| 34 | ||||
| 35 | ||||
| 36 | ||||
| 37 | ||||
| 42 | ||||
|
Name of Respondent: |
This report is: (1) ☐ An Original (2) ☑ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: NameOfAssociatedAffiliatedCompany |
Affiliated Companies shown in Column ( B ):
AEP Credit, Inc. - AEP Credit, Inc.
AEPSC - American Electric Power Service Corporation
AEP Texas - AEP Texas, Inc.
APCo - Appalachian Power Company
DHLC - Dolet Hills Lignite Company
I&M - Indiana Michigan Power Company
OPCo - Ohio Power Company
PSO - Public Service Company of Oklahoma
AEPSC Allocations
Certain managerial and professional services provided by AEPSC are allocated among multiple affiliates. The costs of the services are billed on a direct-charge basis, whenever possible. Costs incurred to perform services that benefit more than one company are allocated to the benefiting companies using one of 80 FERC accepted allocation factors. The allocation factors used to bill for services performed by AEPSC are based upon formulae that consider factors such as number of customers, number of employees,number of transmission pole miles, number of invoices and other factors. The data upon which these formulae are based is updated monthly, quarterly, semi-annually or annually,depending on the particular factor and its volatility. The billings for services are made at cost and include no compensation for a return on investment.
FLEET Allocations (Various)
Costs related to AEP's fleet vehicles are allocated in the same manner as the labor of each department utilizing the vehicles. To the extent a department provides service to another affiliate company, an applicable share of their fleet costs are also assigned to that affiliate company.
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