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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: |
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 | ||||
01 Exact Legal Name of Respondent
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02 Year/ Period of Report
End of: 2,018 /
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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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Quarterly 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. |
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
List of Schedules |
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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 | |||
ScheduleListOfSchedulesAbstract List of Schedules (Electric Utility) |
2 | |||
1 |
ScheduleImportantChangesDuringTheQuarterYearAbstract Important Changes During the Quarter |
108 | ||
2 |
ScheduleComparativeBalanceSheetAbstract Comparative Balance Sheet |
110 | ||
3 |
ScheduleStatementOfIncomeAbstract Statement of Income for the Quarter |
114 | ||
4 |
ScheduleRetainedEarningsAbstract Statement of Retained Earnings for the Quarter |
118 | ||
5 |
ScheduleStatementOfCashFlowsAbstract Statement of Cash Flows |
120 | ||
6 |
ScheduleNotesToFinancialStatementsAbstract Notes to Financial Statements |
122 | ||
7 |
ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract Statement of Accum Comp Income, Comp Income, and Hedging Activities |
122a | ||
8 |
ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep |
200 |
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9 |
ScheduleElectricPlantInServiceAndAccumulatedProvisionForDepreciationByFunctionAbstract Electric Plant In Service and Accum Provision For Depr by Function |
208 | ||
10 |
ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract Transmission Service and Generation Interconnection Study Costs |
231 | ||
11 |
ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets |
232 | ||
12 |
ScheduleOtherRegulatoryLiabilitiesAbstract Other Regulatory Liabilities |
278 | ||
13 |
ScheduleElectricOperatingRevenuesAbstract Elec Operating Revenues (Individual Schedule Lines 300-301) |
300 | ||
14 |
ScheduleRegionalTransmissionServiceRevenuesAbstract Regional Transmission Service Revenues (Account 457.1) |
302 | ||
15 |
ScheduleElectricProductionOtherPowerTransmissionRegionalExpensesAbstract Electric Prod, Other Power Supply Exp, Trans and Distrib Exp |
324 | ||
16 |
ScheduleElectricCustomerAccountServiceSalesAdministrativeAndGeneralExpensesAbstract Electric Customer Accts, Service, Sales, Admin and General Expenses |
325 | ||
17 |
ScheduleTransmissionOfElectricityForOthersAbstract Transmission of Electricity for Others |
328 | ||
18 |
ScheduleTransmissionOfElectricityByIsoOrRtoAbstract Transmission of Electricity by ISO/RTOs |
331 | ||
19 |
ScheduleTransmissionOfElectricityByOthersAbstract Transmission of Electricity by Others |
332 | ||
20 |
ScheduleDepreciationDepletionAndAmortizationsAbstract Deprec, Depl and Amort of Elec Plant (403,403.1,404,and 405) (except Amortization of Acquisition Adjustments) |
338 | ||
21 |
ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract Amounts Included in ISO/RTO Settlement Statements |
397 | ||
22 |
ScheduleMonthlyPeaksAndOutputAbstract Monthly Peak Loads and Energy Output |
399 | ||
23 |
ScheduleMonthlyTransmissionSystemPeakLoadAbstract Monthly Transmission System Peak Load |
400 | ||
24 |
ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract Monthly ISO/RTO Transmission System Peak Load |
400a |
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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.
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1. Changes in franchise rights: None
2. Information on consolidation, mergers, and reorganizations: None
3. Purchase or sale of an operating unit or system: None
4. Important leaseholds: None
5. Important extension or reduction of transmission or distribution system: None
6. Issuance of secruities or assumption of liabilities or guarantees: The settlement of the Company’s various transactions with NGUSA and certain affiliates generally occurs via the intercompany money pool. The Company is a participant in the Regulated Money Pool and can both borrow and lend funds. Borrowings from the Regulated Money Pool bear interest in accordance with the terms of the intercompany money pool agreement. As the Company fully participates in the Regulated Money Pool rather than settling intercompany charges with cash, all changes in the intercompany money pool balance and accounts receivable and payable from affiliate balances, are reflected as investing or financing activities in the accompanying statements of cash flows. In addition, for the purpose of presentation in the statement of cash flows, it is assumed all amounts settled through intercompany money pool are constructive cash receipts and payments, and therefore are presented as such.
7. Changes in articles of incorporation: None
8. Wage scale increase: Local 97C: 2.0% Effective 4/1/2018 Local 97: 2.5% Effective 4/1/2018
9. Status of legal proceedings: Refer to Page 123 - Notes to Financial Statements - Note 11 Commitments and Contingencies
10. Additional material transactions not reported elsewhere in this report: None
11. Reserved: None
12. N/A
13 Changes in General Officers: None
14. N/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: |
COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS) |
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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 |
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2 |
UtilityPlant Utility Plant (101-106, 114) |
200 |
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3 |
ConstructionWorkInProgress Construction Work in Progress (107) |
200 |
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4 |
UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3) |
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5 |
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115) |
200 |
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6 |
UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5) |
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7 |
NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1) |
202 |
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8 |
NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly Nuclear Fuel Materials and Assemblies-Stock Account (120.2) |
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9 |
NuclearFuelAssembliesInReactorMajorOnly Nuclear Fuel Assemblies in Reactor (120.3) |
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10 |
SpentNuclearFuelMajorOnly Spent Nuclear Fuel (120.4) |
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11 |
NuclearFuelUnderCapitalLeases Nuclear Fuel Under Capital Leases (120.6) |
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12 |
AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5) |
202 |
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13 |
NuclearFuelNet Net Nuclear Fuel (Enter Total of lines 7-11 less 12) |
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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 |
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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) |
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21 |
InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1) |
224 |
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23 |
NoncurrentPortionOfAllowances Noncurrent Portion of Allowances |
228 |
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24 |
OtherInvestments Other Investments (124) |
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25 |
SinkingFunds Sinking Funds (125) |
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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) |
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31 |
DerivativeInstrumentAssetsHedgesLongTerm Long-Term Portion of Derivative Assets - Hedges (176) |
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32 |
OtherPropertyAndInvestments TOTAL Other Property and Investments (Lines 18-21 and 23-31) |
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33 |
CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS |
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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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37 |
WorkingFunds Working Fund (135) |
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38 |
TemporaryCashInvestments Temporary Cash Investments (136) |
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39 |
NotesReceivable Notes Receivable (141) |
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40 |
CustomerAccountsReceivable Customer Accounts Receivable (142) |
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41 |
OtherAccountsReceivable Other Accounts Receivable (143) |
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42 |
AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144) |
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43 |
NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145) |
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44 |
AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146) |
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45 |
FuelStock Fuel Stock (151) |
227 |
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46 |
FuelStockExpensesUndistributed Fuel Stock Expenses Undistributed (152) |
227 |
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47 |
Residuals Residuals (Elec) and Extracted Products (153) |
227 |
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48 |
PlantMaterialsAndOperatingSupplies Plant Materials and Operating Supplies (154) |
227 |
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49 |
Merchandise Merchandise (155) |
227 |
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50 |
OtherMaterialsAndSupplies Other Materials and Supplies (156) |
227 |
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51 |
NuclearMaterialsHeldForSale Nuclear Materials Held for Sale (157) |
202/227 |
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52 |
AllowanceInventoryAndWithheld Allowances (158.1 and 158.2) |
228 |
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53 |
NoncurrentPortionOfAllowances (Less) Noncurrent Portion of Allowances |
228 |
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54 |
StoresExpenseUndistributed Stores Expense Undistributed (163) |
227 |
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55 |
GasStoredCurrent Gas Stored Underground - Current (164.1) |
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56 |
LiquefiedNaturalGasStoredAndHeldForProcessing Liquefied Natural Gas Stored and Held for Processing (164.2-164.3) |
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57 |
Prepayments Prepayments (165) |
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58 |
AdvancesForGas Advances for Gas (166-167) |
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59 |
InterestAndDividendsReceivable Interest and Dividends Receivable (171) |
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60 |
RentsReceivable Rents Receivable (172) |
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61 |
AccruedUtilityRevenues Accrued Utility Revenues (173) |
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62 |
MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174) |
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63 |
DerivativeInstrumentAssets Derivative Instrument Assets (175) |
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64 |
DerivativeInstrumentAssetsLongTerm (Less) Long-Term Portion of Derivative Instrument Assets (175) |
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65 |
DerivativeInstrumentAssetsHedges Derivative Instrument Assets - Hedges (176) |
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66 |
DerivativeInstrumentAssetsHedgesLongTerm (Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176) |
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67 |
CurrentAndAccruedAssets Total Current and Accrued Assets (Lines 34 through 66) |
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68 |
DeferredDebitsAbstract DEFERRED DEBITS |
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69 |
UnamortizedDebtExpense Unamortized Debt Expenses (181) |
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70 |
ExtraordinaryPropertyLosses Extraordinary Property Losses (182.1) |
230a |
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71 |
UnrecoveredPlantAndRegulatoryStudyCosts Unrecovered Plant and Regulatory Study Costs (182.2) |
230b |
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72 |
OtherRegulatoryAssets Other Regulatory Assets (182.3) |
232 |
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73 |
PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183) |
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74 |
PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges Preliminary Natural Gas Survey and Investigation Charges 183.1) |
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75 |
OtherPreliminarySurveyAndInvestigationCharges Other Preliminary Survey and Investigation Charges (183.2) |
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76 |
ClearingAccounts Clearing Accounts (184) |
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77 |
TemporaryFacilities Temporary Facilities (185) |
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78 |
MiscellaneousDeferredDebits Miscellaneous Deferred Debits (186) |
233 |
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79 |
DeferredLossesFromDispositionOfUtilityPlant Def. Losses from Disposition of Utility Plt. (187) |
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80 |
ResearchDevelopmentAndDemonstrationExpenditures Research, Devel. and Demonstration Expend. (188) |
352 |
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81 |
UnamortizedLossOnReacquiredDebt Unamortized Loss on Reaquired Debt (189) |
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82 |
AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190) |
234 |
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83 |
UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191) |
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84 |
DeferredDebits Total Deferred Debits (lines 69 through 83) |
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85 |
AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84) |
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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: OtherRegulatoryAssets |
(b) Concept: OtherRegulatoryAssets |
(c) Concept: OtherRegulatoryAssets |
(d) Concept: OtherRegulatoryAssets |
(e) Concept: OtherRegulatoryAssets |
(f) Concept: OtherRegulatoryAssets |
(g) Concept: OtherRegulatoryAssets |
(h) Concept: OtherRegulatoryAssets |
(i) Concept: OtherRegulatoryAssets |
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) |
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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 |
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2 |
CommonStockIssued Common Stock Issued (201) |
250 |
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3 |
PreferredStockIssued Preferred Stock Issued (204) |
250 |
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4 |
CapitalStockSubscribed Capital Stock Subscribed (202, 205) |
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5 |
StockLiabilityForConversion Stock Liability for Conversion (203, 206) |
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6 |
PremiumOnCapitalStock Premium on Capital Stock (207) |
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7 |
OtherPaidInCapital Other Paid-In Capital (208-211) |
253 |
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8 |
InstallmentsReceivedOnCapitalStock Installments Received on Capital Stock (212) |
252 |
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9 |
DiscountOnCapitalStock (Less) Discount on Capital Stock (213) |
254 |
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10 |
CapitalStockExpense (Less) Capital Stock Expense (214) |
254b |
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11 |
RetainedEarnings Retained Earnings (215, 215.1, 216) |
118 |
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12 |
UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1) |
118 |
(a) |
(b) |
13 |
ReacquiredCapitalStock (Less) Reaquired Capital Stock (217) |
250 |
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14 |
NoncorporateProprietorship Noncorporate Proprietorship (Non-major only) (218) |
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15 |
AccumulatedOtherComprehensiveIncome Accumulated Other Comprehensive Income (219) |
122(a)(b) |
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16 |
ProprietaryCapital Total Proprietary Capital (lines 2 through 15) |
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17 |
LongTermDebtAbstract LONG-TERM DEBT |
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18 |
Bonds Bonds (221) |
256 |
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19 |
ReacquiredBonds (Less) Reaquired Bonds (222) |
256 |
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20 |
AdvancesFromAssociatedCompanies Advances from Associated Companies (223) |
256 |
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21 |
OtherLongTermDebt Other Long-Term Debt (224) |
256 |
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22 |
UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225) |
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23 |
UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226) |
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24 |
LongTermDebt Total Long-Term Debt (lines 18 through 23) |
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25 |
OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES |
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26 |
ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227) |
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27 |
AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1) |
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28 |
AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2) |
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29 |
AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3) |
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30 |
AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4) |
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31 |
AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229) |
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32 |
LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities |
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33 |
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges |
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34 |
AssetRetirementObligations Asset Retirement Obligations (230) |
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35 |
OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34) |
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36 |
CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES |
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37 |
NotesPayable Notes Payable (231) |
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38 |
AccountsPayable Accounts Payable (232) |
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39 |
NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233) |
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40 |
AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234) |
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41 |
CustomerDeposits Customer Deposits (235) |
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42 |
TaxesAccrued Taxes Accrued (236) |
262 |
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43 |
InterestAccrued Interest Accrued (237) |
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44 |
DividendsDeclared Dividends Declared (238) |
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45 |
MaturedLongTermDebt Matured Long-Term Debt (239) |
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46 |
MaturedInterest Matured Interest (240) |
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47 |
TaxCollectionsPayable Tax Collections Payable (241) |
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48 |
MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242) |
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49 |
ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243) |
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50 |
DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244) |
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51 |
LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities |
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52 |
DerivativeInstrumentLiabilitiesHedges Derivative Instrument Liabilities - Hedges (245) |
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53 |
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges (Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges |
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54 |
CurrentAndAccruedLiabilities Total Current and Accrued Liabilities (lines 37 through 53) |
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55 |
DeferredCreditsAbstract DEFERRED CREDITS |
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56 |
CustomerAdvancesForConstruction Customer Advances for Construction (252) |
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57 |
AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255) |
266 |
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58 |
DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256) |
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59 |
OtherDeferredCredits Other Deferred Credits (253) |
269 |
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60 |
OtherRegulatoryLiabilities Other Regulatory Liabilities (254) |
278 |
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61 |
UnamortizedGainOnReacquiredDebt Unamortized Gain on Reaquired Debt (257) |
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62 |
AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty Accum. Deferred Income Taxes-Accel. Amort.(281) |
272 |
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63 |
AccumulatedDeferredIncomeTaxesOtherProperty Accum. Deferred Income Taxes-Other Property (282) |
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64 |
AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283) |
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65 |
DeferredCredits Total Deferred Credits (lines 56 through 64) |
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66 |
LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65) |
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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: UnappropriatedUndistributedSubsidiaryEarnings |
(b) Concept: UnappropriatedUndistributedSubsidiaryEarnings |
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
STATEMENT OF INCOME |
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Quarterly
Annual or Quarterly if applicable
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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) |
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1 |
UtilityOperatingIncomeAbstract UTILITY OPERATING INCOME |
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2 |
OperatingRevenues Operating Revenues (400) |
300 |
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3 |
OperatingExpensesAbstract Operating Expenses |
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4 |
OperationExpense Operation Expenses (401) |
320 |
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5 |
MaintenanceExpense Maintenance Expenses (402) |
320 |
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6 |
DepreciationExpense Depreciation Expense (403) |
336 |
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|||
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 |
(a) |
(b) |
|
|
|||||||
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: |
FOOTNOTE DATA |
(a) Concept: EquityInEarningsOfSubsidiaryCompanies |
(b) Concept: EquityInEarningsOfSubsidiaryCompanies |
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 |
|||
4.1 |
AdjustmentsToRetainedEarningsCredit |
|||
4.2 |
AdjustmentsToRetainedEarningsCredit |
|||
4.3 |
AdjustmentsToRetainedEarningsCredit |
|||
4.4 |
AdjustmentsToRetainedEarningsCredit |
|||
4.5 |
AdjustmentsToRetainedEarningsCredit |
|||
4.6 |
AdjustmentsToRetainedEarningsCredit |
|||
4.7 |
AdjustmentsToRetainedEarningsCredit |
|||
4.8 |
AdjustmentsToRetainedEarningsCredit |
|||
4.9 |
AdjustmentsToRetainedEarningsCredit |
|||
4.10 |
AdjustmentsToRetainedEarningsCredit |
|||
9 |
AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439) |
|||
10 |
AdjustmentsToRetainedEarningsDebitAbstract Adjustments to Retained Earnings Debit |
|||
10.1 |
AdjustmentsToRetainedEarningsDebit |
|||
10.2 |
AdjustmentsToRetainedEarningsDebit |
|||
10.3 |
AdjustmentsToRetainedEarningsDebit |
|||
10.4 |
AdjustmentsToRetainedEarningsDebit |
|||
10.5 |
AdjustmentsToRetainedEarningsDebit |
|||
10.6 |
AdjustmentsToRetainedEarningsDebit |
|||
10.7 |
AdjustmentsToRetainedEarningsDebit |
|||
10.8 |
AdjustmentsToRetainedEarningsDebit |
|||
10.9 |
AdjustmentsToRetainedEarningsDebit |
|||
10.10 |
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) |
|||
17.1 |
AppropriationsOfRetainedEarnings |
|||
17.2 |
AppropriationsOfRetainedEarnings |
|||
17.3 |
AppropriationsOfRetainedEarnings |
|||
17.4 |
AppropriationsOfRetainedEarnings |
|||
22 |
AppropriationsOfRetainedEarnings TOTAL Appropriations of Retained Earnings (Acct. 436) |
|||
23 |
DividendsDeclaredPreferredStockAbstract Dividends Declared-Preferred Stock (Account 437) |
|||
23.1 |
DividendsDeclaredPreferredStock |
|
|
|
23.2 |
DividendsDeclaredPreferredStock |
|||
23.3 |
DividendsDeclaredPreferredStock |
|||
23.4 |
DividendsDeclaredPreferredStock |
|||
23.5 |
DividendsDeclaredPreferredStock |
|||
29 |
DividendsDeclaredPreferredStock TOTAL Dividends Declared-Preferred Stock (Acct. 437) |
|
|
|
30 |
DividendsDeclaredCommonStockAbstract Dividends Declared-Common Stock (Account 438) |
|||
30.1 |
DividendsDeclaredCommonStock |
|
||
30.2 |
DividendsDeclaredCommonStock |
|||
30.3 |
DividendsDeclaredCommonStock |
|||
30.4 |
DividendsDeclaredCommonStock |
|||
30.5 |
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) |
|
|
|
AppropriatedRetainedEarningsAbstract APPROPRIATED RETAINED EARNINGS (Account 215) |
||||
.1 |
AppropriatedRetainedEarnings |
|||
.2 |
AppropriatedRetainedEarnings |
|||
.3 |
AppropriatedRetainedEarnings |
|||
.4 |
AppropriatedRetainedEarnings |
|||
.5 |
AppropriatedRetainedEarnings |
|||
.6 |
AppropriatedRetainedEarnings |
|||
.7 |
AppropriatedRetainedEarnings |
|||
.8 |
AppropriatedRetainedEarnings |
|||
.9 |
AppropriatedRetainedEarnings |
|||
.10 |
AppropriatedRetainedEarnings |
|||
.11 |
AppropriatedRetainedEarnings |
|||
.12 |
AppropriatedRetainedEarnings |
|||
.13 |
AppropriatedRetainedEarnings |
|||
.14 |
AppropriatedRetainedEarnings |
|||
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) |
(a) |
||
50 |
EquityInEarningsOfSubsidiaryCompanies Equity in Earnings for Year (Credit) (Account 418.1) |
(b) |
(d) |
|
51 |
DividendsReceived (Less) Dividends Received (Debit) |
|||
52 |
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year |
|||
52.1 |
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits |
|||
53 |
UnappropriatedUndistributedSubsidiaryEarnings Balance-End of Year (Total lines 49 thru 52) |
(c) |
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: UnappropriatedUndistributedSubsidiaryEarnings |
(b) Concept: EquityInEarningsOfSubsidiaryCompanies |
(c) Concept: UnappropriatedUndistributedSubsidiaryEarnings |
(d) Concept: EquityInEarningsOfSubsidiaryCompanies |
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 |
|
|
|||||||||
5.2 |
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription |
|
|
|||||||||
5.3 |
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription |
|
|
|||||||||
8 |
DeferredIncomeTaxesNet Deferred Income Taxes (Net) |
|
|
|||||||||
9 |
InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net) |
|
|
|||||||||
10 |
NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables |
(a) |
(q) |
|||||||||
11 |
NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory |
(b) |
(r) |
|||||||||
12 |
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory |
(c) |
||||||||||
13 |
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses |
|
|
|||||||||
14 |
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets |
(d) |
(s) |
|||||||||
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 |
(e) |
(t) |
|||||||||
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) |
(f) |
(u) |
|||||||||
27 |
GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel |
|||||||||||
28 |
GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant |
(g) |
(v) |
|||||||||
29 |
GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant |
|||||||||||
30 |
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction |
(h) |
(w) |
|||||||||
31 |
OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote): |
|||||||||||
31.1 |
OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription |
(x) |
||||||||||
31.2 |
OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription |
(k) |
|
|||||||||
34 |
CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33) |
(l) |
(y) |
|||||||||
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 |
(m) |
(z) |
|||||||||
53.2 |
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): |
|||||||||||
66 |
NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c) |
|||||||||||
67 |
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote): |
|||||||||||
70 |
CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69) |
|||||||||||
72 |
PaymentsForRetirementAbstract Payments for Retirement of: |
|||||||||||
73 |
PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b) |
(n) |
||||||||||
74 |
PaymentsForRetirementOfPreferredStockFinancingActivities Preferred Stock |
|||||||||||
75 |
PaymentsForRetirementOfCommonStockFinancingActivities Common Stock |
|||||||||||
76 |
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities Other (provide details in footnote): |
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78 |
NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c) |
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80 |
DividendsOnPreferredStock Dividends on Preferred Stock |
(o) |
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81 |
DividendsOnCommonStock Dividends on Common Stock |
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83 |
CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81) |
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85 |
NetIncreaseDecreaseInCashAndCashEquivalentsAbstract Net Increase (Decrease) in Cash and Cash Equivalents |
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86 |
NetIncreaseDecreaseInCashAndCashEquivalents Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83) |
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88 |
CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period |
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90 |
CashAndCashEquivalents Cash and Cash Equivalents at End of Period |
(p) |
(aa) |
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: NetIncreaseDecreaseInReceivablesOperatingActivities | ||||||||||||||||||||||||||||||||||||||||||||
(b) Concept: NetIncreaseDecreaseInInventoryOperatingActivities | ||||||||||||||||||||||||||||||||||||||||||||
(c) Concept: NetIncreaseDecreaseInAllowancesInventoryOperatingActivities | ||||||||||||||||||||||||||||||||||||||||||||
(d) Concept: NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities | ||||||||||||||||||||||||||||||||||||||||||||
(e) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities | ||||||||||||||||||||||||||||||||||||||||||||
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(f) Concept: GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities | ||||||||||||||||||||||||||||||||||||||||||||
(g) Concept: GrossAdditionsToCommonUtilityPlantInvestingActivities | ||||||||||||||||||||||||||||||||||||||||||||
(h) Concept: AllowanceForOtherFundsUsedDuringConstructionInvestingActivities | ||||||||||||||||||||||||||||||||||||||||||||
(i) Concept: OtherConstructionAndAcquisitionOfPlantInvestmentActivities | ||||||||||||||||||||||||||||||||||||||||||||
(j) Concept: OtherConstructionAndAcquisitionOfPlantInvestmentActivities | ||||||||||||||||||||||||||||||||||||||||||||
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(k) Concept: OtherConstructionAndAcquisitionOfPlantInvestmentActivities | ||||||||||||||||||||||||||||||||||||||||||||
(l) Concept: CashOutflowsForPlant | ||||||||||||||||||||||||||||||||||||||||||||
(m) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities | ||||||||||||||||||||||||||||||||||||||||||||
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(n) Concept: PaymentsForRetirementOfLongTermDebtFinancingActivities | ||||||||||||||||||||||||||||||||||||||||||||
(o) Concept: DividendsOnPreferredStock | ||||||||||||||||||||||||||||||||||||||||||||
(p) Concept: CashAndCashEquivalents | ||||||||||||||||||||||||||||||||||||||||||||
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(q) Concept: NetIncreaseDecreaseInReceivablesOperatingActivities | ||||||||||||||||||||||||||||||||||||||||||||
(r) Concept: NetIncreaseDecreaseInInventoryOperatingActivities | ||||||||||||||||||||||||||||||||||||||||||||
(s) Concept: NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities | ||||||||||||||||||||||||||||||||||||||||||||
(t) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities | ||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||
(u) Concept: GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities | ||||||||||||||||||||||||||||||||||||||||||||
(v) Concept: GrossAdditionsToCommonUtilityPlantInvestingActivities | ||||||||||||||||||||||||||||||||||||||||||||
(w) Concept: AllowanceForOtherFundsUsedDuringConstructionInvestingActivities | ||||||||||||||||||||||||||||||||||||||||||||
(x) Concept: OtherConstructionAndAcquisitionOfPlantInvestmentActivities | ||||||||||||||||||||||||||||||||||||||||||||
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(y) Concept: CashOutflowsForPlant | ||||||||||||||||||||||||||||||||||||||||||||
(z) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities | ||||||||||||||||||||||||||||||||||||||||||||
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(aa) Concept: CashAndCashEquivalents | ||||||||||||||||||||||||||||||||||||||||||||
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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: |
NOTES TO FINANCIAL STATEMENTS |
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Niagara Mohawk Power Corporation (“the Company”), a New York Corporation, is engaged principally in the regulated energy delivery business in New York State (“NYS”). The Company provides electric service to approximately 1.8 million customers in the areas of eastern, central, northern, and western New York and sells, distributes, and transports natural gas to approximately 0.6 million customers in the areas of central, northern, and eastern New York.
The Company is a wholly-owned subsidiary of Niagara Mohawk Holdings, Inc. (“NMHI”), which is a wholly-owned subsidiary of National Grid USA (“NGUSA”), a public utility holding company with regulated subsidiaries engaged in the generation of electricity and the transmission, distribution, and sale of both natural gas and electricity. NGUSA is a direct wholly-owned subsidiary of National Grid North America Inc. and an indirect wholly-owned subsidiary of National Grid plc, a public limited company incorporated under the laws of England and Wales.
The accompanying financial statements are unaudited and prepared in accordance with the accounting requirements of the Federal Energy Regulatory Commission (“FERC”) as set forth in its applicable Uniform System of Accounts. This is a comprehensive basis of accounting other than accounting principles generally accepted in the United States of America (“U.S. GAAP”). The primary differences consist of the following:
Supplemental Cash Flow Information
In the opinion of management, the financial statements as of September 30, 2018, and for the three months and nine months ended September 30, 2018 and 2017, include all adjustments (consisting of normal recurring accruals) necessary for the fair statement of the financial position, results of operations, and cash flows for the periods presented. The results of operations for the three months and nine months ended September 30, 2018 and 2017 are not necessarily indicative of the results to be expected for the full year or any other period.
The Company has evaluated subsequent events and transactions through November 29, 2018, the date of issuance of these financial statements, and concluded that there were no events or transactions that require adjustment to, or disclosure in, the financial statements as of and for the three months and nine months ended September 30, 2018.
Use of Estimates
In preparing financial statements that conform to FERC requirements, the Company must make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities included in the financial statements. Actual results could differ from those estimates.
Regulatory Accounting
The FERC and the New York Public Service Commission (“NYPSC”) regulate the rates the Company charges its customers. In certain cases, the rate actions of the FERC and NYPSC can result in accounting that differs from non-regulated companies. In these cases, the Company defers costs (as regulatory assets) or recognizes obligations (as regulatory liabilities) if it is probable that such amounts will be recovered from, or refunded to, customers through future rates. Regulatory assets and liabilities are reflected on the balance sheet consistent with the treatment of the related costs in the ratemaking process.
Revenue Recognition
Revenues are recognized for energy service provided on a monthly billing cycle basis. The Company records unbilled revenues for the estimated amount of services rendered from the time meters were last read to the end of the accounting period.
As approved by the NYPSC, the Company is allowed to pass through commodity-related costs to customers and also bills for approved rate adjustment mechanisms. In addition, the Company has separate revenue decoupling mechanisms for gas and electric which allow for annual adjustments to the Company’s delivery rates as a result of the reconciliation between allowed revenue and billed revenue. Any difference between the allowed revenue and the billed revenue is recorded as a regulatory asset or regulatory liability.
Transmission Formula Rate
The Company’s wholesale transmission service charge (“TSC”) rates are established based on a FERC-approved formula. The Company is required to make an informational filing annually to update certain components of the TSC formula rate. The revenue requirement component of the annual formula rate update is based on prior year actual costs and current year projected capital additions. The update also reconciles any differences between the revenue requirement in effect in the prior year and the actual revenue requirement for that year.
Cash and Cash Equivalents
Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less. Cash and cash equivalents are carried at cost which approximates fair value.
Special Deposits
Special deposits primarily consist of collateral paid to the Company’s counterparties for outstanding derivative instruments, a release of property account for mortgaged property under a mortgage trust indenture, and a reserve for potential environmental violations.
Accounts Receivable and Accumulated Provision for Uncollectible Accounts
The Company recognizes an accumulated provision for uncollectible accounts to record accounts receivable at estimated net realizable value. The provision is determined based on a variety of factors including, for each type of receivable, applying an estimated reserve percentage to each aging category, taking into account historical collection and write-off experience and management's assessment of collectability from individual customers as appropriate. The collectability of receivables is continuously assessed and, if circumstances change, the provision is adjusted accordingly. Receivable balances are written off against the provision for uncollectible accounts when the accounts are disconnected and/or terminated and the balances are deemed to be uncollectible.
Plant Materials and Operating Supplies and Gas Stored Underground
Plant materials and operating supplies are stated at weighted average cost, which represents net realizable value, and are expensed or capitalized as used. The Company’s policy is to write-off obsolete plant materials and operating supplies; there were no material write-offs of obsolete plant materials and operating supplies for the nine months ended September 30, 2018 or 2017.
Gas stored underground is stated at weighted average cost and the related cost is recognized when delivered to customers. Existing rate orders allow the Company to pass directly through to customers the cost of gas purchased, along with any applicable authorized delivery surcharge adjustments. Gas costs passed through to customers are subject to regulatory approvals and are audited annually by the NYPSC.
Derivative Instruments
The Company uses various derivative instruments to manage commodity price risk. All derivative instruments, except those that qualify for the normal purchase normal sale exception, are recorded on the balance sheet at their fair value. All commodity costs, including the impact of derivative instruments, are passed on to customers through the Company’s commodity rate adjustment mechanisms. Therefore, gains or losses on the settlement of these contracts are initially deferred and then refunded to, or collected from, customers consistent with regulatory requirements.
The Company has certain non-trading instruments for the physical purchase of electricity that qualify for the normal purchase normal sale exception and are accounted for upon settlement. If the Company were to determine that a contract no longer qualifies for the normal purchase normal sale exception, then the Company would recognize the fair value of the contract in accordance with the regulatory accounting described above.
The Company’s accounting policy is to not offset fair value amounts recognized for derivative instruments and related cash collateral receivable or payable with the same counterparty under a master netting agreement, but rather to record and present the fair value of the derivative instrument on a gross basis, with related cash collateral recorded within special deposits on the balance sheet.
Fair Value Measurements
The Company measures derivative instruments and available-for-sale securities at fair value. Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The following is the fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value:
The asset or liability’s fair value measurement level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. The Company uses valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.
Available-For-Sale Securities
The Company provides certain executives with nonqualified retirement and deferred compensation benefits which have been partially secured through separate fund arrangements. As a result, the Company holds available-for-sale securities that include equities, municipal bonds, and corporate bonds. These investments are recorded at fair value and are included in other special funds on the balance sheet. Changes in the fair value of these assets are recorded within other comprehensive income.
Asset Retirement Obligations Asset retirement obligations are recognized for legal obligations associated with the retirement of utility plant, primarily associated with the Company’s distribution facilities. Asset retirement obligations are recorded at fair value in the period in which the obligation is incurred, if the fair value can be reasonably estimated. In the period in which new asset retirement obligations, or changes to the timing or amount of existing retirement obligations are recorded, the associated asset retirement costs are capitalized as part of the carrying amount of the related long-lived asset. In each subsequent period the asset retirement obligation is accreted to its present value. The Company applies regulatory accounting guidance and both the depreciation and accretion costs associated with asset retirement obligation are recorded as increases to regulatory assets on the balance sheet. These regulatory assets represent timing differences between the recognition of costs in accordance with FERC reporting and costs recovered through the ratemaking process.
The following table represents the changes in the Company’s asset retirement obligations:
The Company had a current portion of asset retirement obligations of $0.4 million included in miscellaneous current and accrued liabilities on the balance sheet at September 30, 2018.
New and Recent Accounting Guidance
Accounting Guidance Recently Adopted
Employee Share-Based Payment Accounting
In March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-09, "Improvements to Employee Share-Based Payment Accounting (Topic 718)," which simplifies several aspects of the accounting for share-based payment transactions, including the accounting for income taxes, forfeitures and statutory tax withholding requirements, as well as classification in the statement of cash flows. Most notably, entities are required to recognize all excess tax benefits and shortfalls as income tax expense or benefit in the income statement within the reporting period in which they occur. The application of this guidance did not have a material impact on the results of operations, cash flows, or financial position of the Company.
Goodwill
In January 2017, the FASB issued ASU No. 2017-04, “Intangibles—Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment,” which eliminates Step 2 from the goodwill impairment test. For the Company, the requirements of the new standard will be effective for the fiscal year ended March 31, 2022, with early adoption permitted. The Company early adopted the ASU in the year ended March 31, 2018 for its annual goodwill impairment testing. Based on the resulting fair value from the annual analyses, the Company determined that no adjustment to the goodwill carrying value was required.
Derivatives and Hedging
In March 2016, the FASB issued ASU No. 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships.” This update clarifies that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Accounting Standards Codification (“ASC”) 815, “Derivatives and Hedging,” does not require dedesignation of that hedging relationship provided that all other hedge accounting criteria in accordance with ASC 815-20-35 through ASC 815-35-18 continue to be met. The application of this guidance did not have a material impact on the results of operations, cash flows, or financial position of the Company.
Pension and Postretirement Benefits
In March 2017, the FASB issued ASU No. 2017-07, “Compensation Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” which changes certain presentation and disclosure requirements for employers that sponsor defined benefit pension and other postretirement benefit plans. For U.S. GAAP reporting, the ASU requires the service cost component of the net benefit cost to be in the same line item as other compensation in operating income and the other components of net benefit cost to be presented outside of operating income on a retrospective basis. For FERC reporting purposes, all costs will continue to be reported in operating expenses. In addition, only the service cost component will be eligible for capitalization when applicable, on a prospective basis. For the Company, the requirements of the new standard are effective for the current fiscal year ending March 31, 2019 and interim periods therein. The application of the new guidance did not have a material impact on the results of the Company’s operations, cash flows, and financial position since the Company defers the difference between actual pension costs and the amounts used to establish rates (See Note 8, “Employee Benefits” for additional details).
Statement of Cash Flows
In November 2016, the FASB issued ASU No. 2016-18, "Statement of Cash Flows (Topic 230): Restricted Cash (a consensus of the FASB Emerging Issues Task Force)," which requires entities to show the changes in the total of cash, cash equivalents, restricted cash, and restricted cash equivalents in the statement of cash flows.
In August 2016, the FASB issued ASU No. 2016-15, "Classification of Certain Cash Receipts and Cash Payments (Topic 230)," which provides guidance about the classification of certain cash receipts and payments within the statement of cash flows, including debt prepayment or extinguishment costs, contingent consideration payments made after a business combination, proceeds from the settlement of insurance claims and policies, and distributions received from equity method investments.
Both accounting updates are in effect for the current fiscal year ending March 31, 2019 and interim periods therein. The application of ASU No. 2016-18 resulted only in a change in presentation on the Company’s statement of cash flows. Movements in restricted cash were previously included as investing activities. The application of ASU No. 2016-15 did not have a material impact on the Company’s cash flows.
Income Taxes
In October 2016, the FASB issued ASU No. 2016-16, "Income Taxes (Topic 740): IntraEntity Transfers of Assets Other Than Inventory," which eliminates the exception for all intra-entity sales of assets other than inventory. As a result, a reporting entity would recognize the tax expense from the sale of the asset in the seller’s tax jurisdiction when the transfer occurs, even though the pre-tax effects of that transaction are eliminated in consolidation. For the Company, the requirements of the new standard are effective for the current fiscal year ending March 31, 2019 and interim period therein. The application of this guidance did not have a material impact on the results of operations, cash flows, or financial position of the Company.
Revenue Recognition
In May 2014, the FASB issued ASU No. 2014-09: “Revenue from Contracts with Customers (Topic 606).” The underlying principle of this ASU is that an entity will recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration the entity expects to be entitled to, in exchange for those goods or services. For the Company, the new guidance is effective for the fiscal year ending March 31, 2019 and interim periods therein, and was adopted using a modified retrospective approach.
The FASB has issued a number of additional recent ASUs related to revenue recognition, whose effective date and transition requirements are the same as those for ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” In March 2016, the FASB issued ASU No. 2016-08, “Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net),” which clarifies the implementation guidance on principal versus agent considerations. In April 2016, the FASB issued ASU No. 2016-10, "Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing," which provides guidance in the new revenue standard on identifying performance obligations and accounting for licenses of intellectual property. In May 2016, the FASB issued ASU No. 2016-12, “Revenue from Contracts with Customers (Accounting Standards Codification (“ASC”) 606) Narrow-Scope Improvements and Practical Expedients,” providing additional clarity on various aspects of Topic 606, including a) Assessing the Collectability Criterion and Accounting for Contracts That Do Not Meet the Criteria for Step 1, b) Presentation of Sales Taxes and Other Similar Taxes Collected from Customers, c) Noncash Consideration, d) Contract Modifications at Transition, e) Completed Contracts at Transition, and f) Technical Correction. Lastly, in December 2016, the FASB issued ASU No. 2016-20, "Technical Corrections and Improvements to Topic 606, Revenue from Contracts with Customers." The amendments in this update cover a variety of corrections and improvements to the Codification related to the new revenue recognition standard (ASU No. 2014-09).
The Company performed detailed reviews of its revenue arrangements to ensure compliance with the new standard effective for the current fiscal year ending March 31, 2019 and interim periods therein. The adoption of ASC 606 did not have a material impact on the presentation of the Company’s results of operations, cash flows, or financial position. However, the Company has added additional qualitative and quantitative financial statement disclosures per requirements under ASC 606 pertaining to its revenue earning mechanisms (See Note 3, “Revenue” for additional details).
Stock Compensation
In May 2017, the FASB issued ASU No. 2017-09, “Stock Compensation (Topic 718): Scope of Modification Accounting,” which provides clarity on the application of modification accounting upon a change to the terms or conditions of a share-based payment award. The Company early adopted the ASU in the year ended March 31, 2018. The application of this guidance did not have a material impact on the results of operations, cash flows, or financial position of the Company.
Accounting Guidance Not Yet Adopted
Financial Instruments – Credit Losses
In June 2016, the FASB issued ASU No. 2016-13, "Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments." The amendment replaces the incurred loss impairment methodology in current U.S. GAAP with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. For the Company, the requirements of the new standard will be effective for the fiscal year ending March 31, 2022, and interim periods therein, with early adoption permitted from the fiscal year ending March 31, 2019 and interim periods therein. The Company is currently evaluating the impact of the new guidance on the presentation, results of its operations, cash flows, and financial position.
Upon the adoption of ASC Topic 606, revenue is measured based on the consideration specified in a contract with a customer and excludes amounts collected on behalf of third parties. The Company recognizes revenue when it transfers control over a product or service to a customer.
Nature of Goods and Services
The following is a description of principal activities – separated by reportable segments – from which the Company generates its revenue.
Transmission The Transmission segment of the Company principally generates revenue from providing the services/products shown in further detail below. Transmission systems generally include overhead lines, underground cables and substations, connecting generation and interconnectors to the distribution system. The Company owns, maintains, and operates an electricity transmission system spanning upstate New York. The Company’s transmission services are regulated by both the New York Independent System Operator and by the FERC in respect of interstate transmission.
Distribution
The Distribution segment of the Company principally generates revenue from providing the services/products shown in further detail below. The distribution revenues are primarily associated with cancellable contracts with the exception of certain long-term contracts with commercial and industrial customers. The Company’s distribution services are regulated by the NYPSC.
Other Activities The Other Activities segment of the Company and the revenues generated from it are shown in further detail below.
Disaggregation of Revenue
In the following table, revenue is disaggregated by major products and services.
The Company records regulatory assets and liabilities that result from the ratemaking process. The following table presents the regulatory assets and regulatory liabilities recorded on the balance sheet:
Carrying charges: The Company records carrying charges on regulatory balances for which cash expenditures have been made and are subject to recovery, or for which cash has been collected and is subject to refund. Carrying charges are not recorded on items for which expenditures have not yet been made.
Derivative instruments: The Company evaluates open derivative instruments for regulatory deferral by determining if they are probable of recovery from, or refund to, customers through future rates. Derivative instruments that qualify for recovery are recorded at fair value, with changes in fair value recorded as regulatory assets or regulatory liabilities in the period in which the change occurs.
Dunkirk settlement deferral: The Company is allowed to defer up to $57 million to offset the Reliability Support Services (“RSS”) associated with the Dunkirk generating plant and RSS agreements with other generators. This is an on-going deferral mechanism. The timing for disposition of any associated deferred balances will be determined by future NYPSC rulings.
Economic development fund: Represents a deferral mechanism for economic development discounts. Under this mechanism, the Company reconciles the economic discounts provided to customers to the amount reflected in rates for future refund to, or recovery from, customers. This is an on-going deferral mechanism. The timing for disposition of any associated deferred balances will be determined by future NYPSC rulings.
Energy efficiency: An asset or liability is recognized resulting from the difference between revenue billed to customers through the Company’s energy efficiency charge and the costs of the Company’s energy efficiency programs as approved by the NYPSC.
Environmental response costs: The regulatory asset represents deferred costs associated with the Company’s share of the estimated costs to investigate and perform certain remediation activities at sites with which it may be associated. The Company’s rate plans provide for specific rate allowances for these costs at a level of $32.1 million per year, with variances deferred for future recovery from, or return to, customers. The Company believes future costs, beyond the expiration of current rate plans, will continue to be recovered through rates. The regulatory liability represents the excess of amounts received in rates over the Company’s actual site investigation and remediation costs.
Gas costs adjustment: The Company is subject to rate adjustment mechanisms for commodity costs, whereby an asset or liability is recognized resulting from differences between actual revenues and the underlying cost being recovered or differences between actual revenues and targeted amounts as approved by the NYPSC. These amounts will be refunded to, or recovered from, customers over the next year.
Long-term debt true-up: The Company has a mechanism whereby it reconciles the actual interest expense and other debt costs related to its variable rate debt with the amount reflected in rates ($22 million for electric and $5.5 million for gas). The Company defers any over or under recoveries for future refund to, or recovery from, customers. This is an on-going deferral mechanism. The timing for disposition of any associated deferred balances will be determined by future NYPSC rulings.
Postretirement benefits: The regulatory asset represents the Company’s deferral related to the underfunded status of its pension and PBOP plans. The regulatory liability primarily represents the excess of amounts received in rates over actual costs of the Company’s pension and PBOP plans to be refunded in future periods.
Rate adjustment mechanisms: In addition to commodity costs, the Company is subject to a number of additional rate adjustment mechanisms whereby an asset or liability is recognized resulting from differences between actual revenues and the underlying cost being recovered or differences between actual revenues and targeted amounts as approved by the NYPSC.
Regulatory tax asset/liability, net: Represents over-recovered federal and state deferred taxes of the Company primarily as a result of regulatory flow through accounting treatment and state income tax rate changes and excess federal deferred taxes as a result of the recently enacted Tax Cuts and Jobs Act (“Tax Act”).
Storm costs: The Joint Proposal (NMPC rate proceeding Case 12-E-0201) established an annual allowance for major storm recovery of $29 million in each of the three fiscal years ended March 31, 2016. The NYPSC allowed for the continuation of this allowance in Case 15-M-0744 for the two fiscal years ended March 31, 2018. The Company deferred the difference between the base rate allowance and actual major storm incremental costs for future refund to, or recovery from, customers. Under the new NMPC rate case (Case 17-E-0238), the annual allowance for major storm recovery will be $23 million for the three fiscal years ending March 31, 2021 and a per storm deferral threshold of $0.4 million was established. At December 31, 2017, the regulatory liability represents the cumulative storm reserve allowance/funding for major storm incremental costs and the regulatory asset represents the cumulative incremental costs incurred for qualified storm events. At September 30, 2018, these amounts have been reported net.
Electric and Gas Filing
On April 28, 2017, the Company filed a proposal to reset electric and natural gas delivery prices beginning in April 2018. On January 19, 2018, the Company reached a settlement agreement with the NYPSC Staff and other parties to the case and filed a Joint Proposal for a three-year rate plan. The proposal reflects the new federal tax law changes and provides a cumulative revenue requirement increase of $240.8 million and $60.8 million for the electric and gas business, respectively, based on a 9.0% return on equity and 48% common equity ratio. On March 15, 2018, the NYPSC issued a final order approving the Joint Proposal and the new rates took effect on April 1, 2018.
As of March 31, 2018, resulting from the Joint Proposal, a new electric rate plan settlement credit of $44.9 million and a new gas rate plan settlement credit of $28.4 million were established. The Company applied $38.4 million of existing regulatory liabilities towards the creation of these credits.
Tax Act
On March 15, 2018, the FERC initiated multiple proceedings intended to adjust FERC-jurisdictional rates to reflect the corporate tax changes as a result of the passage of the Tax Act. Of the proceedings initiated relevant to the Company is the Notice of Inquiry (“NOI”) seeking comments on the effects of the Tax Act on all FERC-jurisdiction rates. This NOI will be used by the FERC to build a record on the tax issues affecting FERC-jurisdictional rates and will be used to determine whether additional action by the FERC is needed.
In response to the Tax Act signed into law on December 22, 2017, the NYPSC issued an Order Instituting Proceeding under Case 17-M-0815 - Proceeding on Motion of the Commission on Changes in Law that May Affect Rates. This proceeding was instituted to solicit comments on the Tax Act’s implications and places the utilities on notice of the NYPSC’s intent to protect ratepayers’ interest and to ensure that any cost reductions from the changes in federal income taxes are deferred for future ratepayer benefit. On March 29, 2018, the NYPSC Staff released its proposal to address accounting and ratemaking related to the Tax Act. Comments on NYPSC Staff’s proposal were filed June 27, 2018.
On August 9, 2018, the NYPSC issued an order in its generic proceeding considering the impacts of federal tax reform. NYPSC Staff had advocated that all New York utilities implement a sur-credit by October 1st that would reflect the immediate effects of the Tax Act and also return any deferred benefits to customers. In response, the Company filed a proposal to (i) delay any sur-credit to January 1st to offset scheduled rate increases and (ii) retain any deferred benefits, including accumulated deferred federal income taxes (“ADFIT”), for future rate moderation.
The NYPSC’s order effectively approved all aspects of the Company’s proposal. The NYPSC agreed that the Company should be allowed to defer both the pass back of calendar year 2018 tax savings (to the extent not already returned in the new rate plan) and the amortization of excess ADFIT balances, and use the benefits as a rate moderator when base rates are next revised in 2020/2021. Specifically the NYPSC directed that no sur-credit is required as the current rate plan already reflects the reduction of the tax rate to 21% and the termination of bonus depreciation. The NYPSC approved the Company’s proposal to defer the tax benefit realized for the three-month period (January-March) prior to new rates, of $18.0 million for electric and $4.6 million for gas, to offset future rate increases or investments. Projected balances of $620 million of electric ADFIT and $129 million of gas ADIT and unprotected electric ADFIT of $76 million and unprotected gas ADFIT of $14 million will be deferred for future disposition in rate proceedings.
Operations Staffing Audit
In January 2014, the NYPSC initiated an operational audit to review internal staffing levels and use of contractors for the core utility functions of the investor owned utilities operating in New York, including the Company. On June 26, 2014, the NYPSC selected a third party to conduct the audit. On February 21, 2017, the third party submitted its final report, which contained recommendations for all of National Grid’s New York utilities designed to improve the staffing and workforce management processes. The report contained 27 recommendations for National Grid. The Company filed its implementation plan on March 23, 2017. On December 15, 2017, the NYPSC issued an Order approving the Company’s implementation plan without modification, with updates to be made every four months to the NYPSC on the status of implementation. The Company submitted its most recent update on August 15, 2018.
New York Management Audit
In 2018, the NYPSC initiated a comprehensive management and operations audit of National Grid’s three New York electric and gas utilities. New York law requires periodic management audits of all utilities at least once every five years. National Grid last underwent a New York management audit in 2014/2015, when the NYPSC audited our New York gas business. The audit will be process oriented and forward looking, and presents opportunities to obtain feedback on how to improve service to customers and meet regulatory expectations. Areas of focus will include the traditional audit areas of corporate governance, budgeting and finance, customer, work management, and long-term planning, as well as organization design, information systems, gas safety, and grid modernization.
The Company utilizes derivative instruments to manage commodity price risk associated with its natural gas and electricity purchases. The Company’s commodity risk management strategy is to reduce fluctuations in firm gas and electricity sales prices to its customers.
The Company’s financial exposures are monitored and managed as an integral part of the Company’s overall financial risk management policy. The Company engages in risk management activities only in commodities and financial markets where it has an exposure, and only in terms and volumes consistent with its core business.
Volumes
Volumes of outstanding commodity derivative instruments measured in dekatherms (“dths”) and megawatt hours (“mwhs”) are as follows:
Amounts Recognized on the Balance Sheet
The changes in fair value of the Company’s rate recoverable contracts are offset by changes in regulatory assets and liabilities. As a result, the changes in fair value of those contracts had no impact in the accompanying statements of income. All of the Company’s derivative instruments are subject to rate recovery as of September 30, 2018 and December 31, 2017.
Credit and Collateral
The Company is exposed to credit risk related to transactions entered into for commodity price risk management. Credit risk represents the risk of loss due to counterparty non-performance. Credit risk is managed by assessing each counterparty’s credit profile and negotiating appropriate levels of collateral and credit support.
The credit policy for commodity transactions is managed and monitored by the Finance Committee to National Grid plc’s Board of Directors (“Finance Committee”), which is responsible for approving risk management policies and objectives for risk assessment, control and valuation, and the monitoring and reporting of risk exposures. NGUSA’s Energy Procurement Risk Management Committee (“EPRMC”) is responsible for approving transaction strategies, annual supply plans, and counterparty credit approval, as well as all valuation and control procedures. The EPRMC is chaired by the Vice President of U.S. Treasury and reports to both the NGUSA Board of Directors and the Finance Committee.
The EPRMC monitors counterparty credit exposure and appropriate measures are taken to bring such exposures below the limits, including, without limitation, netting agreements, and limitations on the type and tenor of trades. The Company enters into enabling agreements that allow for payment netting with its counterparties, which reduce its exposure to counterparty risk by providing for the offset of amounts payable to the counterparty against amounts receivable from the counterparty. In instances where a counterparty’s credit quality has declined, or credit exposure exceeds certain levels, the Company may limit its credit exposure by restricting new transactions with the counterparty, requiring additional collateral or credit support, and negotiating the early termination of certain agreements. Similarly, the Company may be required to post collateral to its counterparties.
The Company’s credit exposure for all commodity derivative instruments, normal purchase normal sale contracts, and applicable payables and receivables, net of collateral, and instruments that are subject to master netting agreements, was an asset of $7.4 million and a liability of $12.5 million as of September 30, 2018 and December 31, 2017, respectively.
The aggregate fair value of the Company’s commodity derivative instruments with credit-risk-related contingent features that were in a liability position at September 30, 2018 and December 31, 2017 was $2.5 million and $24.7 million, respectively. The Company had zero and $8.8 million collateral posted for these instruments at September 30, 2018 and December 31, 2017, respectively. At September 30, 2018, if the Company’s credit rating were to be downgraded by one or two levels it would be required to post no additional collateral to its counterparties and if the Company’s credit rating were to be downgraded by three levels it would be required to post additional collateral to its counterparties of $3.1 million. At December 31, 2017, if the Company’s credit rating had been downgraded by one, two, or three levels, it would have been required to post additional collateral to its counterparties of zero, $1.3 million, or $20.2 million, respectively.
Offsetting Information for Derivative Instruments Subject to Master Netting Arrangements
The following tables present assets and liabilities measured and recorded at fair value on the balance sheet on a recurring basis and their level within the fair value hierarchy as of September 30, 2018 and December 31, 2017:
Derivative instruments: The Company’s Level 2 fair value derivative instruments primarily consist of over-the-counter (“OTC”) electric and gas swap contracts with pricing inputs obtained from the New York Mercantile Exchange and the Intercontinental Exchange (“ICE”), except in cases where the ICE publishes seasonal averages or where there were no transactions within the last seven days. The Company may utilize discounting based on quoted interest rate curves, including consideration of non-performance risk, and may include a liquidity reserve calculated based on bid/ask spread for the Company’s Level 2 derivative instruments. Substantially all of these price curves are observable in the marketplace throughout at least 95% of the remaining contractual quantity, or they could be constructed from market observable curves with correlation coefficients of 95% or higher.
The Company’s Level 3 fair value derivative instruments consist of gas option and purchase, and electric option and capacity transactions, which are valued based on internally-developed models. Industry-standard valuation techniques, such as the Black-Scholes pricing model, Monte Carlo simulation, and Financial Engineering Associates libraries are used for valuing such instruments. A derivative is designated Level 3 when it is valued based on a forward curve that is internally developed, extrapolated, or derived from market observable curves with correlation coefficients less than 95%, where optionality is present, or if non-economic assumptions are made.
Available-for-sale securities: Available-for-sale securities are included in other special funds on the balance sheet and primarily include equity and debt investments based on quoted market prices (Level 1) and municipal and corporate bonds based on quoted prices of similar traded assets in open markets (Level 2).
Changes in Level 3 Derivative Instruments
A transfer into Level 3 represents existing assets or liabilities that were previously categorized at a higher level for which the inputs became unobservable during the period. A transfer out of Level 3 represents assets and liabilities that were previously classified as Level 3 for which the inputs became observable based on the criteria discussed previously for classification in Level 2. These transfers, which are recognized at the end of each period, result from changes in the observability of forward curves from the beginning to the end of each reporting period. There were no transfers between Level 1 and Level 2, and no transfers into or out of Level 3, during the nine months ended September 30, 2018 or 2017. For valuations that include both observable and unobservable inputs, if the unobservable input is determined to be significant to the overall inputs, the entire valuation is categorized in Level 3. This includes derivative instruments valued using indicative price quotations whose contract tenure extends into unobservable periods. In instances where observable data is unavailable, consideration is given to the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility, and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable. The Company considers non-performance risk and liquidity risk in the valuation of derivative instruments categorized in Level 2 and Level 3.
Quantitative Information About Level 3 Fair Value Measurements
The following tables provide information about the Company’s Level 3 valuations:
The significant unobservable inputs listed above would have a direct impact on the fair values of the Level 3 instruments if they were adjusted. The significant unobservable inputs used in the fair value measurement of the Company’s gas option derivative instruments and electric option and swap derivative instruments are implied volatility and gas forward curves. A relative change in commodity price at various locations underlying the open positions can result in significantly different fair value estimates.
Other Fair Value Measurements
The Company’s balance sheet reflects long-term debt at amortized cost. The fair value of the Company’s long-term debt was based on quoted market prices when available, or estimated using quoted market prices for similar debt. The fair value of this debt at September 30, 2018 and December 31, 2017 was $2.8 billion and $2.9 billion, respectively.
All other financial instruments on the balance sheet such as accounts receivable, accounts payable, and notes receivable from and payable to associated companies are stated at cost, which approximates fair value.
The Company participates in two non-contributory defined benefit pension plans (the “Pension Plans”) and two PBOP plans (the “PBOP Plans,” together with the Pension Plans, the “Plans”). The Company calculates benefits under these plans based on age, years of service and pay using March 31 as a measurement date. In addition, the Company also participates in defined contribution plans for eligible employees. The plans are sponsored by National Grid USA Service Company.
Plan assets are maintained in commingled trusts. In respect of cost determination, plan assets are allocated to the Company based on the Company’s proportionate share of the Plan’s projected benefit obligation. The Plan’s costs are first directly charged to the Company based on the Company’s employees that participate in the Plan. Costs associated with affiliated service companies’ employees are then allocated as part of the labor burden for work performed on the Company’s behalf. The Company applies deferral accounting for pension and PBOP expenses associated with its regulated gas and electric operations. Any differences between actual pension costs and amounts used to establish rates are deferred and collected from, or refunded to, customers in subsequent periods. Pension and PBOP expense are included within operation expenses in the accompanying statements of income. Portions of the net periodic benefit costs disclosed below have been capitalized as a component of property, plant and equipment.
Pension Plans
The Pension Plans are composed of both a qualified and a non-qualified plan. The qualified pension plan provides substantially all union employees, as well as all non-union employees hired before January 1, 2011, with a retirement benefit. The qualified pension plan is a cash balance pension plan design in which pay-based credits are applied based on service time and interest credits are applied at rates set forth in the plan. For non-union employees, effective January 1, 2011, pay-based credits are based on a combination of service time and age. The non-qualified pension plans provide additional defined pension benefits to certain eligible executives. The funding policy is determined largely by the Company’s rate agreements with the NYPSC. However, the contribution to the qualified pension plan for any year will not be less than the minimum amount required under Internal Revenue Service regulations.
PBOP Plans
The Company’s PBOP Plans provide health care and life insurance coverage to eligible retired employees. Eligibility is based on age and length of service requirements and, in most cases, retirees must contribute to the cost of their coverage. The PBOP Plans are funded based on rate agreements with the NYPSC.
ASU 2017-07
In March 2017, the FASB issued guidance that required the service costs of net periodic benefit costs be disaggregated from the other components of net periodic benefit costs with the remaining components presented outside of operating income and no longer subject to capitalization. In December 2017, the FERC issued guidance to all jurisdictional entities to ensure proper and consistent application of the FERC’s accounting requirements over pension and PBOP costs in response to ASU No. 2017-07 for FERC financial reporting purposes. The guidance required all jurisdictional public utilities and licensees, natural gas companies, and centralized service companies should continue to record pension and PBOP costs in their entirety in operation expenses. Further, the FERC allowed a one-time election to adopt the new FASB capitalization guidance for regulatory filing purposes.
The NYPSC adopted the provisions of ASU No. 2017-07 in Case 17-M-0363 as it relates to not capitalizing non-service components of pension/PBOP costs. The Company adopted ASU No. 2017-07 for its fiscal year beginning April 1, 2018 for both regulatory filing and U.S. GAAP reporting purposes.
Components of Net Periodic Benefit Costs
The following table presents the components of net periodic benefit cost, prior to capitalization and deferral accounting, for the three months and nine months ended September 30, 2018 and 2017:
Debt Authorizations
Since January 12, 2015, the Company had regulatory approval from the FERC to issue up to $1 billion of short-term debt internally or externally. The authorization was renewed and is effective for a period of two years that expires on January 10, 2019. The Company had no external short-term debt as of September 30, 2018 and December 31, 2017. Refer to Note 12, “Related Party Transactions” under “Notes Receivable from and Notes Payable to Associated Companies (“Intercompany Money Pool”)” for short-term debt outstanding to associated companies.
Since May 19, 2016, the NYPSC authorized the Company to issue up to $2.1 billion of incremental long-term debt in one or more transactions through March 31, 2020. The Company can issue up to $429.5 million of the total authorization for optional refunding of existing debt.
State Authority Financing Bonds
The assets of the Company are subject to liens and other charges and are provided as collateral over borrowings of $424.2 million and $429.5 million of State Authority Financing Bonds at September 30, 2018 and December 31, 2017, respectively. These bonds were issued to secure a like amount of tax-exempt revenue bonds issued by the New York State Energy Research and Development Authority (“NYSERDA”). The bonds bear interest at short-term adjustable interest rates (with an option to convert to other rates, including a fixed interest rate) ranging from 0.72% to 5.53% and 1.56% to 3.10% for the nine months ended September 30, 2018 and 2017, respectively. The bonds are currently in auction rate mode and are backed by bond insurance. These bonds cannot be put back to the Company and, in the case of a failed auction, the resulting interest rate on the bonds would revert to the maximum auction rate which depends on the current appropriate, short-term benchmark rate and the senior unsecured rating of the Company or the bond insurer, whichever is greater. The effect on interest on long-term debt has not been material in the nine months ended September 30, 2018 or 2017. As of the date of issuance of these financial statements, the Company had converted all eight series of the State Authority Financing Bonds from a variable rate into a fixed rate.
Advances from Associated Companies
The Company has board authorization to borrow up to $500 million from NGUSA and $450 million from NMHI as deemed necessary for working capital needs. At September 30, 2018 and December 2017, the Company had no outstanding advances from associated companies.
Dividend Restrictions
The Company’s debt and credit arrangements contain various financial and other covenants as described below. The Company was in compliance with all such covenants at September 30, 2018.
The indenture securing the Company’s mortgage debt provides that retained earnings shall be reserved and held unavailable for the payment of dividends on common stock to the extent that expenditures for maintenance and repairs plus provisions for depreciation do not exceed 2.25% of depreciable property as defined therein. These provisions have never resulted in a restriction of the Company’s retained earnings.
The Company is limited by the various rate plans, NYPSC orders, and FERC orders with respect to the amount of dividends the Company can pay. If the Company’s total debt exceeds 55% of its total capital excluding goodwill but does not exceed 57%, then the Company will be permitted to pay dividends up to an amount equal to but no greater than 50% of its net income for the previous twelve months until its average total debt for the most recent six month period is less than or equal to 55%. If the Company’s total capital exceeds 57% then the Company may not pay dividends until the average total debt for the most recent six months ending is less than or equal to 55%. As long as the bond ratings on the least secure forms of debt issued by the Company and National Grid plc remain investment grade and do not fall to the lowest investment grade rating (with one or more negative watch downgrade notices issued with respect to such debt), the Company is allowed to pay dividends.
The Company’s filed rate plan includes a ratemaking capital structure of approximately 52% debt and 48% equity through the combination of long-term debt issuance and dividend payments. In September 2017, the Company paid dividends on common stock of $550 million to NMHI to align the capital structure more closely to its filed rate plan.
Cumulative Preferred Stock
The Company has certain issues of non-participating cumulative preferred stock outstanding which can be redeemed at the option of the Company. There are no mandatory redemption provisions on the Company’s cumulative preferred stock. A summary of cumulative preferred stock is as follows:
In connection with the acquisition of KeySpan by NGUSA, the Company became subject to a requirement to issue a class of preferred stock, having one share (the “Golden Share”), subordinate to any existing preferred stock. The holder of the Golden Share would have voting rights that limit the Company’s right to commence any voluntary bankruptcy, liquidation, receivership, or similar proceeding without the consent of the holder of the Golden Share. The NYPSC subsequently authorized the issuance of the Golden Share to a trustee, GSS Holdings, Inc. (“GSS”), who will hold the Golden Share subject to a Services and Indemnity Agreement requiring GSS to vote the Golden Share in the best interests of NYS. On July 8, 2011, the Company issued the Golden Share with a par value of $1.
The annual dividend requirement for cumulative preferred stock is $1.1 million.
The normal ongoing operations and historic activities of the Company are subject to various federal, state, and local environmental laws and regulations. Under federal and state Superfund laws, potential liability for the historic contamination of property may be imposed on responsible parties jointly and severally, without regard to fault, even if the activities were lawful when they occurred.
The United States Environmental Protection Agency ("EPA"), and the New York State Department of Environmental Conservation ("DEC"), as well as private entities, have alleged that the Company is a potentially responsible party under state or federal law for the remediation of numerous sites. The Company’s most significant liabilities relate to former Manufactured Gas Plant (“MGP”) facilities formerly owned or operated by the Company. The Company is currently investigating and remediating, as necessary, those MGP sites and certain other properties under agreements with the EPA and the DEC. Expenditures incurred for the nine months ended September 30, 2018 and 2017 were $6.1 million and $9.7 million, respectively.
The Company estimated the remaining costs of environmental remediation activities were $370.0 million and $359.6 million at September 30, 2018 and December 31, 2017, respectively. The Company had a current portion of environmental remediation costs of $25.3 million included in other miscellaneous current and accrued liabilities on the balance sheet at September 30, 2018. These costs are expected to be incurred over approximately 41 years. However, remediation costs for each site may be materially higher than estimated, depending on changing technologies and regulatory standards, selected end use for each site, and actual environmental conditions encountered. The Company has recovered amounts from certain insurers and potentially responsible parties, and, where appropriate, the Company may seek additional recovery from other insurers and from other potentially responsible parties, but it is uncertain whether, and to what extent, such efforts will be successful.
By rate orders issued and effective April 1, 2018, the NYPSC has provided an annual rate allowance of $32.1 million ($27.3 million in electric base rates and $4.8 million in gas base rates). Any annual spend above the $32.1 million rate allowance is deferred for future recovery. Previous rate orders have provided for similar recovery mechanisms (with different rate allowances and thresholds). Accordingly, as of September 30, 2018 and December 31, 2017, the Company has recorded environmental regulatory assets of $370.0 million and $359.6 million, respectively, and environmental regulatory liabilities of $49.0 million and $82.3 million, respectively.
The Company believes that its ongoing operations, and its approach to addressing conditions at historic sites, are in substantial compliance with all applicable environmental laws. Where the Company has regulatory recovery, it believes that the obligations imposed on it because of the environmental laws will not have a material impact on its results of operations or financial position.
Legal Matters
The Company is subject to various legal proceedings arising out of the ordinary course of its business. The Company does not consider any of such proceedings to be material, individually or in the aggregate, to its business or likely to result in a material adverse effect on its results of operations, financial position, or cash flows.
Nuclear Contingencies
As of September 30, 2018 and December 31, 2017, the Company had a liability of $172.0 million and $169.8 million, respectively, recorded in other deferred credits on the balance sheet, for the disposal of nuclear fuel irradiated prior to 1983. The Nuclear Waste Policy Act of 1982 provides three payment options for liquidating such liability and the Company has elected to delay payment, with interest, until the year in which Constellation Energy Group Inc., which purchased the Company’s nuclear assets, initially plans to ship irradiated fuel to an approved Department of Energy (“DOE”) disposal facility.
The 2010 Federal budget (which became effective October 1, 2009) eliminated almost all funding for the creation of the Yucca Mountain repository. A Blue Ribbon Commission (“BRC”) on America’s Nuclear Future, appointed by the U.S. Energy Secretary, released a report on January 26, 2012, detailing comprehensive recommendations for creating a safe, long-term solution for managing and disposing of the nation’s spent nuclear fuel and high-level radioactive waste.
In early 2013, the DOE issued an updated “Strategy for the Management and Disposal of Used Nuclear Fuel and High-Level Radioactive Waste” in response to the BRC recommendations. This strategy included a consolidated interim storage facility that was planned to be operational in 2025. However, due to continued delays on the part of the DOE, and the amount of time required for DOE to select a site location and develop the necessary infrastructure for long-term spent nuclear fuel storage, the Company cannot predict the date at which the DOE will begin accepting spent nuclear fuel.
Accounts Receivable from and Accounts Payable to Associated Companies
NGUSA and its affiliates provide various services to the Company, including executive and administrative, customer services, financial (including accounting, auditing, risk management, tax, and treasury/finance), human resources, information technology, legal, and strategic planning, that are charged between the companies and charged to each company.
The Company records short-term receivables from, and payables to, certain of its associated companies in the ordinary course of business. The amounts receivable from, and payable to, its associated companies do not bear interest and are settled through the intercompany money pool. A summary of outstanding accounts receivable from associated companies and accounts payable to associated companies is as follows:
Notes Receivable from and Notes Payable to Associated Companies (“Intercompany Money Pool”)
The settlement of the Company’s various transactions with NGUSA and certain associated companies generally occurs via the intercompany money pool in which it participates. The Company is a participant in the Regulated Money Pool and can both borrow and invest funds. Borrowings from the Regulated Money Pool bear interest in accordance with the terms of the Regulated Money Pool Agreement. As the Company fully participates in the Regulated Money Pool rather than settling intercompany charges with cash, all changes in the intercompany money pool balance and accounts receivable from associated companies and accounts payable to associated companies balances are reflected as investing or financing activities in the accompanying statements of cash flows. In addition, for the purpose of presentation in the statements of cash flows, it is assumed all amounts settled through the intercompany money pool are constructive cash receipts and payments, and therefore are presented as such.
The Regulated Money Pool is funded by operating funds from participants. NGUSA has the ability to borrow up to $3 billion from National Grid plc for working capital needs including funding of the Regulated Money Pool, if necessary. The Company had short-term intercompany money pool investments of $62.4 million and $182.9 million at September 30, 2018 and December 31, 2017, respectively. The average interest rates for the intercompany money pool were 2.1% and 1.3% for the nine months ended September 30, 2018 and 2017, respectively.
Service Company Charges
The affiliated service companies of NGUSA provide certain services to the Company at their cost. The service company costs are generally allocated to associated companies through a tiered approach. First and foremost, costs are directly charged to the benefited company whenever practicable. Secondly, in cases where direct charging cannot be readily determined, costs are allocated using cost/causation principles linked to the relationship of that type of service, such as number of employees, number of customers/meters, capital expenditures, value of property owned, and total transmission and distribution expenditures. Lastly, all other costs are allocated based on a general allocator determined using a 3-point formula based on net margin, net utility plant, and operations and maintenance expense.
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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: |
STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES |
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Line No. |
Item (a) |
Unrealized Gains
and Losses on
Available-For-Sale
Securities (b) |
Minimum Pension
Liability Adjustment
(net amount) (c) |
Foreign Currency
Hedges (d) |
Other
Adjustments (e) |
Other Cash Flow Hedges
Interest Rate Swaps (f) |
Other Cash Flow Hedges
[Specify] (g) |
Totals for each
category of
items recorded in
Account 219 (h) |
Net Income
(Carried Forward
from Page 116,
Line 78) (i) |
Total
Comprehensive
Income (j) |
1 | Balance of Account 219 at Beginning of Preceding Year |
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2 | Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income |
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3 | Preceding Quarter/Year to Date Changes in Fair Value |
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5 | Balance of Account 219 at End of Preceding Quarter/Year |
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6 | Balance of Account 219 at Beginning of Current Year |
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7 | Current Quarter/Year to Date Reclassifications from Account 219 to Net Income |
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9 | Total (lines 7 and 8) |
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10 | Balance of Account 219 at End of Current Quarter/Year |
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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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Line No. |
Classification (a) |
Total Company
For the Current
Year/Quarter Ended (b) |
Electric (c) |
Gas (d) |
Other (Specify) (e) |
Other (Specify) (f) |
Other (Specify) (g) |
Common (h) |
1 |
UtilityPlantAbstract UTILITY PLANT |
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2 |
UtilityPlantInServiceAbstract In Service |
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3 |
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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9 |
UtilityPlantLeasedToOthers Leased to Others |
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10 |
UtilityPlantHeldForFutureUse Held for Future Use |
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ConstructionWorkInProgress Construction Work in Progress |
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12 |
UtilityPlantAcquisitionAdjustment Acquisition Adjustments |
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13 |
UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12) |
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14 |
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion |
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15 |
UtilityPlantNet Net Utility Plant (13 less 14) |
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16 |
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION |
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17 |
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service: |
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18 |
DepreciationUtilityPlantInService Depreciation |
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19 |
AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService Amortization and Depletion of Producing Natural Gas Land and Land Rights |
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20 |
AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService Amortization of Underground Storage Land and Land Rights |
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21 |
AmortizationOfOtherUtilityPlantUtilityPlantInService Amortization of Other Utility Plant |
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22 |
DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21) |
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23 |
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract Leased to Others |
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24 |
DepreciationUtilityPlantLeasedToOthers Depreciation |
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25 |
AmortizationAndDepletionUtilityPlantLeasedToOthers Amortization and Depletion |
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26 |
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers Total Leased to Others (24 & 25) |
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27 |
DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract Held for Future Use |
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28 |
DepreciationUtilityPlantHeldForFutureUse Depreciation |
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29 |
AmortizationUtilityPlantHeldForFutureUse Amortization |
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30 |
DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29) |
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31 |
AbandonmentOfLeases Abandonment of Leases (Natural Gas) |
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32 |
AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment |
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33 |
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32) |
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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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Line No. |
Item (a) |
Plant in Service Balance at End of Quarter (b) |
Accumulated Depreciation And Amortization Balance at End of Quarter (c) |
1 |
Intangible Plant |
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2 |
Steam Production Plant |
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3 |
Nuclear Production Plant |
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4 |
Hydraulic Production - Conventional |
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5 |
Hydraulic Production - Pumped Storage |
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6 |
Other Production |
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7 |
Transmission |
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8 |
Distribution |
|
|
9 |
Regional Transmission and Market Operation |
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10 |
General |
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|
11 |
TOTAL (Total of lines 1 through 10) |
|
|
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 |
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|
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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 |
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2 | (a) |
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3 | (b) |
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4 | (c) |
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5 | |||||
6 | (d) |
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7 | |||||
8 | |||||
9 | |||||
10 | |||||
11 | |||||
12 | |||||
13 | (e) |
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14 | (f) |
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15 | (g) |
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16 | |||||
17 | (h) |
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18 | (i) |
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19 | |||||
20 |
Total |
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21 |
Generation Studies |
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22 | (j) |
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23 | |||||
24 | |||||
25 | |||||
26 | (k) |
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27 | |||||
28 | (l) |
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29 | |||||
30 | |||||
31 | |||||
32 | |||||
33 | |||||
34 | |||||
35 | |||||
36 | (m) |
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37 | (n) |
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38 | (o) |
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39 | |||||
40 | |||||
41 | |||||
42 | |||||
43 | |||||
44 | |||||
45 | |||||
46 | |||||
47 | |||||
48 | (p) |
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49 | (q) |
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50 | |||||
51 | |||||
52 | (r) |
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53 | |||||
54 | |||||
55 | |||||
56 | (s) |
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57 | (t) |
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58 | |||||
59 | (u) |
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60 | |||||
61 | |||||
62 | |||||
63 | |||||
64 | |||||
65 | |||||
66 | |||||
67 | |||||
68 | |||||
69 | |||||
70 | |||||
71 | |||||
72 | |||||
73 | |||||
74 | |||||
75 | |||||
76 | |||||
77 | |||||
78 | |||||
79 | |||||
80 | |||||
81 | |||||
82 | |||||
83 | |||||
84 | |||||
85 | |||||
39 |
Total |
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40 | Grand 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: DescriptionOfStudyPerformed |
HVDC - High Voltage Direct Current; SRISA - System Reliability Impact Study Agreement |
(b) Concept: DescriptionOfStudyPerformed |
SWA - Study Work Agreement |
(c) Concept: DescriptionOfStudyPerformed |
SRIS - System Reliability Impact Study |
(d) Concept: DescriptionOfStudyPerformed |
SIS & SWA - System Impact Study and Study Work Agreement |
(e) Concept: DescriptionOfStudyPerformed |
SWA - Study Work Agreement, SRIS - System Reliability Impact Study |
(f) Concept: DescriptionOfStudyPerformed |
SWA - Study Work Agreement, SRIS - System Reliability Impact Study |
(g) Concept: DescriptionOfStudyPerformed |
SISA & SWA - System Impact Study Agreement and Study Work Agreement |
(h) Concept: DescriptionOfStudyPerformed |
ITC – Interconnector, FSA/SWA – Facilities Study Agreement/Study Work Agreement |
(i) Concept: DescriptionOfStudyPerformed |
BEC - Bethlehem Energy Center, FES - Feasibility Study |
(j) Concept: DescriptionOfStudyPerformed |
FESA - Feasibility Study Agreement |
(k) Concept: DescriptionOfStudyPerformed |
FSA/SWA - Facility Study Agreement/Study Work Agreement |
(l) Concept: DescriptionOfStudyPerformed |
FSA - Facility Study Agreement |
(m) Concept: DescriptionOfStudyPerformed |
SWA - Study Work Agreement |
(n) Concept: DescriptionOfStudyPerformed |
SRIS SWA - System Reliability Impact Study Study Work Agreement |
(o) Concept: DescriptionOfStudyPerformed |
SRIS - System Reliability Impact Study |
(p) Concept: DescriptionOfStudyPerformed |
SISA/SWA - System Impact Study Agreement/Study Work Agreement |
(q) Concept: DescriptionOfStudyPerformed |
FESA/SWA - Feasibility Study Agreement/Study Work Agreement |
(r) Concept: DescriptionOfStudyPerformed |
SWA-FES - Study Work Agreement Feasability Study |
(s) Concept: DescriptionOfStudyPerformed |
SIS - System Impact Study |
(t) Concept: DescriptionOfStudyPerformed |
FES - Feasibility Study |
(u) Concept: DescriptionOfStudyPerformed |
LFIP - Large Facility Interconnection Procedures |
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) |
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|
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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 | (es) |
(kg) |
||||
2 | (c) |
(et) |
(mr) |
|||
3 | (eu) |
|||||
4 | (ev) |
|||||
5 | (ew) |
(id) |
(kn) |
(mw) |
||
6 | (ex) |
(ie) |
(ko) |
|||
7 | (ey) |
|||||
8 | ||||||
9 | (ez) |
|||||
10 | (fa) |
(nf) |
||||
11 | (fb) |
|||||
12 | (ip) |
|||||
13 | (iq) |
(kz) |
||||
14 | ||||||
15 | (lc) |
|||||
16 | (ld) |
|||||
17 | ||||||
18 | (ja) |
|||||
19 | (fq) |
(od) |
||||
20 | ||||||
21 | (jb) |
|||||
22 | (jc) |
(lj) |
||||
23 | (fv) |
(jd) |
||||
24 | (je) |
(lm) |
||||
25 | (ln) |
|||||
26 | ||||||
27 | (jf) |
|||||
28 | (ls) |
|||||
29 | (ji) |
|||||
30 | (jj) |
|||||
31 | (jk) |
|||||
32 | ||||||
33 | (go) |
(jl) |
(lt) |
|||
34 | (gp) |
(pk) |
||||
35 | ||||||
36 | ||||||
37 | (js) |
(ma) |
||||
38 | ||||||
39 | ||||||
40 | ||||||
41 | (jt) |
(mb) |
||||
42 | ||||||
43 | ||||||
44 | ||||||
45 | ||||||
46 | (hs) |
(ml) |
||||
47 | (ht) |
(qr) |
||||
48 | (hu) |
(kf) |
(mm) |
(qs) |
||
49 | (mn) |
(qt) |
||||
50 | (mo) |
(qu) |
||||
44 |
TOTAL |
(qv) |
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: DescriptionAndPurposeOfOtherRegulatoryAssets |
The objectives of accounting for income taxes are to recognize (a) the amount of taxes payable or refundable for the current year, and (b) deferred tax liabilities and assets for the future tax consequences of events that have been recognized in the Company's financial statements or tax returns. |
(b) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(c) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
This account represents an allowance of nonrecurring costs associated with the Electric Transmission Energy Highway project that was transferred to account 182.2 - Unrecovered plant and regulatory study costs for a project that is not going into construction. In Rate Case 17-E-0238, the PSC allowed recovery of $4.615 million (Appendix 5, Schedule 1) with a 3 year amortization recovery period (April 2018 - March 2021). The balance will be amortized in the amount of $1.538 million each Rate Year from account 182.2. |
(d) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(e) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Section 10.1.6 of the Joint Proposal of 17-E-0238 and 17-E-0239 provides for the recoveries of Site Investigation and Remediation expenses. The Company will reconcile the expense to the annual rate allowance of $27.321 million for electric and $4.821 million for gas. Any under- or over-expenditures are deferred for future refund to, or recovery from customers. |
(f) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(g) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Section 10.1.15 of the Joint Proposal of 17-E-0238, the Company is authorized a base rate allowance of $23 million each rate year. The Company will defer the difference between the base rate allowance and actual major storm incremental costs. Balance in account represents Storm Restoration Costs that are allowed to be deferred and have been deferred by the Company with permission from the PSC for future recoveries based on various rate years. These costs are allowed to be collected from customers. The expense deferred in account 1823006 should be analyzed in conjunction with account 2540314 which holds the respective allowances for storm deferrals which match up with the expenses deferred in 1823006. |
(h) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(i) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The Company's Electric Tariff has a mechanism (PSC No. 220, Rule 57 effective April 2018 per Section 3.5 of rate case 17-E-0238) that permits the Company to defer the difference between revenue per customer targets and actual revenues. |
(j) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The Company recovers cost of removal through its depreciation rates, as such the Company defers recognition of the effects of the asset retirement obligation. |
(k) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(l) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(m) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The Company's Electric Tariff has a mechanism (PSC No. 220, Rule 46.2.6 effective April 2018 per Case 17-E-0238 section 10.1.25) that permits the Company to reconcile the benefits associated with the net market value of NYPA Rural & Domestic power, the benefit of the monthly Residential Consumer Discount Program payment and the Residential Agricultural Discount Program to the amounts credited to customers. |
(n) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
This account represents the monthly the Gas Adjustment Clause (GAC) deferral. The GAC deferral entry takes into account the difference between (1) the actual gas cost recoveries from customers and (2) the actual gas costs incurred by the Company for gas purchased from suppliers. The deferral is filed annually for the period of September to August and submitted to the PSC by October 15th. After the filing is made, the balance is transferred to an imbalance regulatory deferral account and is recovered or refunded to customers in the next calendar period. |
(o) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(p) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
As commodity costs, including realized gains and losses on commodity derivatives, are refunded to or recovered from customers through the Company's gas recovery mechanism, a regulatory asset or liability is recorded as an offset to the unrealized gain or loss on a derivative asset in accordance with ASC 980 under US GAAP. |
(q) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(r) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
As commodity costs, including realized gains and losses on commodity derivatives, are refunded to or recovered from customers through the Company's electric cost recovery mechanism, a regulatory asset or liability is recorded as an offset to the unrealized gain or loss on a derivative asset in accordance with ASC 980 under US GAAP. |
(s) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(t) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(u) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
This account represents the Refund/Surcharge for prior years’ TAC (Transportation Adjustment Clause) imbalances (i.e. over/under collection). Dependent on the position/year of the imbalance amount, debits and/or credits can represent amortization of the imbalances and accrued interest on the declining balances. The account is filed annually for the period of September – August. Amortization of refund/surcharge occur from January to December and relate to prior GAC (Gas Adjustment Clause) Gas year September - August. |
(v) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(w) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(x) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(y) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
This account represents asset related to Medicare Act Tax Benefit deferral to be recovered from customers. NMPC rate cases 12-E-0201 & 12-G-0202 includes the pro-rata allocation of deferral credits for this account. Effective April 2018, rate case 17-G-0239 required an additional pro rata allocation credit to create the Gas Rate Plan Deferral Credit. This mechanism is discontinued under case 17-G-0239. |
(z) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(aa) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ab) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Purpose of this account is to reconcile commodity expense in a given month with commodity revenue in the same month, with the difference being collected from or returned to customers. |
(ac) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
On August 1, 2016, the PSC issued an order (Case 15-E-0302) to implement a Large-Scale Renewable Program and Clean Energy Standards (CES). Under this program, the Company is required to purchase the percentage of Renewable Energy Credits to support new renewable generation sources and Zero Emission Credits to support Zero-Emission-nuclear power from NYSERDA and recover costs from ratepayers through commodity charges on customer bills. |
(ad) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ae) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(af) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
To establish recoverable incremental expenditure for interim gas programs and associated carrying charges for disposition in a future rate case pursuant to Case 07-M-0548 issued and effective March 4, 2015. Deferred with carrying charges using the Other Customer Capital Rate. |
(ag) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ah) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ai) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Account represents actuarial gain/loss on prior service cost that will be amortized into expense over a set period of time. |
(aj) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ak) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(al) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Account represents actuarial gain/loss on prior service cost that will be amortized into expense over a set period of time. |
(am) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(an) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ao) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ap) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(aq) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The purpose of this account is to amortize the deferral summary balance per rate case 10-E-0050. In line with rate case 12-E-0201, amortization of the balance has taken place, and the remaining balance of $3.1 million in the account will remain until the next rate case. Pursuant to the new electric rate case 17-E-0238, the Company was authorized to create an Electric Rate Plan Deferral Credit to promote rate stability and mitigate bill impacts for our customers. In April 2018, $2.245 million was transferred from the Deferral Summary case 10-E balance to the Electric Rate Plan Deferral Credit. This mechanism is discontinued under Case 17-E-0238. |
(ar) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The Merchant Function Charge (MFC) is applied to the customer’s bill when the customer receives electricity supply from the Company. This charge includes costs associated with commodity related credit and collections, commodity related uncollectible expense, electric supply procurement costs and working capital for electric supply. This charge is applied to the Electricity Supply portion of a customer’s bill. This charge will not be billed if the customer chooses and alternate supplier. Based on rate case 17-E-0238 the Company is allowed to defer the difference between the revenue for the MFC and the revenue requirement. |
(as) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(at) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(au) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(av) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(aw) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The Company's Gas Tariff has a mechanism (PSC No. 219, Rule 32 effective April 2018 per Section 4.6, of rate case 17-G-0239) that permits the Company to defer the difference between revenue per customer targets and actual revenues. |
(ax) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Section 10.1.1 of the Joint Proposal in Cases 17-E-0238 & 17-E-0239 require the Company to defer the difference between actual Pension and OPEB costs and the annual revenue requirements for Pension and OPEB costs. |
(ay) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(az) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ba) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Allowance for Funds Used During Construction given to the Company, which are being amortized April 2004-May 2023. |
(bb) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bc) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bd) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(be) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Section 10.1.1 of the Joint Proposal in Cases 17-E-0238 & 17-E-0239 require the Company to defer the difference between actual Pension and OPEB costs and the annual revenue requirements for Pension and OPEB costs. |
(bf) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bg) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bh) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bi) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
This deferral mechanism discontinued April 2013. The balance of this account represents partially amortized amount per Section 4.4.1 and Appendix 6, Schedule 13 of the Joint Proposal per Case 12-G-0202. In April 2018, rate case 17-G-0239 transferred a pro-rata allocation of this account, a portion was used to create the Gas Rate Plan Deferral Credit. Remaining balance will be considered in future rate cases. |
(bj) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bk) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The Company's Electric Tariff has a mechanism (PSC No. 220, Rule 46.2 effective April 2018 per case 17-E-0238 section10.1.25) that permits the Company to recover from customers costs associated with Legacy power agreements and reconcile the revenues and costs. |
(bl) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bm) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bn) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Allowance for Funds Used During Construction given to the Company, which are being amortized April 2004-April 2038. |
(bo) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bp) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bq) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The Company's Electric Tariff has a mechanism (PSC No. 220, Rule 46.3 effective April 2018 per case 17-E-0238 section 10.1.25) that permits the Company to recover from customers costs associated with purchased power agreements and reconcile the revenues and costs. |
(br) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bs) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
In Case 14-M-0101 (Proceeding on Motion of the Commission in Regard to Reforming the Energy Vision; issued/effective 02/26/2015), the State of New York PSC directed the Company to engage third parties and develop concepts for demonstration projects related to Reforming the Energy Vision (REV). Additionally, per the order, utilities are permitted to defer the revenue requirement impacts of the incremental cost of demonstration projects, until their next rate plan. This account captures the deferral of incremental revenue requirement amounts for incremental O&M associated with the Company’s REV Demonstration Projects. At the inception of the deferral, the REV Demonstration Projects are as follows: (1) Fruit Belt Community Solar Project (Buffalo, NY), (2) Potsdam Resiliency Project (Potsdam, NY), (3) Distributed System Platform Project (Buffalo, NY) and (4) Demand Reduction Project (Clifton Park, NY). Per Rate Case 17-E-0238, the Company will defer costs associated with addtioanl REV demostration pojects. |
(bt) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bu) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bv) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bw) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(bx) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
This account holds the deferral for later recovery of the cost that the Company has incurred to comply with new federal regulations application to vegetation management practices on the electric transmission system. The incremental work performed to comply with the regulation is the basis for deferral of the incremental expenditures incurred for FY 2015 in agreement with Appendix 7, Section 1.2.2. of the Joint Proposal approved by NY PSC in Case 12-E-0201. Effective April 2018, PSC Case 17-E-0238 transferred a pro-rata allocation, $11.5 million was used to create the Electric Rate Plan Deferral Credit. This mechanism is discontinued under case 17-E-0238. |
(by) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The Company's Gas Tariff has a mechanism (PSC No. 219, Rule 33 effective April 2018 per case 17-G-0239) that permits the Company to recover from customers costs associated with energy supply procurement, credit and collections and uncollectibles as well as working capital on purchased gas and gas storage. |
(bz) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ca) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(cb) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(cc) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The objectives of accounting for income taxes are to recognize (a) the amount of taxes payable or refundable for the current year, and (b) deferred tax liabilities and assets for the future tax consequences of events that have been recognized in the Company's financial statements or tax returns. |
(cd) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ce) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(cf) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
In Case 14-M-0101 ("Proceeding on Motion of the Commission in Regard to Reforming the Energy Vision; issued/effective 02/26/2015), the State of New York PSC directed the Company to engage third parties and develop concepts for demonstration projects related to Reforming the Energy Vision (REV). Additionally, per the order, utilities are permitted to defer the revenue requirement impacts of the incremental cost of demonstration projects, until their next rate plan. This account covers the deferral of incremental revenue requirement amounts for in-service CAPEX associated with the Company’s REV Demonstration Projects. At the inception of the deferral, the REV Demonstration Projects are as follows: (1) Fruit Belt Community Solar Project (Buffalo, NY), (2) Potsdam Resiliency Project (Potsdam, NY), (3) Distributed System Platform Project (Buffalo, NY) and (4) Demand Reduction Project (Clifton Park, NY). (5) Smart City Project (Schenectady, NY). Per Rate Case 17-E-0238, the Company will defer costs associated with addtioanl REV demostration pojects. |
(cg) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ch) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
This account records (1) the current year's Net Revenue Sharing (NRS) deferral and (2) the amortization of prior year NRS imbalances (i.e. net over or under collections). In accordance with rate case 17-G-0239 and the PSC 219 tariff (Rule 26), the Company sets delivery revenue targets for SC 6 and combined SC9/ SC14 service classes each rate year and reconciles actual fiscal year revenues to these targets. The company shares with participating service classes of customers 90% of the difference vs targets in SC 6 revenues and 100% of the difference in the combined SC9/14 revenues vs targets. Additionally, the annual filing with the PSC occurs during June of each year, with new rates effective August 1st. |
(ci) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(cj) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ck) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Section 10.1 of Joint Proposal in case 17-E-0238 requires the Company to defer interest on regulatory assets. |
(cl) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(cm) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(cn) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(co) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(cp) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Section 10.1 of Joint Proposal in rate case 17-E-0238 requires the Company to defer interest on regulatory assets. |
(cq) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(cr) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(cs) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Per Case 17-E-0238, System Benefit Charge costs will continue to be reconciled pursuant to Public Service Commission 220 Rule 41. Energy Efficiency Portfolio Standard deferral was re-classed to a separate GL account per Public Service Commission request in July 2018. |
(ct) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(cu) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(cv) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(cw) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
This account carries the deferred charges for RSS (Reliability Support Service) paid to Dunkirk totaling $57 million as per RSS agreement rate case 12-E-0136 (Petition of Dunkirk Power LLC and NRG energy Inc for Waiver of generator Retirement ) and rate case 12-E-0201. Pursuant to the new electric rate case 17-E-0238, the Company was authorized to create an Electric Rate Plan Deferral Credit to promote rate stability and mitigate bill impacts for our customers. In April 2018, a pro rata allocation was transferred from the Dunkirk Settlement deferral balance to the Electric Rate Plan Deferral Credit. This mechanism is discontinued under case 17-E-0238. |
(cx) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(cy) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(cz) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(da) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The Company filed tariff amendments to incorporate Light Emitting Diode (LED) street lighting fixture options, P.S.C. No 214 - Electricity. Municipalities have expressed interest to NMPC in replacing the non-LED fixtures with LED fixtures. The company requested a deferral for future recovery equal to the return of and return on (1) LED facility costs not included in the proposed rate, (2) incremental cost of removal incurred by the Company, and (3) any lost delivery kilowatt-hour (kWh) sales revenue. (case 15-E-0645) |
(db) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(dc) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(dd) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(de) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(df) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The Company filed tariff amendments to incorporate Light Emitting Diode (LED) street lighting fixture options, P.S.C. No 214 - Electricity. Municipalities have expressed interest to NMPC in replacing the non-LED fixtures with LED fixtures. The company requested a deferral for future recovery equal to the return of and return on (1) LED facility costs not included in the proposed rate, (2) incremental cost of removal incurred by the Company, and (3) any lost delivery kilowatt-hour (kWh) sales revenue. (case 15-E-0645) |
(dg) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(dh) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(di) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(dj) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The Compnay filed tariff amendments to incorporate Light Emitting Diode (LED) street lighting fixture options, P.S.C. No 214 - Electricity. Municipalities have expressed interest to NMPC in replacing the non-LED fixtures with LED fixtures. The company requested a deferral for future recovery equal to the return of and return on (1) LED facility costs not included in the proposed rate, (2) incremental cost of removal incurred by the Company, and (3) any lost delivery kilowatt-hour (kWh) sales revenue. (case 15-E-0645) |
(dk) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(dl) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The balance in this account represents the incremental rate case expenses incurred associated with Case 17-E-0238 (Electric). The rate case expenses for Case 17-E-0238 are deferred as a regulatory asset. In the Company's current rate cases 17-E-0238 & 17-G-0239, the balance in the account will be amortized over three Rate Years (April 2018 - March 2021) under the rate plan in accordance to Appendix 1, Schedule 1. |
(dm) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(dn) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(do) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(dp) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(dq) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(dr) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The balance in this account represents the incremental rate case expenses incurred associated with Case 17-G-0239 (Gas). The rate case expenses for Case 17-G-0239 are deferred as a regulatory asset. In the Company's current rate cases 17-E-0238 & 17-G-0239, the balance in the account will be amortized over three Rate Years (April 2018 - March 2021) under the rate plan in accordance to Appendix 1, Schedule 2. |
(ds) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(dt) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(du) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
This account contains the MFC (Merchant Function Charge) Gas Imbalance surcharges/refunds and associated carrying charges. The MFC is included on the customers bills and annual recoveries are compared to annual amounts allowed per the PSC. Any imbalance is filed with the PSC annually and collected/refunded from customers from April through March. |
(dv) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(dw) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(dx) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(dy) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(dz) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ea) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Section 10.1.7 of the Joint Proposal in Case 17-E-0238 requires the Company to defer 80% of the difference between actual property taxes (excluding the effects of property tax refunds) and the rate allowance ($183.024 million in Rate Year One, $189.211 million in Rate Year Two, and $195.164 million in Rate Year Three). |
(eb) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ec) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ed) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
This account represents the Refund/Surcharge for prior years’ SPA (System Performance Adjustment) imbalances (i.e. over/under collection). This account is filed annually for the period of September - August and is submitted to the PSC by October 15th. |
(ee) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ef) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(eg) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(eh) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Per PSC Case 14-M-0094 et al. (Issued/Effective January 21, 2016), NYSERDA’s clean energy activities are consolidated under the umbrella of the Clean Energy Fund (CEF). The legacy program (and its associated deferral balance) existing prior to this case related to the Gas Energy Efficiency Portfolio Standard (EEPS) was consolidated into this newly created deferral account to track CEF activity.
Per Tariff Leaf 122.1 of PSC No. 219, Rule 31.1A (CEF Surcharge Rate). Beginning on March 1, 2016, the CEF Surcharge Rate collects funds associated with NYSERDA-run EEPS activities as well as over or under collections associated with company-run EEPS programs for the period prior to 2016. |
(ei) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ej) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ek) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(el) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Per PSC case 14-M-0094 et al. (Issued/Effective January 21, 2016), NYSERDA’s clean energy activities are consolidated under the umbrella of the Clean Energy Fund (CEF). Legacy programs (and their associated deferral balances) existing prior to this case, including the Renewable Portfolio Standard (RPS), the System Benefit Charge (SBC) III/IV and the Electric Energy Efficiency Portfolio Standard (EEPS), were consolidated into this newly created deferral account to track CEF activity.
Per Tariff Leaf 221 of PSC No. 220, Rule 41.3 (CEF Surcharge Rate). Beginning on March 1, 2016, the CEF Surcharge Rate will collect funds associated with NYSERDA administered clean energy activities, including RPS, EEPS, SBC IV, and CEF, as well as over- or under-collections associated with Company administered EEPS programs for the period prior to 2016. |
(em) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(en) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
Per rate case 17-G-0239 (Section 10.1.22, Section 13.8.2 & Appendix 6, Schedule 13), the Company continue its oil to gas conversion deferral. NMPC will defer the difference between conversion cost and annual rate allowance of $0.764 million, the cost of which will not exceed $1 million annually. |
(eo) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(ep) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The balance in this account represents the NY PSC management audit costs incurred. The management audit expenses will be deferred as a regulatory asset. As approved in the Company's Rate Case 17-E-0238 & 17-G-0239, Appendix 5, Schedule 1, the balance in the account will be amortized over five Rate Years (April 2018 - March 2023) for $67,200 each Rate Year. |
(eq) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
The balance in this account represents the NY PSC management audit costs incurred. The management audit expenses will be deferred as a regulatory asset. As approved in the Company's Rate Case 17-E-0238 & 17-G-0239, Appendix 6, Schedule 1, the balance in the account will be amortized over five Rate Years (April 2018 - March 2023) for $12,800 each Rate Year. |
(er) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets |
(es) Concept: OtherRegulatoryAssets |
(et) Concept: OtherRegulatoryAssets |
(eu) Concept: OtherRegulatoryAssets |
(ev) Concept: OtherRegulatoryAssets |
(ew) Concept: OtherRegulatoryAssets |
(ex) Concept: OtherRegulatoryAssets |
(ey) Concept: OtherRegulatoryAssets |
(ez) Concept: OtherRegulatoryAssets |
(fa) Concept: OtherRegulatoryAssets |
(fb) Concept: OtherRegulatoryAssets |
(fc) Concept: OtherRegulatoryAssets |
(fd) Concept: OtherRegulatoryAssets |
(fe) Concept: OtherRegulatoryAssets |
(ff) Concept: OtherRegulatoryAssets |
(fg) Concept: OtherRegulatoryAssets |
(fh) Concept: OtherRegulatoryAssets |
(fi) Concept: OtherRegulatoryAssets |
(fj) Concept: OtherRegulatoryAssets |
(fk) Concept: OtherRegulatoryAssets |
(fl) Concept: OtherRegulatoryAssets |
(fm) Concept: OtherRegulatoryAssets |
(fn) Concept: OtherRegulatoryAssets |
(fo) Concept: OtherRegulatoryAssets |
(fp) Concept: OtherRegulatoryAssets |
(fq) Concept: OtherRegulatoryAssets |
(fr) Concept: OtherRegulatoryAssets |
(fs) Concept: OtherRegulatoryAssets |
(ft) Concept: OtherRegulatoryAssets |
(fu) Concept: OtherRegulatoryAssets |
(fv) Concept: OtherRegulatoryAssets |
(fw) Concept: OtherRegulatoryAssets |
(fx) Concept: OtherRegulatoryAssets |
(fy) Concept: OtherRegulatoryAssets |
(fz) Concept: OtherRegulatoryAssets |
(ga) Concept: OtherRegulatoryAssets |
(gb) Concept: OtherRegulatoryAssets |
(gc) Concept: OtherRegulatoryAssets |
(gd) Concept: OtherRegulatoryAssets |
(ge) Concept: OtherRegulatoryAssets |
(gf) Concept: OtherRegulatoryAssets |
(gg) Concept: OtherRegulatoryAssets |
(gh) Concept: OtherRegulatoryAssets |
(gi) Concept: OtherRegulatoryAssets |
(gj) Concept: OtherRegulatoryAssets |
(gk) Concept: OtherRegulatoryAssets |
(gl) Concept: OtherRegulatoryAssets |
(gm) Concept: OtherRegulatoryAssets |
(gn) Concept: OtherRegulatoryAssets |
(go) Concept: OtherRegulatoryAssets |
(gp) Concept: OtherRegulatoryAssets |
(gq) Concept: OtherRegulatoryAssets |
(gr) Concept: OtherRegulatoryAssets |
(gs) Concept: OtherRegulatoryAssets |
(gt) Concept: OtherRegulatoryAssets |
(gu) Concept: OtherRegulatoryAssets |
(gv) Concept: OtherRegulatoryAssets |
(gw) Concept: OtherRegulatoryAssets |
(gx) Concept: OtherRegulatoryAssets |
(gy) Concept: OtherRegulatoryAssets |
(gz) Concept: OtherRegulatoryAssets |
(ha) Concept: OtherRegulatoryAssets |
(hb) Concept: OtherRegulatoryAssets |
(hc) Concept: OtherRegulatoryAssets |
(hd) Concept: OtherRegulatoryAssets |
(he) Concept: OtherRegulatoryAssets |
(hf) Concept: OtherRegulatoryAssets |
(hg) Concept: OtherRegulatoryAssets |
(hh) Concept: OtherRegulatoryAssets |
(hi) Concept: OtherRegulatoryAssets |
(hj) Concept: OtherRegulatoryAssets |
(hk) Concept: OtherRegulatoryAssets |
(hl) Concept: OtherRegulatoryAssets |
(hm) Concept: OtherRegulatoryAssets |
(hn) Concept: OtherRegulatoryAssets |
(ho) Concept: OtherRegulatoryAssets |
(hp) Concept: OtherRegulatoryAssets |
(hq) Concept: OtherRegulatoryAssets |
(hr) Concept: OtherRegulatoryAssets |
(hs) Concept: OtherRegulatoryAssets |
(ht) Concept: OtherRegulatoryAssets |
(hu) Concept: OtherRegulatoryAssets |
(hv) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(hw) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(hx) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(hy) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(hz) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ia) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ib) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ic) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(id) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ie) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(if) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ig) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ih) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ii) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ij) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ik) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(il) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(im) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(in) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(io) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ip) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(iq) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ir) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(is) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(it) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(iu) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(iv) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(iw) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ix) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(iy) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(iz) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ja) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jb) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jc) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jd) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(je) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jf) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jg) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jh) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ji) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jj) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jk) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jl) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jm) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jn) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jo) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jp) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jq) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jr) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(js) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jt) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ju) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jv) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jw) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jx) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jy) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(jz) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ka) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(kb) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(kc) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(kd) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ke) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(kf) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(kg) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(kh) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(ki) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(kj) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(kk) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(kl) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(km) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(kn) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(ko) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(kp) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(kq) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(kr) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(ks) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(kt) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(ku) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(kv) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(kw) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(kx) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(ky) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(kz) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(la) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lb) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lc) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(ld) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(le) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lf) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lg) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lh) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(li) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lj) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lk) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(ll) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lm) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(ln) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lo) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lp) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lq) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lr) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(ls) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lt) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lu) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lv) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lw) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lx) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(ly) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(lz) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(ma) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(mb) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(mc) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(md) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(me) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(mf) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(mg) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(mh) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(mi) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(mj) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(mk) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(ml) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(mm) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(mn) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(mo) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(mp) Concept: OtherRegulatoryAssets |
(mq) Concept: OtherRegulatoryAssets |
(mr) Concept: OtherRegulatoryAssets |
(ms) Concept: OtherRegulatoryAssets |
(mt) Concept: OtherRegulatoryAssets |
(mu) Concept: OtherRegulatoryAssets |
(mv) Concept: OtherRegulatoryAssets |
(mw) Concept: OtherRegulatoryAssets |
(mx) Concept: OtherRegulatoryAssets |
(my) Concept: OtherRegulatoryAssets |
(mz) Concept: OtherRegulatoryAssets |
(na) Concept: OtherRegulatoryAssets |
(nb) Concept: OtherRegulatoryAssets |
(nc) Concept: OtherRegulatoryAssets |
(nd) Concept: OtherRegulatoryAssets |
(ne) Concept: OtherRegulatoryAssets |
(nf) Concept: OtherRegulatoryAssets |
(ng) Concept: OtherRegulatoryAssets |
(nh) Concept: OtherRegulatoryAssets |
(ni) Concept: OtherRegulatoryAssets |
(nj) Concept: OtherRegulatoryAssets |
(nk) Concept: OtherRegulatoryAssets |
(nl) Concept: OtherRegulatoryAssets |
(nm) Concept: OtherRegulatoryAssets |
(nn) Concept: OtherRegulatoryAssets |
(no) Concept: OtherRegulatoryAssets |
(np) Concept: OtherRegulatoryAssets |
(nq) Concept: OtherRegulatoryAssets |
(nr) Concept: OtherRegulatoryAssets |
(ns) Concept: OtherRegulatoryAssets |
(nt) Concept: OtherRegulatoryAssets |
(nu) Concept: OtherRegulatoryAssets |
(nv) Concept: OtherRegulatoryAssets |
(nw) Concept: OtherRegulatoryAssets |
(nx) Concept: OtherRegulatoryAssets |
(ny) Concept: OtherRegulatoryAssets |
(nz) Concept: OtherRegulatoryAssets |
(oa) Concept: OtherRegulatoryAssets |
(ob) Concept: OtherRegulatoryAssets |
(oc) Concept: OtherRegulatoryAssets |
(od) Concept: OtherRegulatoryAssets |
(oe) Concept: OtherRegulatoryAssets |
(of) Concept: OtherRegulatoryAssets |
(og) Concept: OtherRegulatoryAssets |
(oh) Concept: OtherRegulatoryAssets |
(oi) Concept: OtherRegulatoryAssets |
(oj) Concept: OtherRegulatoryAssets |
(ok) Concept: OtherRegulatoryAssets |
(ol) Concept: OtherRegulatoryAssets |
(om) Concept: OtherRegulatoryAssets |
(on) Concept: OtherRegulatoryAssets |
(oo) Concept: OtherRegulatoryAssets |
(op) Concept: OtherRegulatoryAssets |
(oq) Concept: OtherRegulatoryAssets |
(or) Concept: OtherRegulatoryAssets |
(os) Concept: OtherRegulatoryAssets |
(ot) Concept: OtherRegulatoryAssets |
(ou) Concept: OtherRegulatoryAssets |
(ov) Concept: OtherRegulatoryAssets |
(ow) Concept: OtherRegulatoryAssets |
(ox) Concept: OtherRegulatoryAssets |
(oy) Concept: OtherRegulatoryAssets |
(oz) Concept: OtherRegulatoryAssets |
(pa) Concept: OtherRegulatoryAssets |
(pb) Concept: OtherRegulatoryAssets |
(pc) Concept: OtherRegulatoryAssets |
(pd) Concept: OtherRegulatoryAssets |
(pe) Concept: OtherRegulatoryAssets |
(pf) Concept: OtherRegulatoryAssets |
(pg) Concept: OtherRegulatoryAssets |
(ph) Concept: OtherRegulatoryAssets |
(pi) Concept: OtherRegulatoryAssets |
(pj) Concept: OtherRegulatoryAssets |
(pk) Concept: OtherRegulatoryAssets |
(pl) Concept: OtherRegulatoryAssets |
(pm) Concept: OtherRegulatoryAssets |
(pn) Concept: OtherRegulatoryAssets |
(po) Concept: OtherRegulatoryAssets |
(pp) Concept: OtherRegulatoryAssets |
(pq) Concept: OtherRegulatoryAssets |
(pr) Concept: OtherRegulatoryAssets |
(ps) Concept: OtherRegulatoryAssets |
(pt) Concept: OtherRegulatoryAssets |
(pu) Concept: OtherRegulatoryAssets |
(pv) Concept: OtherRegulatoryAssets |
(pw) Concept: OtherRegulatoryAssets |
(px) Concept: OtherRegulatoryAssets |
(py) Concept: OtherRegulatoryAssets |
(pz) Concept: OtherRegulatoryAssets |
(qa) Concept: OtherRegulatoryAssets |
(qb) Concept: OtherRegulatoryAssets |
(qc) Concept: OtherRegulatoryAssets |
(qd) Concept: OtherRegulatoryAssets |
(qe) Concept: OtherRegulatoryAssets |
(qf) Concept: OtherRegulatoryAssets |
(qg) Concept: OtherRegulatoryAssets |
(qh) Concept: OtherRegulatoryAssets |
(qi) Concept: OtherRegulatoryAssets |
(qj) Concept: OtherRegulatoryAssets |
(qk) Concept: OtherRegulatoryAssets |
(ql) Concept: OtherRegulatoryAssets |
(qm) Concept: OtherRegulatoryAssets |
(qn) Concept: OtherRegulatoryAssets |
(qo) Concept: OtherRegulatoryAssets |
(qp) Concept: OtherRegulatoryAssets |
(qq) Concept: OtherRegulatoryAssets |
(qr) Concept: OtherRegulatoryAssets |
(qs) Concept: OtherRegulatoryAssets |
(qt) Concept: OtherRegulatoryAssets |
(qu) Concept: OtherRegulatoryAssets |
(qv) Concept: OtherRegulatoryAssets |
(qw) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(qx) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(qy) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(qz) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(ra) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(rb) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(rc) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(rd) Concept: IncreaseDecreaseInOtherRegulatoryAssets |
(re) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(rf) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(rg) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(rh) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(ri) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(rj) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(rk) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(rl) Concept: OtherRegulatoryAssetsWrittenOffRecovered |
(rm) Concept: OtherRegulatoryAssets |
(rn) Concept: OtherRegulatoryAssets |
(ro) Concept: OtherRegulatoryAssets |
(rp) Concept: OtherRegulatoryAssets |
(rq) Concept: OtherRegulatoryAssets |
(rr) Concept: OtherRegulatoryAssets |
(rs) Concept: OtherRegulatoryAssets |
(rt) Concept: OtherRegulatoryAssets |
(ru) Concept: OtherRegulatoryAssets |
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) |
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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 |
(a) |
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2 |
(b) |
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3 |
(c) |
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4 |
(d) |
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5 |
(e) |
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6 |
(f) |
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7 |
(g) |
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8 |
(h) |
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9 |
(i) |
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10 |
(j) |
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11 |
(k) |
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12 |
(l) |
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13 |
(m) |
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14 |
(n) |
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15 |
(o) |
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16 |
(p) |
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17 |
(q) |
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18 |
(r) |
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19 |
(s) |
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20 |
(t) |
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21 |
(u) |
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22 |
(v) |
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23 |
(w) |
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24 |
(x) |
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25 |
(y) |
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26 |
(z) |
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27 |
(aa) |
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28 |
(ab) |
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29 |
(ac) |
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30 |
(ad) |
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31 |
(ae) |
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32 |
(af) |
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33 |
(ag) |
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34 |
(ah) |
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35 |
(ai) |
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36 |
(aj) |
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37 |
(ak) |
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38 |
(al) |
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39 |
(am) |
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40 |
(an) |
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41 |
(ao) |
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42 |
(ap) |
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43 |
(aq) |
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44 |
(ar) |
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45 |
(as) |
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46 |
(at) |
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47 |
(au) |
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48 |
(av) |
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49 |
(aw) |
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50 |
(ax) |
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51 |
(ay) |
|
|
|
|
|
52 |
(az) |
|
|
|||
53 |
(ba) |
|
|
|||
54 |
(bb) |
|
|
|||
55 |
(bc) |
|
|
|||
56 |
(bd) |
|
|
|||
57 |
(be) |
|
|
|
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58 |
(bf) |
|||||
59 |
(bg) |
|
|
|
|
|
60 |
(bh) |
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|
|
|
|
61 |
(bi) |
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62 |
(bj) |
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|
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63 |
(bk) |
|
|
|
|
|
64 |
(bl) |
|
|
|
||
65 |
(bm) |
|
|
|||
66 |
(bn) |
|
|
|
||
67 |
(bo) |
|
|
|
||
68 |
(bp) |
|
|
|
||
69 |
(bq) |
|
|
|
||
70 |
(br) |
|
|
|
|
|
71 |
(bs) |
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|
|||
72 |
(bt) |
|
|
|
|
|
73 |
(bu) |
|
|
|||
74 |
(bv) |
|
|
|||
75 |
(bw) |
|
|
|||
76 |
(bx) |
|
|
|
||
77 |
(by) |
|||||
78 |
(bz) |
|||||
79 |
(ca) |
|
|
|
|
|
80 |
(cb) |
|
|
|
||
81 |
(cc) |
|
|
|||
82 |
(cd) |
|
|
|
||
83 |
(ce) |
|
|
|
|
|
84 |
(cf) |
|
|
|
|
|
85 |
(cg) |
|
|
|
|
|
86 |
(ch) |
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|
|||
87 |
(ci) |
|
|
|
||
88 |
(cj) |
|
|
|
|
|
89 |
(ck) |
|
|
|
||
90 |
(cl) |
|
|
|
||
91 |
(cm) |
|
|
|
||
92 |
(cn) |
|
|
|
|
|
93 |
(co) |
|
|
|||
94 |
(cp) |
|
|
|||
95 |
(cq) |
|
|
|||
96 |
(cr) |
|
|
|||
97 |
(cs) |
|||||
98 |
(ct) |
|
|
|||
99 |
(cu) |
|
|
|||
100 |
(cv) |
|
|
|
||
101 |
(cw) |
|
|
|
||
102 |
(cx) |
|
|
|||
103 |
(cy) |
|||||
104 |
(cz) |
|
|
|
|
|
105 |
(da) |
|
|
|
||
106 |
(db) |
|
|
|
||
107 |
(dc) |
|
|
|
|
|
108 |
(dd) |
|
|
|
|
|
109 |
(de) |
|
|
|
||
110 |
(df) |
|
|
|
||
111 |
(dg) |
|
|
|
||
112 |
(dh) |
|
|
|
||
41 | 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: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
In FAS 109, the objectives of accounting for income taxes are to recognize (a) the amount of taxes payable or refundable for the current year, and (b) deferred tax liabilities and assets for the future tax consequences of events that have been recognized in the Company's financial statements or tax returns. |
(b) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per Case 12-G-0202 Appendix 6 Schedule 12, the Company will defer the difference between costs (self-administered and System Benefit Charge) and revenue collections. The Energy Efficiency Portfolio Standard (EEPS) program was re-classed into its own account per Public Service Commission request in June 2018. Previously, it was deferred in combination with the Clean Energy Fund gas deferral. |
(c) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Account balance represents the remaining portion of NMPC’s litigation settlement from Sithe/Independence Power Partners, L.P. Of the $1.8 million settlement, $1.397 million was returned to firm sales customers through the October 2012 GAC filing. The Company has petitioned the Public Service Commission that the remaining $0.403 million be retained by the Company and not returned to customers/shareholders. The PSC has yet to respond to the Company’s petition. |
(d) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account represents the monthly calculation of the Gas Adjustment Clause (GAC) deferral. The GAC deferral entry takes into account the difference between (1) the actual gas cost recoveries from customers and (2) the actual gas costs incurred by the Company for gas purchased from suppliers. The deferral is filed annually for the period of September to August and submitted to the PSC by October 15th. After the filing is made, the balance is transferred to an imbalance regulatory deferral account and is recovered or refunded to customers in the next calendar period. |
(e) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account represents refunds received from various pipelines which the Company uses to transport gas. These refunds can come into the company in the form of checks, wires or credits on the pipeline invoice. All refunds in the account at the end of the GAC year (August) are transferred to the annual GAC/TAC Imbalance filing to the PSC at October 15 and will subsequently be refunded to the customes in the next calendar year. |
(f) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account represents the Refund/Surcharge for prior years’ MCG (Monthly Cost of Gas) imbalances (i.e. over/under collection). The refund/surcharge is filed annually for the period of September - August and is submitted to the PSC by October 15th. |
(g) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Balance in this account represents 18-A Temporary State Energy & Utility Service Conservation Assessment. This account was established based on a new Temporary State Energy & Utility Services Conservation Assessment effective April 1, 2009 . It imposes a charge of 2% of gross intrastate operating revenues for electric (and gas prior to this period - June 2013) utilities derived in the last preceding calendar year minus the amount of General Assessment for the Department of Public Service costs for fiscal year. There will be no further activity in this account due to the end of the 18-A program in FY18. |
(h) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account represents the Refund/Surcharge for prior years’ TAC (Transportation Adjustment Clause) imbalances (i.e. over/under collection). The account is filed annually for the period of September – August and is submitted to the Public Service Commission by October 15th. |
(i) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The Company reconciles the commodity cost through the Electricity Supply Reconciliation Mechanism (ESRM) pursuant to PSC 220 Rule 46.3. The mechanism calculates the deferral using the prior month actual cost of purchase power and prior month sales revenue, thus there is one month lag from the accounting perspective. The purpose of this account is to remove one month lag by recording commodity timing adjustment. |
(j) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
On August 1, 2016, the Commission issued an order (Case 15-E-0302) to implement a Large-Scale Renewable Program and Clean Energy Standards (CES). Under this program, the company is required to purchase the percentage of Renewable Energy Credits to support new renewable generation sources and Zero Emission Credits to support Zero-Emission-nuclear power from NYSERDA and recover costs from ratepayers through commodity charges on customer bills. |
(k) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Stipulated in Attachment 1 to DPS-001 filed with the PSC, the Company recorded the adjustment to the revenue requirement in response to new federal tax rate effective January 2018. Effective April 2018 the federal tax law change is included in delivery rates under the new rate cases 17-E-0238 & 17-G-0239. |
(l) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Stipulated in Attachment 1 to DPS-001 filed with the PSC, the Company recorded the adjustment to the revenue requirement in response to new federal tax rate effective January 2018. Effective April 2018 the federal tax law change is included in delivery rates under the new rate cases 17-E-0238 & 17-G-0239. |
(m) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per rate case 17-G-0239, The Company's energy efficiency costs (ETIP) will be recovered in base rates instead of the Energy Efficiency Tracker Surcharge portion of SBC. Any under-expenditure in a given Rate Year will be carried forward and reconciled at the end of Rate Year Three. See Leaf 221.1 of PSC No. 220 for tariff details. On a monthly basis, the company will compare (1) Self-Administered Costs to (2) Rate Allowance. This deferral is downward only.On a monthly basis, carrying charges are calculated on the deferral balance using the "Other Customer Capital Rate," which is set annually by the PSC. |
(n) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per rate case 17-G-0239, The Company's energy efficiency costs (ETIP) will be recovered in base rates instead of the Energy Efficiency Tracker Surcharge portion of SBC. Any under-expenditure in a given Rate Year will be carried forward and reconciled at the end of Rate Year Three. See Leaf 221.1 of PSC No. 220 for tariff details. On a monthly basis, the Company will compare (1) Self-Administered Costs to (2) Rate Allowance. This deferral is downward only.On a monthly basis, carrying charges are calculated on the deferral balance using the "Other Customer Capital Rate," which is set annually by the PSC. |
(o) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Account is used by Energy Efficiency as a CoPay loan account to record theoretical borrowing from the relevant EE Fund Balance to fund EE CoPay loans and to track the outstanding loan portfolio balance for the CoPay loans given to customers who participate in the Energy Efficiency CoPay Loan program. This account serves as an indication of the amount "borrowed from the Company-E Demand Side Management Fund Balance" to fund Company-E CoPay loans. |
(p) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The Merchant Function Charge (MFC) is applied to the customer’s bill when the customer receives electricity supply from the Company. This charge includes costs associated with commodity related credit and collections, commodity related uncollectible expense, electric supply procurement costs and working capital for electric supply. This charge is applied to the Electricity Supply portion of a customer’s bill. This charge will not be billed if the customer chooses and alternate supplier. Based on rate case 17-E-0238 the Company is allowed to defer the difference between the revenue for the MFC and the revenue requirement. |
(q) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
NMPC Electric Tariff has a mechanism (PSC No. 220, Rule 57 effective April 2018 per Section 3.5, rate case 17-E-0238) that permits the Company to defer the difference between target revenues for delivery services and actual billed delivery service revenues. |
(r) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The Company conducted an A&G Capitalization study based on a time study completed during FY 2018 Q4 using CY 2017. This study resulted in the transfer of A&G costs charged to FERC accounts 920 and 921 to capital through the A&G overhead process at the individual regulated utility operating companies. An entry was recorded in March 2018 by Service Company to transfer A&G costs determined to be capitalized in FY 2018.
In March 2018, Niagara Mohawk’s total costs transferred by business segment was $10.796 million for electric distribution, $3.158 million for transmission and $3.217 million for gas. General Accounting prepared a corresponding entry to defer the A&G costs credited to expense and establish a regulatory liability for future benefit to the customer. Going forward the Company is continuing the transfer and defer of A&G costs that represent capitalized costs. |
(s) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The Company has implemented a downward only gas reconciliation mechanism which reconciles common plant and depreciation expenses as per rate case 12-G-0202 . Each rate year, the Company will reconcile its annual combined actual gas average net utility plant & depreciation expense revenue requirement to the combined target gas average net utility plant and depreciation expense revenue requirement. If targets exceed actual expenses a credit entry would be made to the account. There will be no further activity in this account due to the end of the rate case. |
(t) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The AffordAbility Program provides assistance to a small number of eligible low income residential consumers with arrears owed to the company who enter into a payment plan to make current payments and retire arrears. The AffordAbility Program discontinued new enrollment in its arrear forgiveness program in March 2017. The program discontinued as of 3/31/2018 per Rate Case 17-E-0238 & 17-G-0239. The program will be phased-out gradually, as existing customers participating in the program either complete the program, default, or voluntarily remove themselves from the program. The Company will reduce (debit) the current regulatory liability for the credits provided to grandfather customers. |
(u) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Section 10.1.19 of the Joint Proposal (JP) in rate case 17-E-0238 requires the Company to defer any reductions or additions to stranded costs associated with the implementation of JP for Nine Mile Point (Case 01-E-0011). |
(v) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Beginning January 1, 2018, Niagara Mohawk implemented the Low Income Energy Affordability Program (EAP), which was approved by case 14-M-0565. Per Rate Case 17-G-0239, each Rate Year beginning April 1 2018, the Company will fully reconcile Low Income Energy Affordability Program costs to the rate allowance of $14.905 million. Amount in excess of the rate allowance will be deferred for future recovery from customers. Any under-expenditure will be deferred for future use in a low income program. |
(w) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per Case 12-G-0202 Appendix 6 Schedule 12, the Company deferred the difference between costs (self-administered and System Benefit Charge) and revenue collections. This program was re-classed into its own account per Public Service Commission request in June 2018, with Principle to U2540002 and Interest to U2540280. Previously, it was deferred in combination with the Clean Energy Fund gas deferral. Per Case 14-M-0094, interest for Energy Efficiency Portfolio Standard and Clean Energy Fund is to be segregated in the company's books for future benefit to ratepayers. This account represents the Interest component of the Energy Efficiency Portfolio Standard (EEPS) deferral. |
(x) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account records net margins from off-system sales, capacity release credits other than those associated with assignments to ESCOs and any net margins derived from the optimization of the Company's portfolio of gas supply, transportation, storage and peaking contracts. These net margins will be shared at 85% to customers and 15% to the Company. This account is filed annually as part of the Gas Adjustment Clause (GAC) with the PSC in October for the preceding September through August time period. Once filed, the balance is transferred to the GAC Imbalance account to be refunded in the next calendar year (PSC 219 Rule 17.7; Case 17-G-0239). |
(y) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The accounts process Electricity Supply Reconciliation Mechanism (ESRM) performed per rule 46.3.1, 46.3.2, and 46.3.3 of PSC tariff 220. ESRM reconciles electricity supply revenues for the month to the market cost of electricity purchased. Costs in excess of revenues are collected from customers and revenues in excess of costs are credited to customers. ESRM also includes the cost of benefit of hedging contracts the Company entered into. |
(z) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Balance in account represents the cumulative Excess Storm Deferral. In accordance with the Case 17-E-0238, the Storm Reserve allowance amount for Electric incremental major storm costs has been updated to reflect the new allowance amount of $23 million per rate year. The allowance deferred in this account should be analyzed in conjunction with account 1823006, which holds the respective expenses for storm deferrals which match up with the allowances deferred in this account. Pursuant to the new electric rate case 17-E-0238, a pro-rata allocation of $32.76 million was transferred from the Excess Storm Reserve deferral balance to the Rate Plan Deferral Credit liability account. |
(aa) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The Company has implemented a downward only electric reconciliation mechanism which reconciles common plant and depreciation expenses as per rate case 12-E-0201. Each rate year, the Company will reconcile its annual combined actual electric average net utility plant & depreciation expense revenue requirement to the combined target electric average net utility plant and depreciation expense revenue requirement. There will be no further activity in this account due to the end of the rate case. |
(ab) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account contains the deferral balance of the Net Utility Plant tracker pertaining to the electric service for fiscal year 2018. As determined by rate case 15-M-0744, NMPC will reconcile its annual actual average net utility plant and depreciation expense revenue requirements to the target amounts. There will be no further activity in this account due to the close out of this balance using existing deferred credits specified in case 15-M-0744. |
(ac) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The objectives of accounting for income taxes are to recognize (a) the amount of taxes payable or refundable for the current year, and (b) deferred tax liabilities and assets for the future tax consequences of events that have been recognized in the Company's financial statements or tax returns. |
(ad) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account contains the deferral balance of the Net Utility Plant tracker pertaining to the gas service for fiscal year 2018. As determined by rate case 15-M-0744, NMPC will reconcile its annual actual average net utility plant and depreciation expense revenue requirements to the target amounts. There will be no further activity in this account due to the close out of this balance using existing deferred credits specified in case 15-M-0744. |
(ae) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The Case 15-G-0171 settled a pending penalty proceeding between The company and PSC DPS Staff concerning a natural gas incident that occurred at 310 Paige Street, Schenectady, New York on August 10, 2014. The Company committed to creating a $500,000 deferral, at shareholder expense, to be used to develop a remote meter valve technology pilot program. The pilot program would be supplemental to any existing research and development budget focused on remote meter valves. |
(af) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The account holds the deferral for Auction Debt True up deferral recovery mechanism stipulated by Section 10.1.5 of Joint Proposal (rate cases 17-E-0238 and 17-G-0239) for Rate Year One only. The Comapny's capital structure includes variable rate pollution control revenue bonds. The Company reconciles the actual interest expense for these bonds with the amount reflected in rates and defers the difference for refund to or recovery from customers. |
(ag) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per rate case 10-E-0050, the Company will hire one additional Consumer Advocate effective 2010. In the event that the Company does not hire an additional Consumer Advocate, the allowance will be deferred for future ratepayer use. Per rate case 12-E-0201, this deferral is discontinued and the deferred balance above is partially amortized per Section 3.4.1 and Appendix 5, Schedule 18. Per rate case 17-E-0238 effective April 2018, a pro-rata allocation was used to create the Rate Plan Deferral Credit per Appendix 2 Schedule 3.5 effective 2018. |
(ah) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Section 10.1 of Joint Proposal in rate case 17-E-0238 requires the company to defer interest on regulatory assets and liabilities. This account holds interest on these regulatory deferrals using the weighted average cost of capital (net of tax). |
(ai) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Schedule 17 of Appendix 5 of the Joint Proposal in rate case 12-E-0201 discontinues this deferral mechanism. In addition, the pre-existing deferred amount is partially amortized per Section 3.4.1 & Appendix 5, Schedule 18. Remaing balance subject to pro-rata deferral, $1.26 million used to create the Electric Rate Plan Deferral Credit per rate case 17-E-0238 Appendix 2 Schedule 3.5 effective April 2018. |
(aj) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Schedule 17 of Appendix 5 of the Joint Proposal in rate case 12-E-0201 discontinues this deferral mechanism. In addition, the pre-existing deferred amount is partially amortized per Section 3.4.1 & Appendix 5, Schedule 18. Remainning balance subject to pro-rata deferral, a portion was used to create the Electric Rate Plan Deferral Credit per rate case 17-E-0238 per Appendix 2 Schedule 3.5 effective 2018. |
(ak) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Schedule 12 of Appendix 6 of the Joint Proposal in rate case 12-G-0202 discontinues this deferral mechanism. In addition, the pre-existing deferred amounts are partially amortized per Section 4.4.1 and Appendix 6, Schedule 13. Remaing balance subject to pro-rata deferral was used to create the Gas Rate Plan Deferral Credit per rate case 17-G-0239 Appendix 3 Schedule 2 and 3 effective April 2018. |
(al) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account records (1) the current year's Net Revenue Sharing (NRS) deferral and (2) the amortization of prior year NRS imbalances (i.e. net over or under collections). In accordance with rate case 17-G-0239 and the PSC 219 tariff (Rule 26), the Company sets delivery revenue targets for SC 6 and combined SC9/ SC14 service classes each rate year and reconciles actual fiscal year revenues to these targets. The Company shares with participating service classes of customers 90% of the difference vs targets in SC 6 revenues and 100% of the difference in the combined SC9/14 revenues vs targets. Additionally, the annual filing with the PSC occurs during June of each year, with new rates effective August 1st. |
(am) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
In accordance with rate cases 17-E-0238 & 17-G-0239, Section 10.1.24, this account represents the accrued unbilled revenue Deferral (Gas Only), the Company will continue its current deferral practice concerning accrued unbilled revenues pursuant to the PSC’s August 30, 1988 Order in Case 29670. No carrying charges will be calculated for accrued unbilled revenues. |
(an) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Balances reflects penalties relating to operations for the the Distribution, Sub-Transmissions projects, and Capital Projects that did not meet the PSC Estimating compliance target standards. Balance of this regulatory liabiltiy will decline as penalties are paid out via billing. Respective penalties have been incurred as per rate cases 10-E-0050, 12-E-0201, and 15-M-0744. |
(ao) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account represents Gas Contigency Reserve Per rate case 17-G-0239 (Appendix 6, Schedule 1, Page 1 of 2). This reserve is subject to disposition in future rate case. |
(ap) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Balance reflects penalties relating to operations for the Gas Quality Assurance & Safety Program projects that did not meet the PSC Estimating compliance target standards and Gas Safety & Reliability Performance Metric. The PSC has the right to enforce penalties on the Company based on operation performance. The accumulated liability in this account can be drawn down through pro-rata allocation and others offsets as set forth in PSC orders in which penalties are refunded to customers. |
(aq) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Schedule 12 of Appendix 6 of the Joint Proposal in rate case 12-G-0202 discontinues this deferral mechanism. In addition, the pre-existing deferred amounts are partially amortized per Section 4.4.1 and Appendix 6, Schedule 13. This mechanism is discontinued under cases 17-E-0238 & 17-G-0239. |
(ar) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Schedule 17 of Appendix 5 of the Joint Proposal in Case 12-E-0201 discontinues this deferral mechanism. In addition, the pre-existing deferred amount is partially amortized per Section 3.4.1 & Appendix 5, Schedule 18. The balance subject to pro-rata deferral, $2.5 million was transferred to the Electric Rate Plan Deferral Credit per rate case 17-E-0238 Appendix 2 Schedule 3.5 effective April 2018. |
(as) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account balance represents the deferral associated with the Merchant Function Charge (MFC) as per rate case 17-G-0239. The MFC deferral is calculated by comparing the (1) actual recoveries associated with various gas commodity related cost components (Gas Supply Procurement, Return Requirement on Gas Storage Inventory and Commodity Related Credit and Collection Expenses) to (2) forecast. The MFC account balance is filed annually for the fiscal year period (April - March) and is submitted to the PSC in May. The balance is then transferred to an Imbalance regulatory account (i.e. net under- or over-recovered position vs forecast) and is recovered/refunded from/to customers commencing in June and ending in May. |
(at) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Section 10.1.6 of the Joint Proposals of 17-E-0238 and 17-G-0239 provides the recoveries of Site Investigaton and Remediation(SIR) expenses. The Company will reconcile the expense to the annual rate allowance of $27.321 million for electric and $4.821 million for gas. Any under- or over-expenditures will be deferred for future refund to, or recovery from customers. |
(au) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account holds the deferral balance for the Transmission Revenue Adjustment Clause (TRAC). The TRAC deferral is the difference between the forecast based on transmission revenue credits in delivery rates and actual transmission revenue realized. The TRAC is defined per rate case 17-E-0238 and PSC Tariff 220, Rule 43 effective April 2018. |
(av) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per Joint Proposal 12-M-0447, a sales tax refund from the New York State Department of Taxation and Finance in the amount of $1.2 million would be allocated for the benefit of ratepayers through a deferral mechanism subject to carrying charges. Pursuant to the new electric and gas rates cases 17-E-0238 & 17-G-0239, this mechanism is discontinued and the Company was authorized to create a Rate Plan Deferral Credit to promote rate stability and mitigate bill impacts for customers. In April 2018, $0.869 million was transferred from the NYS Sales Tax Refund deferral balance to the Rate Plan Deferral Credit. |
(aw) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The Economic Development Fund Program provides discounted electric delivery rates to qualified customers. National Grid will continue its Economic Development Fund Program. Each Rate Year, the Company will fully reconcile economic development discounts to the amount reflected in rates ($2.193 million in Rate Year One, $2.120 million in Rate Year Two and $1.721 million in Rate Year Three) for refund to or recovery from customers. Refer to Economic Development Fund (10.1.3) rate cases 17-E-0238 and 17-G-0239. |
(ax) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Schedule 12 of Appendix 6 of the Joint Proposal in Case 12-G-0202 discontinues this deferral mechanism. In addition, the pre-existing deferred amounts are partially amortized per Sections 4.4.1 and Appendix 6, Schedules 13. Remaing balance subject to pro-rata deferral, a portion was used to create the Gas Rate Plan Deferra Credit per rate case 17-G-0239 per Appendix 3 Schedule 2 and 3 effective April 2018. |
(ay) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account records deferral of recoveries from customers through surcharge as allowed under: Case 99-G-1369 and continued under CASE 17-G-0239 Joint Proposal page 76. These recoveries are meant to compensate the company for specific R&D expenditures related to Millenium projects. The account is reconciled and filed annually for the period of (Jan- Dec) and submitted to the PSC at January 1. In April 2018, Millenium R&D's share of the one-time Gas Rate Plan Deferral Credit was applied to the deferral balance which increased deferred liability by $0.341 million. |
(az) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per rate case 15-M-0744,the Company is allowed to recover 100 percent of the revenue requirement associated with these proposed capital expenditures. It is reasonable for customers to receive the entire tax benefit associated with bonus depreciation from the expenditures. This account holds the deferred tax benefit for the electric business that is owed to customers. Pursuant to Case 17-E-0238, the balance was reduced by pro-rata Electric Rate Plan Deferral Credit in April 2018. There will be no further activity in this account due to the end of the rate case. |
(ba) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per rate case 15-M-0744,the Company is allowed to recover 100 percent of the revenue requirement associated with these proposed capital expenditures. It is reasonable for customers to receive the entire tax benefit associated with bonus depreciation from the expenditures. This account holds the deferred tax benefit for the gas business that is owed to customers. Pursuant to case 17-E-0238, the balance was reduced by pro-rate Gas Rate Plan Deferral Credit in April 2018. There will be no further activity in this account due to the end of the rate case. |
(bb) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Regulatory liability relates to Internal Reserve Carrying Charges at the time of the Company acquisition that were initially recorded to the Company's pension liability. Pursuant to Case 17-E-0238, the balance was reduced by pro-rata Rate Plan Deferral Credit in April 2018. |
(bc) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
As commodity costs, including realized gains and losses on commodity derivatives, are refunded to or recovered from customers through the Company's gas and electric cost recovery mechanisms, a regulatory asset or liability is recorded as an offset to the unrealized gain or loss on a derivative asset in accordance with ASC 980 under US GAAP. |
(bd) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Schedule 12 of Appendix 6 of the Joint Proposal in rate case 12-G-0202 discontinues this deferral mechanism. In addition, the pre-existing deferred amounts are partially amortized per Section 4.4.1 and Appendix 6, Schedule 13. The balance was further reduced by pro-rata deferral used to create the Gas Rate Plan Deferral Credit per rate case 17-G-0239 Appendix 3 Schedule 2 and 3 in April 2018. |
(be) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
As commodity costs, including realized gains and losses on commodity derivatives, are refunded to or recovered from customers through the Company's gas and electric cost recovery mechanisms, a regulatory asset or liability is recorded as an offset to the unrealized gain or loss on a derivative asset in accordance with ASC 980 under US GAAP. |
(bf) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Section 10.1.17 of the Joint Proposal in Case 17-E-0238 permits the Company to accrue and amortize voltage migration fee amounts collected pursuant to PSC 220 Rule 44.2. Pursuant to Case 17-E-0238, the balance was reduced by Pro-rata Electric Rate Plan Deferral Credit in April 2018. |
(bg) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The Company's Gas Tariff has a mechanism (PSC No. 219, Rule 32 effective April 2018 per rate case 17-G-0239) that permits the Company to defer the difference between revenue per customer targets and actual revenues. |
(bh) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The account holds the deferral for Auction Debt True up deferral recovery mechanism stipulated by Section 10.1.5 of Joint Proposal (rate cases 17-E-0238 - Electric and 17-G-0239 - Gas) for Rate Year One only. Niagara Mohawk's capital structure includes variable rate pollution control revenue bonds. The Company reconciles the actual interest expense for these bonds with the amount reflected in rates and defer the difference for refund to or recovery from customers. Pursuant to PSC 220 Rule 44.2. Pursuant to Case 17-G-0239, the balance was redeuced by Pro-rata Gas Rate Plan Deferral Credit in April 2018. |
(bi) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Balance in account represents the Company's Fed Tax Refund 1991-1995 as per rate case 09-M-0554. This joint proposal resolves a dispute between staff and the Company as to the disposition of Federal Income Tax Return and the associate interest received by the Company from the IRS. Per rate cases 12-G-020, Appendix 6 Scheduled 13, $6.7 million is being amortized in the Pro-Rata Allocations of deferral credits for this account. Pursuant to rate case 17-G-0239, this mechanism is discontinued and the Company was authorized to create an Gas Rate Plan Deferral Credit to promote rate stability and mitigate bill impacts for customers. In April 2018, $2.800 million was transferred from the Federal Tax Refund balance to the Rate Plan Deferral Credit. |
(bj) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Section 6.1.1 of the Joint Proposal in Case 12-E-0201 and Section 7.1.1 of the Joint Proposal in Docket 12-G-0202 require the Company to defer the difference between actual Pension and OPEB costs and the annual revenue requirements for Pension and OPEB costs. Pursuant to the new electric and gas rate case 17-E-0238 & 17-G-0239, this mechanism is discontinued and the Company was authorized to create a Rate Plan Deferral Credit to promote rate stability and mitigate bill impacts for our customers. In April 2018, $226K was transferred from the Excess Storm Reserve deferral balance to the Rate Plan Deferral Credit liability account. |
(bk) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The Company entered into a 30 year Purchase Power Agreement (PPA) with the City of Oswego (City) to purchase power at fixed rate on October 5, 1993. A tracking provision in the agreement obligates the City to pay the Company the difference (being tracked in an Adjustment Account) between the fixed contract rate and the cost the Company would have incurred in producing the power itself. This difference has built in the Company’s favor over time. General Accounting has recorded a Regulatory Liability to track this difference. This account using a discounting schedule will wind down the regulatory liability balance based on the difference between the fixed contract rate and the internal production rate for monthly production and the amount withheld/prepaid monthly by the City. |
(bl) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account processes the NYPA (New York Power Authority) Hydropower Benefit reconciliation as per Rule 46.2.6 of PSC tariff 220. The NYPA Hydropower Benefit is low-cost hydropower that NIMO procures from NYPA. Monthly forecasts of contracts are trued up to the actual costs, market prices, and customer loads. The true ups are reflected on the customers' bills on a two month lag. |
(bm) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Section 10.1.1 of the Joint Proposal in rate cases 17-E-0238 & 17-E-0239 require the Company to continue defer the difference between actual Pension and OPEB costs and the annual revenue requirements for Pension and OPEB costs. |
(bn) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Section 10.1.1 of the Joint Proposal in rate cases 17-E-0238 & 17-E-0239 require the Company to continue defer the difference between actual Pension and OPEB costs and the annual revenue requirements for Pension and OPEB costs. |
(bo) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Beginning January 1, 2018 Niagara Mohawk implemented the Low Income Energy Affordability Program (EAP), which was approved by case 14-M-0565. Per Rate Case 17-E-0238, Section 10.1.2 and Section 13.1., each Rate Year, the Company will fully reconcile Energy Affordability Program costs to the rate allowance of $56.594 million. Amount in excess of the rate allowance will be deferred for future recovery from customers. Any under-expenditure will be deferred for future use in a low income program. |
(bp) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Section 10.1.6 of the Joint Proposals of 17-E-0238 and 17-E-0239 provides the recoveries of SIR expenses. The Company will reconcile the expense to the annual rate allowance of $27.321 million for electric and $4.821 million for gas. Any under- or over-expenditures will be deferred for future refund to, or recovery from, customers. |
(bq) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account processes the Legacy transition Charge (LTC) reconciliation as per Rule 46.2 PSC 220 tarif. The LTC is a true up mechanism for old purchases power contracts. |
(br) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account reconciles the deferred charges for RSS (Reliability Support Service) from Dunkirk paid to NRG Power Marketing, the related carrying charges, and recovery via revenue collection as per RSS agreement and rate case 12-E-0136. The reconciliation recovers only the total RSS cost exceeding the total 57 million. This mechanism is discontinued under Case 17-E-0238. |
(bs) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
In accordance with rate case 11-E-0535, the Company allows customers who received the benefit of reduced delivery rates for existing allocations of New York Power Authority Expansion Power and Replacement Power to be phased-in to full standard tariff delivery rates over a five or seven year period in order to allow these customers to plan and adjust for these electric bill impacts. The incremental revenues associated with these customers being phase-in to full standard tariff rates will be deferred for future benefit to customers. The balance was subject to pro-rata deferral, $3.5 million was used to create the Electric Rate Plan Deferral Credit per rate case 17-E-0238 Appendix 2 Schedule 3.5 in April 2018. |
(bt) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Balance in this account represents 18-A Temporary State Energy & Utility Service Conservation Assessment. This account was established based on a new Temporary State Energy & Utility Services Conservation Assessment effective April 1, 2009. The account records the deferral of the difference between the payment to PSC and the recovery of that payment. The account was filed annually to the PSC for the period of (July-June) submitted at June 15. There will be no further activity in this account due to the end of the 18-A program in Fiscal Year 2018. |
(bu) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per NMPC Case 12-E-0201, the Hydro One Network account was established to record $6.4 million of costs for the Hydro One project to be recovered over three years ($2.133 million per year) ending in Fiscal Year-End March 31, 2016. The estimated cost for Hydro One to recover of $6.4 million exceeds the actual cost resulting in a credit balance of $1.887 million. The balance was fully amortized in Fiscal Year 2016 and recorded as revenue. |
(bv) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Account holds NIMO's miscellaneous penalties for an ethics penalty, as per Case 12-M-0366 and a field violation penalty. Pursuant to the new gas rate case 17-G-0239, this mechanism is discontinued and the Company was authorized to create a Gas Rate Plan Deferral Credit to promote rate stability and mitigate bill impacts for our customers. In April 2018, a portion was transferred from the Misc Gas Penalties balance to the Gas Rate Plan Deferral Credit. |
(bw) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Schedule 12 of Appendix 6 of the Joint Proposal in Case 12-G-0202 discontinued this deferral mechanism. The pre-existing deferred amounts were reduced in April 2014 stipulated by Case 12-G-0202 and April 2018 stipulated by Case 17-G-0239 via pro-rata Gas Rate Plan Deferral Credits. |
(bx) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per rate case 14-E-0423 National Grid will continue its electric Demand Response Programs. Each Rate Year, the Company will fully reconcile its Demand Response Program costs to the amount reflected in rates. Amounts below or above value collected in rates will be deferred. Demand Response programs are as follow: Distribution Load Relief, Commercial System Relief, Direct Load Control. Interest will be provided by Electric Pricing for NIMO accounting to record at the end of each year. |
(by) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account contains the deferral balance of the Net Utility Plant tracker pertaining to the electric service for fiscal year 2017. As determined by rate case 15-M-0744, the Company will reconcile its annual actual average net utility plant and depreciation expense revenue requirements to the target amounts. There will be no further activity in this account due to the close out of this balance using existing deferred credits specified in case 15-M-0744. |
(bz) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account contains the deferral balance of the Net Utility Plant tracker pertaining to the gas service for fiscal year 2017. As determined by rate case 15-M-0744, the Company will reconcile its annual actual average net utility plant and depreciation expense revenue requirements to the target amounts. There will be no further activity in this account due to the end of the close out of this balance using existing deferred credits specified in case 15-M-0744. |
(ca) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per Case 14-M-0101 (“Proceeding on Motion of the Commission in Regard to Reforming the Energy Vision,” I/E 02/26/2015), Appendix C, NMPC will include a Self-Direct Program for large commercial and industrial customers in their energy efficiency portfolios no later than January 1, 2017. The Self-Direct Programs will allow large commercial and industrial customers to self-direct funds that would otherwise support the utilities’ portfolio of energy efficiency programs toward the customers’ unique suite of energy management investments, and allow the customers’ energy savings to count toward the utilities’ goals. The Self-Direct Program is implemented on a three-year cycle. Throughout the cycle, participants will be able to access at least 85% of their contributions to fund eligible projects, as agreed upon by the customer and the utility. Beginning January 1 of the first year of the cycle, the utility will regularly allocate a Self-Direct participant’s contributions to the utility’s energy efficiency portfolio into the participant’s Energy Savings Account (ESA), excluding the up-to 15% that is retained by the utility for program administration and EM&V For deferral purposes, 85% of monthly revenues from customers enrolled in the program are deferred in this account. |
(cb) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
As stipulated by the latest rate case 17-E-0238, Section 2.3, the Company created a new electric deferral credit of $44.88 million ("Rate Plan Settlement Credit"). This will resolve several pending issues addressed in the rate case proceeding. The Company will use $6.2 million of the electric Rate Plan Settlement Credit in each Rate Year ($18.6 Million in total) to amortize an equivalent amount of its undepreciated investment in pre-Automated Meter Reading meters. |
(cc) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
As stipulated by the latest rate order 17-G-0239, Section 2.3, the Company created a new gas deferral credit of $28.42 million ("Rate Plan Settlement Credit"). This will resolve several pending issues addressed in the rate case proceeding. The Company will utilize $8.971 million of the Gas Rate Plan Settlement Credits to fund Gas Safety pograms identified in section 7.5 of the Joint Proposal. The Company will also reserve $5 million to fund future gas safety and compliance improvement programs. |
(cd) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per rate case 17-E-0238, the Company's electric rates assume an annual rate of municipal conversions to LED technology of ten percent. To enable the Company to implement municipal conversions of up to 20 percent annually, the Company will implement an LED capital investment tracker for municipal LED street light conversions. Each rate year NMPC will reconcile the amount reflected in rates to convert municipal roadway luminaires to LEDs and defer for future recovery from or refund to customers, the revenue requirement impact of the over or under spend capped at an acnnual 20 percent LED conversion level. |
(ce) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per Case 17-E-0238, each rate year the company reconciles the actual level of transaction fee cost to the respective rate allowance($1.12 million for eletric and $0.414 million for gas). Any under-or over-recovery will be deferred for future refund to or recovery from customers, this balance represents the electric portion of the deferral. |
(cf) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per Case 17-G-0239, each rate year the company reconciles the actual level of transaction fee cost to the respective rate allowance($1.12 million for eletric and $0.414 million for gas). Any under-or over-recovery will be deferred for future refund to or recovery from customers, this balance represents the gas portion of the deferral. |
(cg) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
As set forth through rate case 17-E-0238, the Company will implement a downward-only reconciliation of transmission and distribution vegetation management program costs. The reconciliation will apply to the Company’s aggregate total vegetation management costs over the term of the Rate Plan.($71.844 million for FY19, $74.653 million for FY20, and $76.220 million for FY21). Any under-expenditure in total program costs in a given Rate Year will be carried forward and reconciled at the end of Rate Year Three. |
(ch) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per rate case 17-E-0238, the Company will implement a platform service revenue sharing mechanism for its electric business in the Rate Years. The Company will retain 20% of fees collected from vendors and defer the 80% for future credit to customers. |
(ci) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account contains the deferral balance of the Net Utility Plant tracker pertaining to the gas service for fiscal years 2019, 2020, and 2021. As determined by rate case 17-G-0239, the Company reconciles its annual actual average net utility plant and depreciation expense revenue requirements to the target amounts. |
(cj) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Balance in this account represents Economic Development Fund Program which provides discounted gas delivery rates to qualified customers. Each Rate Year, the Company will fully reconcile economic development discounts to the amount reflected in rates ($1.150 million, $0.935 million and $0.762 million) for refund to or recovery from customers as authorized in section 10.1.3 in rate case 17-G-0239. |
(ck) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Pursuant to rate case 17-G-0239, the Economic Development Grant program offers financial assistance for projects that promote the economic health of New York State by facilitating the creation and or retention of jobs or the increase of business activity in the State. This account contains the deferral balance for the Economic Development grant program deferral for gas, which is the difference between the cumulative allowance and the cumulative actual expenditures. The reconciliation is subject to a down-ward only reconciliation over the term of the rate plan. Any difference between the respective rate allowance and actual program costs in a given rate year will be carried forward and reconciled at the end of rate year Three, with any under-expenditure to be deferred for future use in the Economic Development Grant Programs. |
(cl) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The Economic Development Grant Program is funded by PSC in which the Company is funded grants to improve the economic state of the community. This account contains the deferral balance for the Economic Development grant program deferral for electric, which is the difference between the cumulative allowance (as allowed per the PSC) and the cumulative expenditures for the program. Pursuant to case 17-E-0238, the reconciliation is subject to downward-only reconciliations over the term of the rate plan. Any difference between the respective rate allowance and actual program costs in a given rate year will be carried forward and reconciled at the end of rate year Three, with any under-expenditure to be deferred for future use in the program. |
(cm) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The AffordAbility Program provides assistance to a small number of eligible low income residential consumers with arrears owed to the company who enter into a payment plan to make current payments and retire arrears. The AffordAbility Program discontinued new enrollment in its arrear forgiveness program in March 2017. This program was discontinued per rate cases 17-E-0238 & 17-G-0239. The program will be phased-out gradually, as existing customers participating in the program either complete the program, default, or voluntarily remove themselves from the program. |
(cn) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Balance in the account represents Property Tax Deferral (Gas) as per rate case 17-G-0239. As stated in Section 10.1.7 of the rate case, the Company will reconcile actual property tax expense to the rate allowance ($43.072 million, $45.311 million, and $47.730 million). The difference will be deferred for future refund to or recovery from customers. The difference between actual tax expense and the rate allowance will be shared 80/20 percent between customers and the Company respectively. In addition, the deferral credit balance was reduced by $9.006 million for a pro-rata allocation pursuant to rate case 17-G-0239, Appendix 5, Schedule 23. |
(co) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The account holds the deferral for Variable Pay - Gas, stipulated by the Niagara Mohawk’s Rate Case 17-G-0239, section 10.1.12 and Appendix 6, Schedule 12. Each rate year, the Company reconciles the actual variable compensation amount with the target amounts reflected in rates and defers for refund to customers any variable pay compensation reflected in rates that are not paid to employees. This is a downward only reconciliation. |
(cp) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The purpose of this account is to process rate case 12-E-0201 - NYPA Discount Reconciliation Section 6.2.1. The amount of NYPA Expansion Power, Replacement Power, and High Load Factor Power discounts are fully reconciled each rate year. Any differences between the actual discounts and the level reflected in rates will be deferred and recovered from or credited to customers on a monthly basis. Pursuant to the new electric rate case 17-E-0238, the Company was authorized to create an Electric Rate Plan Deferral Credit to promote rate stability and mitigate bill impacts for our customers. In April 2018, $0.999 million was transferred from the NYPA Discount deferral balance to the Electric Rate Plan Deferral Credit. |
(cq) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per rate case of 17-E-0238, this mechanism is discontinued, and carrying charges of deferral balance is continued but calculated separately in the Company's Community Carrying Charge account. The company was authorized per rate case 17-E-0238 to create a Rate Plan Deferral Credit to promote rate stability and mitigate bill impacts for customers. Accordingly, a portion was transferred from this account to the Eletric Rate Plan Deferral Credit. |
(cr) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per rate case of 17-E-0238, this mechanism is discontinued, and carrying charges of deferral balance is continued but calculated separately in the Company's Community Carrying Charge account. The company was authorized per rate case 17-E-0238 to create a Rate Plan Deferral Credit to promote rate stability and mitigate bill impacts for customers. Accordingly, a portion was transferred from this account to Electic Rate Plan Deferral Credit. |
(cs) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per rate case of 17-E-0238, this mechanism is discontinued, and carrying charges of deferral balance is continued but calculated separately in the Company's Community Carrying Charge account. The company was authorized per rate case 17-E-0238 to create a Rate Plan Deferral Credit to promote rate stability and mitigate bill impacts for customers. Accordingly, a portion was transferred from this account to Electric Rate Plan Deferral Credit. |
(ct) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per rate case of 17-E-0238, this mechanism is discontinued, and carrying charges of deferral balance is continued but calculated separately in the Company's Community Carrying Charge account. The company was authorized per rate case 17-E-0238 to create a Rate Plan Deferral Credit to promote rate stability and mitigate bill impacts for customers. Accordingly, a portion was transferred from this account to Electric Rate Plan Deferral Credit. |
(cu) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The purpose of this account is to record Federal Income Tax (FIT) repair cost, a deferred rate case liability for gas per rate case 12-G-0202, Section 7.2.4. Additionally, in accordance with Case 15-M-0744, this account was used as an offset to the recognition of the earned revenue requirement when analyzing the balance of the Net Utility Plant Depreciation (NUPD) Gas account. Pursuant to the new gas rate case 17-G-0239, this mechanism is discontinued and the Company was authorized to create an Gas Rate Plan Deferral Credit to promote rate stability and mitigate bill impacts for customers. In April 2018, $28.12 million was transferred from the FIT Repair Costs account to the Gas Rate Plan Deferral Credit. |
(cv) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The account holds Pro-Rata Allocation of Deferral Credits amortization stipulated by the latest Rate Case 17-E-0238. The Company will credit customers with a portion of the forecast electric deferral balance in amount of $200.4 Million. For the gradual transition to full cost-of-service rates, the credits are allocated (April 2018 - March 2022) to Rate Year One $116,916,000, Rate Year Two $59,295,000, Rate Year Three $19,460,000 and 12 months ending March 31, 2022 $4,729,000. The credits are calculated by taking a pro rata share from the overall projected deferred credit balances. |
(cw) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The account holds Pro-Rata Allocation of Deferral Credit to create the Gas Rate Plan Deferral Credit stipulated by the latest Rate Case 17-G-0239. The Company will credit customers with a portion of the forecast gas deferral balance in amount of $56.123 Million. For the gradual transition to full cost-of-service rates, the credits are allocated (April 2018 - March 2022) to Rate Year One $32.315 Million, Rate Year Two $16.924 Million, Rate Year Three $5.344 Million and 12 months ending March 31, 2022 $1.54 Millino. The credits are calculated by taking a pro rata share from the overall projected deferred credit balances. |
(cx) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
The purpose of this account is to process the Bonus Depreciation Adjustment. Per rate case 12-G-0202, this deferral is discontinued and the deferred balance is partially amortized per Section 4.4.1 and Appendix 6, Schedule 13. The remaining balance will be considered in future rate cases. Pursuant to case 17-G-0239, this mechanism is discontinued and the Company was authorized to create an Gas Rate Plan Deferral Credit to promote rate stability and mitigate bill impacts for customers. In April 2018, a portion was transferred from the Bonus Depreciation balance to the Gas Rate Plan Deferral Credit. |
(cy) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account balance represents the Refund/Surcharge for prior years’ Merchant Function Charge (MFC) imbalance account (i.e. net under- or over-recovered position vs forecast), plus associated carrying charges. The MFC account balance is filed annually for the fiscal year period (April - March) and is submitted to the PSC in May. |
(cz) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Section 10.1 of the Joint Proposal in Case 17-G-0239 requires the Company to defer interest on regulatory assets and liabilities. This account holds interest on regulatory liabilities (gas) using the pre-tax weighted average cost of capital rate authorized in the current rate case. |
(da) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
This account represents the Refund/Surcharge for prior years’ SPA (System Performance Adjustment) imbalances (i.e. over/under collection). This SPA account balance is filed annually for the period of September - August and is submitted to the PSC by October 15th. |
(db) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
In accordance with rate case 04-M-0159 - Proceeding on Motion of the Commission to Examine the Safety of Electric Transmission and Distribution Systems, the Company in this account addresses the disposition of savings resulting from the modified Electric Safety Standards through a deferral for customer benefit, inclusive of carrying charges. Pursuant to Case 15-M-0744, the balance at March 2018 was decreased offsetting the NUPD Reconciliation Mechanism in amount $8.234 million. Pursuant to Case 17-E-0238, the deferral was discontinued and the balance was further reduced by pro-rata deferred credit in amount $6.202 million. |
(dc) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per Case 17-G-0239, System Benefit Charge costs, which include the Clean Energy Fund (CEF) surcharge, will continue to be reconciled pursuant to PSC 219 Rule 31. The Company compares actual CEF expenditures (NYSERDA payment) to the actual CEF collections from customers. Carrying charges are calculated on the deferral balance using the other Customer Capital Rate (net of Tax), which is set annually by the PSC. |
(dd) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per Case 17-E-0238, SBC costs, which include the CEF surcharge, will continue to be reconciled pursuant to PSC 220 Rule 41. The Company will compares the actual CEF expenditures (NYSERDA Payments)to actual CEF collections. Carrying charges are calculated on the deferral balance using the Other Customer Capital Rate (net of tax), which is set annually by the PSC. |
(de) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
To recognize upfont the Tier Fall to Rotterdam Transmission Line total settlement amount (borne by shareholders) for incremental O&M cost on the maintenance of the steel structures on the Spier Falls to Ro Herdam Transmission line pursuant to case 10-T-0080, and amortization over the average service life of the assets. |
(df) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per Case 17-G-0239, SBC costs, which include the CEF surcharge, will continue to be reconciled pursuant to PSC 219 Rule 31. Carrying charges are calculated on the deferral balance using the Other Customer Capital Rate (net of tax), which is set annually by the PSC. Per Case 14-M-0094, interest for Energy Efficiency Portfolio Standard and CEF is to be segregated in the company's books for the future benefit of ratepayers. The deferred interest related to CEF was reclassified into a seperate account on the company's books in June 2018. |
(dg) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per Case 17-E-0238, System Benefit Charge costs, which include the Clean Energy Fund (CEF) surcharge, will continue to be reconciled pursuant to Public Service Commission 220 Rule 41. On a monthly basis, the Company will compare monthly amounts due to NYS Energy Research Development Authority (if any) to Actual CEF Collections/Revenues. On a monthly basis, carrying charges are calculated on the deferral balance using the “Other Customer Capital Rate,” which is set annually by the NY PSC. |
(dh) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities |
Per Case 17-E-0238, System Benefit Charge costs will continue to be reconciled pursuant to Public Service Commission 220 Rule 41. On a monthly basis, the Company will compare the sum of the Company’s Self-Administered Costs to Actual Collections/Revenues. On a monthly basis, carrying charges are calculated on the deferral balance using the “Other Customer Capital Rate,” which is set annually by the NY Public Service Commission.
Energy Efficiency Portfolio Standard interest was re-classed to a separate GL account per Public Service Commission request in July 2018.
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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: |
Electric Operating Revenues |
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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 |
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2 |
ResidentialSalesAbstract (440) Residential Sales |
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3 |
CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales |
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4 |
CommercialSalesAbstract Small (or Comm.) (See Instr. 4) |
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5 |
IndustrialSalesAbstract Large (or Ind.) (See Instr. 4) |
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6 |
PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting |
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7 |
OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities |
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8 |
SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways |
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9 |
InterdepartmentalSalesAbstract (448) Interdepartmental Sales |
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10 |
SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers |
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11 |
SalesForResaleAbstract (447) Sales for Resale |
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12 |
SalesOfElectricityAbstract TOTAL Sales of Electricity |
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13 |
ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds |
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14 |
RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Net of Prov. for Refunds |
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15 |
OtherOperatingRevenuesAbstract Other Operating Revenues |
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16 |
ForfeitedDiscounts (450) Forfeited Discounts |
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17 |
MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues |
(a) |
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18 |
SalesOfWaterAndWaterPower (453) Sales of Water and Water Power |
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19 |
RentFromElectricProperty (454) Rent from Electric Property |
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20 |
InterdepartmentalRents (455) Interdepartmental Rents |
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21 |
OtherElectricRevenue (456) Other Electric Revenues |
(b) |
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22 |
RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others |
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23 |
RegionalTransmissionServiceRevenues (457.1) Regional Control Service Revenues |
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24 |
MiscellaneousRevenue (457.2) Miscellaneous Revenues |
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25 |
OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues |
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25.1 |
OtherMiscellaneousOperatingRevenues (456.2) Revenues from Distribution of Electricity |
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26 |
OtherOperatingRevenues TOTAL Other Operating Revenues |
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27 |
ElectricOperatingRevenues TOTAL Electric Operating Revenues |
|
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: |
ELECTRIC PRODUCTION, OTHER POWER SUPPLY EXPENSES, TRANSMISSION AND DISTRIBUTION EXPENSES | ||
Report Electric production, other power supply expenses, transmission, regional market, and distribution expenses through the reporting period. |
||
Line No. |
Account (a) |
Year to Date
Quarter (b) |
1 |
PowerProductionExpensesAbstract 1. POWER PRODUCTION AND OTHER SUPPLY EXPENSES |
|
2 |
SteamPowerGenerationOperationsExpense Steam Power Generation - Operation (500-509) |
|
3 |
SteamPowerGenerationMaintenanceExpense Steam Power Generation – Maintenance (510-515) |
|
4 |
PowerProductionExpensesSteamPower Total Power Production Expenses - Steam Power |
|
5 |
NuclearPowerGenerationOperationsExpense Nuclear Power Generation – Operation (517-525) |
|
6 |
NuclearPowerGenerationMaintenanceExpense Nuclear Power Generation – Maintenance (528-532) |
|
7 |
PowerProductionExpensesNuclearPower Total Power Production Expenses - Nuclear Power |
|
8 |
HydraulicPowerGenerationOperationsExpense Hydraulic Power Generation – Operation (535-540.1) |
|
9 |
HydraulicPowerGenerationMaintenanceExpense Hydraulic Power Generation – Maintenance (541-545.1) |
|
10 |
PowerProductionExpensesHydraulicPower Total Power Production Expenses - Hydraulic Power |
|
11 |
RentsOtherPowerGeneration Other Power Generation – Operation (546-550.1) |
|
12 |
MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration Other Power Generation – Maintenance (551-554.1) |
|
13 |
MaintenanceOfMiscellaneousOtherPowerGenerationPlant Total Power Production Expenses - Other Power |
|
14 |
OtherPowerSuplyExpensesAbstract Other Power Supply Expenses |
|
15 |
PurchasedPower (555) Purchased Power |
|
15.1 |
PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations |
|
16 |
SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching |
|
17 |
OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses |
|
18 |
OtherPowerSupplyExpense Total Other Power Supply Expenses (line 15-17) |
|
19 |
PowerProductionExpenses Total Power Production Expenses (Total of lines 4, 7, 10, 13 and 18) |
|
20 |
TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES |
|
21 |
TransmissionExpensesOperationAbstract Transmission Operation Expenses |
|
22 |
OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering |
|
24 |
LoadDispatchReliability (561.1) Load Dispatch-Reliability |
|
25 |
LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System |
|
26 |
LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling |
|
27 |
SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services |
|
28 |
ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development |
|
29 |
TransmissionServiceStudies (561.6) Transmission Service Studies |
|
30 |
GenerationInterconnectionStudies (561.7) Generation Interconnection Studies |
|
31 |
ReliabilityPlanningAndStandardsDevelopmentServices (561.8) Reliability, Planning and Standards Development Services |
|
32 |
StationExpensesTransmissionExpense (562) Station Expenses |
|
32.1 |
OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment |
|
33 |
OverheadLineExpense (563) Overhead Lines Expenses |
|
34 |
UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses |
|
35 |
TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others |
|
36 |
MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses |
|
37 |
RentsTransmissionElectricExpense (567) Rents |
|
38 |
OperationSuppliesAndExpensesTransmissionExpense (567.1) Operation Supplies and Expenses (Non-Major) |
|
39 |
TransmissionOperationExpense TOTAL Transmission Operation Expenses (Lines 22 - 38) |
|
40 |
TransmissionMaintenanceAbstract Transmission Maintenance Expenses |
|
41 |
MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering |
|
42 |
MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures |
|
43 |
MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware |
|
44 |
MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software |
|
45 |
MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment |
|
46 |
MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant |
|
47 |
MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment |
|
47.1 |
MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment |
|
48 |
MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines |
|
49 |
MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines |
|
50 |
MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant |
|
51 |
MaintenanceOfTransmissionPlant (574) Maintenance of Transmission Plant |
|
52 |
TransmissionMaintenanceExpenseElectric TOTAL Transmission Maintenance Expenses (Lines 41 – 51) |
|
53 |
TransmissionExpenses Total Transmission Expenses (Lines 39 and 52) |
|
54 |
RegionalMarketExpensesAbstract 3. REGIONAL MARKET EXPENSES |
|
55 |
RegionalMarketExpensesOperationAbstract Regional Market Operation Expenses |
|
56 |
OperationSupervision (575.1) Operation Supervision |
|
57 |
DayAheadAndRealTimeMarketAdministration (575.2) Day-Ahead and Real-Time Market Facilitation |
|
58 |
TransmissionRightsMarketAdministration (575.3) Transmission Rights Market Facilitation |
|
59 |
CapacityMarketAdministration (575.4) Capacity Market Facilitation |
|
60 |
AncillaryServicesMarketAdministration (575.5) Ancillary Services Market Facilitation |
|
61 |
MarketMonitoringAndCompliance (575.6) Market Monitoring and Compliance |
|
62 |
MarketFacilitationMonitoringAndComplianceServices (575.7) Market Facilitation, Monitoring and Compliance Services |
|
63 |
RegionalMarketOperationExpense Regional Market Operation Expenses (Lines 55 - 62) |
|
64 |
RegionalMarketExpensesMaintenanceAbstract Regional Market Maintenance Expenses |
|
65 |
MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses (576.1) Maintenance of Structures and Improvements |
|
66 |
MaintenanceOfComputerHardware (576.2) Maintenance of Computer Hardware |
|
67 |
MaintenanceOfComputerSoftware (576.3) Maintenance of Computer Software |
|
68 |
MaintenanceOfCommunicationEquipmentRegionalMarketExpenses (576.4) Maintenance of Communication Equipment |
|
69 |
MaintenanceOfMiscellaneousMarketOperationPlant (576.5) Maintenance of Miscellaneous Market Operation Plant |
|
70 |
RegionalMarketMaintenanceExpense Regional Market Maintenance Expenses (Lines 65-69) |
|
71 |
RegionalMarketExpenses TOTAL Regional Control and Market Operation Expenses (Lines 63,70) |
|
72 |
DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES |
|
73 |
DistributionOperationExpensesElectric Distribution Operation Expenses (580-589) |
|
74 |
DistributionMaintenanceExpenseElectric Distribution Maintenance Expenses (590-598) |
|
75 |
DistributionExpenses Total Distribution Expenses (Lines 73 and 74) |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
Report the amount of expenses for customer accounts, service, sales, and administrative and general expenses year to date. |
||
Line No. |
Account (a) |
Year to Date
Quarter (b) |
- |
CustomerAccountsExpensesOperationsAbstract Operation |
|
1 |
CustomerAccountExpenses (901-905) Customer Accounts Expenses |
|
2 |
CustomerServiceAndInformationExpenses (907-910) Customer Service and Information Expenses |
|
3 |
SalesExpenses (911-917) Sales Expenses |
|
4 |
AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES |
|
5 |
AdministrativeAndGeneralExpensesOperationAbstract Operation |
|
6 |
AdministrativeAndGeneralSalaries (920) Administrative and General Salaries |
|
7 |
OfficeSuppliesAndExpenses (921) Office Supplies and Expenses |
|
8 |
AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit |
|
9 |
OutsideServicesEmployed (923) Outside Services Employed |
|
10 |
PropertyInsurance (924) Property Insurance |
|
11 |
InjuriesAndDamages (925) Injuries and Damages |
|
12 |
EmployeePensionsAndBenefits (926) Employee Pensions and Benefits |
|
13 |
FranchiseRequirements (927) Franchise Requirements |
|
14 |
RegulatoryCommissionExpenses (928) Regulatory Commission Expenses |
|
15 |
DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr. |
|
16 |
GeneralAdvertisingExpenses (930.1) General Advertising Expenses |
|
17 |
MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses |
|
18 |
RentsAdministrativeAndGeneralExpense (931) Rents |
|
19 |
AdministrativeAndGeneralOperationExpense TOTAL Operation (Total of lines 6 thru 18) |
|
20 |
AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance |
|
21 |
MaintenanceOfGeneralPlant (935) Maintenance of General Plant |
|
22 |
AdministrativeAndGeneralExpenses TOTAL Administrative and General Expenses (Total of lines 19 and 21) |
|
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 |
(a) |
|
(i) |
|
(j) |
|
(k) |
|
|
(q) |
|
|||
2 |
(b) |
|
|
|
|
|
|
|||||||
3 |
|
|
|
|
|
|
|
|
(r) |
|
||||
4 |
|
|
|
|
|
|
|
|||||||
5 |
|
|
|
|
|
|
|
|
(l) |
|
||||
6 |
|
|
|
|
|
|
|
(s) |
|
|||||
7 |
(c) |
|
|
|
|
|
|
|
(m) |
|
||||
8 |
|
|
|
|
|
|
|
|
(n) |
|
||||
9 |
(d) |
|
|
|
|
|
|
|
(o) |
|
||||
10 |
|
|
|
|
|
|
|
|
|
(t) |
|
|||
11 |
|
|
|
|
|
|
|
|||||||
12 |
|
|
|
|
|
|
|
|||||||
13 |
|
|
|
|
|
|
|
|||||||
14 |
(e) |
|
|
|
|
|
|
|||||||
15 |
|
|
|
|
|
|
|
(p) |
|
|||||
16 |
(f) |
|
|
|
|
|
|
|
|
(u) |
|
|||
17 |
(g) |
|
|
|
|
|
|
|
|
(v) |
|
|||
18 |
|
|
|
|
|
|
|
|||||||
19 |
|
|
|
|
|
|
|
|||||||
20 |
|
|
|
|
|
|
|
|||||||
21 |
|
|
|
|
|
|
|
|||||||
22 |
|
|
|
|
|
|
|
|||||||
23 |
|
|
|
|
|
|
|
|||||||
24 |
|
|
|
|
|
|
|
|||||||
25 |
|
|
|
|
|
|
|
(w) |
|
|||||
26 |
|
|
|
|
|
|
|
(x) |
|
|||||
27 |
|
|
|
|
|
|
|
(y) |
|
|||||
28 |
|
|
|
|
|
|
|
|||||||
29 |
|
|
|
|
|
|
|
(z) |
|
|||||
30 |
|
|
|
|
|
|
|
(aa) |
|
|||||
31 |
(h) |
|
|
|
|
|
|
(ab) |
|
|||||
32 |
|
|
|
|
|
|
|
(ac) |
|
|||||
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 |
TSC - Transmission Service Charge |
(b) Concept: PaymentByCompanyOrPublicAuthority |
NYPA - New York Power Authority |
(c) Concept: PaymentByCompanyOrPublicAuthority |
LIPA - Long Island Power Authority |
(d) Concept: PaymentByCompanyOrPublicAuthority |
NYSEG - New York Gas and Electric |
(e) Concept: PaymentByCompanyOrPublicAuthority |
OATT - Open Access Transmission Tariff |
(f) Concept: PaymentByCompanyOrPublicAuthority |
ISO- Independent System Operator |
(g) Concept: PaymentByCompanyOrPublicAuthority |
New York Municipal Power Authority |
(h) Concept: PaymentByCompanyOrPublicAuthority |
LLC - Limited Liability Company |
(i) Concept: TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName |
NYPA NYS - New York Power Authority New York State |
(j) Concept: RateScheduleTariffNumber |
NYISO OATT - New York Independent System Operator Open Access Transmission Tariff |
(k) Concept: TransmissionPointOfDelivery |
Muni - Municipals |
(l) Concept: DemandChargesRevenueTransmissionOfElectricityForOthers |
Grandfathered Wheeling Charges |
(m) Concept: DemandChargesRevenueTransmissionOfElectricityForOthers |
Grandfathered Wheeling Charges |
(n) Concept: DemandChargesRevenueTransmissionOfElectricityForOthers |
Grandfathered Wheeling Charges |
(o) Concept: DemandChargesRevenueTransmissionOfElectricityForOthers |
Grandfathered Wheeling Charges |
(p) Concept: DemandChargesRevenueTransmissionOfElectricityForOthers |
Rochester Gas & Electric Transmission Capacity Charge |
(q) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers |
Transmission Service Charge |
(r) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers |
Grandfathered Wheeling Charges |
(s) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers |
Grandfathered Wheeling Charges |
(t) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers |
Grandfathered Wheeling Charges |
(u) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers |
New York Independent System Operator External transactions - TSC (Transmission Service Charge) |
(v) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers |
Transmission Service Charge |
(w) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers |
Operating & Maintenance Expense Agreement |
(x) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers |
Operating & Maintenance Expense Agreement |
(y) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers |
Operating & Maintenance Expense Agreement |
(z) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers |
Operating & Maintenance Expense Agreement |
(aa) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers |
Operating & Maintenance Expense Agreement |
(ab) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers |
Operating & Maintenance Expense Agreement |
(ac) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers |
Operating & Maintenance Expense Agreement |
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 |
(a) |
|
(b) |
|
|
2 |
|
|
|
||
3 |
|
|
|
|
|
4 |
|
|
|
|
|
40 |
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: TransmissionPaymentByCompanyOrPublicAuthority |
TCC - Transmission Congestion Contract |
(b) Concept: RateScheduleTariffNumber |
NYISO - New York Independent System Operator OATT - Open Acess Transmission Tariff |
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 | ||||||||
4 | ||||||||
5 | ||||||||
6 | ||||||||
7 | ||||||||
8 | ||||||||
9 | ||||||||
10 | ||||||||
11 | ||||||||
12 | ||||||||
13 | ||||||||
14 | ||||||||
15 | ||||||||
16 | ||||||||
TOTAL |
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
||||||
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 |
General Plant |
|
|
|||
10 |
Common Plant-Electric |
|
|
|||
11 |
TOTAL |
|
|
|
|
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 |
|
|
|
|
|
46 | TOTAL |
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
||||||
Line No. |
MonthAxis Month (a) |
Total Monthly Energy (MWH) (b) |
Monthly Non-Requirements Sales for Resale & Associated Losses (c) |
MonthlyPeakLoad Monthly Peak Megawatts (See Instr. 4) (d) |
DayOfMonthlyPeak Monthly Peak Day of Month (e) |
HourOfMonthlyPeak Monthly Peak Hour (f) |
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 |
|
||||
11 |
September |
|
||||
12 |
Total for Quarter 3 |
|
||||
41 |
Total |
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 |
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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) |
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 |
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1 |
January |
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2 |
February |
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3 |
March |
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4 |
Total for Quarter 1 |
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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 |
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 |
Q1 2018 reporting data is not available due to the restructure of the NYISO server. The server restructure caused disruption in the automated data extraction process and Q1 2018 data could not be extracted. The error was resolved at the beginning of Q2 2018 and the data became available. |
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: Enter System |
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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 |
|||||||||
11 |
September |
|||||||||
12 |
Total for Quarter 3 |
|||||||||
13 |
October |
|||||||||
14 |
November |
|||||||||
15 |
December |
|||||||||
16 |
Total for Quarter 4 |
|||||||||
17 |
Total Year to Date/Year |