FERC Form

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

GENERAL INFORMATION

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

What and Where to Submit

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

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

The CPA Certification Statement should:

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

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

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

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

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

GENERAL INSTRUCTIONS

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

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

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

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

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

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

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

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

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

AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment.

DEFINITIONS

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

EXCERPTS FROM THE LAW

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

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

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

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

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

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

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

"Sec. 304.

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

"Sec. 309.

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

GENERAL PENALTIES

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

FERC FORM NO.

1/3-Q

REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER

Identification

01 Exact Legal Name of Respondent

Nevada Power Company, d/b/a NV Energy

02 Year/ Period of Report

End of:

2022

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

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

6226 West Sahara Avenue, Las Vegas, NV 89146

05 Name of Contact Person

Danielle Lewis

06 Title of Contact Person

Rev Req and Regulatory Mgr

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

6100 Neil Road, Reno, NV 89511

08 Telephone of Contact Person, Including Area Code

(775) 834-4976

09 This Report is An Original / A Resubmission

(1)

☑ An Original

(2)

☐ A Resubmission

10 Date of Report (Mo, Da, Yr)

05/27/2022

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.

01 Name

Michael E. Cole

02 Title

SVP, CFO and Treasurer

03 Signature

/s/ Michael E. Cole

04 Date Signed (Mo, Da, Yr)

05/27/2022

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

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

List of Schedules
Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".
Line No.	Title of Schedule (a)	Reference Page No. (b)	Remarks (c)
	ScheduleIdentificationAbstract Identification	1
	ScheduleListOfSchedulesAbstract List of Schedules (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
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	None
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	NA
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	NA

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

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

1. None.
2. None.
3. None.
4. None.
5. None.
6. Refer to Page 122, Recent Financing Transaction note of Notes to Financial Statements in this FERC Form 3-Q for information regarding legal proceedings affecting Nevada Power Company.
7. None.
8. None.
9. Refer to Page 122, Commitments and Contingencies note of Notes to Financial Statements in this FERC Form 3-Q for information regarding legal proceedings affecting Nevada Power Company.
10. None.
12. NA.
13. Effective February 28, 2022, Jesse E. Murray, formerly Vice President, Gas Delivery was named Vice President, Electric Delivery and Natural Disaster Protection. Effective February 28, 2022, Shahzad M. Lateef, formerly Vice President, Electric Delivery was named Senior Project Director. Effective February 28, 2022, David W. Ulozas, formerly Senior Vice President, Renewable and Origination was named Senior Vice President, Energy Supply. Effective February 28, 2022, Brandon Barkhuff, formerly Vice President, General Counsel, Corporate Secretary and Chief Compliance Officer was named Senior Vice President, General Counsel, Corporate Secretary and Chief Compliance Officer. Effective February 28, 2022, Michael E. Cole, formerly Vice President, Chief Financial Officer and Treasurer was named Senior Vice President, Chief Financial Officer and Treasurer. Effective February 28, 2022, Matt Johns was named Vice President, Environmental and Lands. Effective March 11, 2022, Dariusz Rekowski retired from his position as Vice President of Generation.
14. NA.

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlant Utility Plant (101-106, 114)	200	10,466,325,456	10,394,969,372
3	ConstructionWorkInProgress Construction Work in Progress (107)	200	341,237,004	244,484,807
4	UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3)		10,807,562,460	10,639,454,179
5	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)	200	3,823,966,074	3,748,805,035
6	UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5)		6,983,596,386	6,890,649,144
7	NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)	202
8	NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly Nuclear Fuel Materials and Assemblies-Stock Account (120.2)
9	NuclearFuelAssembliesInReactorMajorOnly Nuclear Fuel Assemblies in Reactor (120.3)
10	SpentNuclearFuelMajorOnly Spent Nuclear Fuel (120.4)
11	NuclearFuelUnderCapitalLeases Nuclear Fuel Under Capital Leases (120.6)
12	AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)	202
13	NuclearFuelNet Net Nuclear Fuel (Enter Total of lines 7-11 less 12)
14	UtilityPlantAndNuclearFuelNet Net Utility Plant (Enter Total of lines 6 and 13)		6,983,596,386	6,890,649,144
15	OtherElectricPlantAdjustments Utility Plant Adjustments (116)
16	GasStoredUndergroundNoncurrent Gas Stored Underground - Noncurrent (117)
17	OtherPropertyAndInvestmentsAbstract OTHER PROPERTY AND INVESTMENTS
18	NonutilityProperty Nonutility Property (121)		1,221,467	1,221,467
19	AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122)		39,162	37,179
20	InvestmentInAssociatedCompanies Investments in Associated Companies (123)
21	InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1)	224
23	NoncurrentPortionOfAllowances Noncurrent Portion of Allowances	228
24	OtherInvestments Other Investments (124)		36,316,963	38,536,407
25	SinkingFunds Sinking Funds (125)
26	DepreciationFund Depreciation Fund (126)
27	AmortizationFundFederal Amortization Fund - Federal (127)
28	OtherSpecialFunds Other Special Funds (128)		63,289,518	61,506,861
29	SpecialFunds Special Funds (Non Major Only) (129)
30	DerivativeInstrumentAssetsLongTerm Long-Term Portion of Derivative Assets (175)			307,812
31	DerivativeInstrumentAssetsHedgesLongTerm Long-Term Portion of Derivative Assets - Hedges (176)
32	OtherPropertyAndInvestments TOTAL Other Property and Investments (Lines 18-21 and 23-31)		100,788,786	101,535,368
33	CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS
34	CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130)
35	Cash Cash (131)		4,196,481	959,309
36	SpecialDeposits Special Deposits (132-134)		173,228	160,408
37	WorkingFunds Working Fund (135)
38	TemporaryCashInvestments Temporary Cash Investments (136)		43,250,123	33,548,026
39	NotesReceivable Notes Receivable (141)
40	CustomerAccountsReceivable Customer Accounts Receivable (142)		88,551,829	121,601,624
41	OtherAccountsReceivable Other Accounts Receivable (143)		3,612,436	3,223,201
42	AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144)		17,596,628	18,347,333
43	NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145)
44	AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146)		39,383,714	40,913,068
45	FuelStock Fuel Stock (151)	227
46	FuelStockExpensesUndistributed Fuel Stock Expenses Undistributed (152)	227
47	Residuals Residuals (Elec) and Extracted Products (153)	227
48	PlantMaterialsAndOperatingSupplies Plant Materials and Operating Supplies (154)	227	60,734,757	63,689,007
49	Merchandise Merchandise (155)	227
50	OtherMaterialsAndSupplies Other Materials and Supplies (156)	227
51	NuclearMaterialsHeldForSale Nuclear Materials Held for Sale (157)	202/227
52	AllowanceInventoryAndWithheld Allowances (158.1 and 158.2)	228
53	NoncurrentPortionOfAllowances (Less) Noncurrent Portion of Allowances	228
54	StoresExpenseUndistributed Stores Expense Undistributed (163)	227	108,249	56,395
55	GasStoredCurrent Gas Stored Underground - Current (164.1)
56	LiquefiedNaturalGasStoredAndHeldForProcessing Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57	Prepayments Prepayments (165)		61,481,917	41,538,864
58	AdvancesForGas Advances for Gas (166-167)
59	InterestAndDividendsReceivable Interest and Dividends Receivable (171)
60	RentsReceivable Rents Receivable (172)
61	AccruedUtilityRevenues Accrued Utility Revenues (173)		97,655,941	106,834,666
62	MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174)
63	DerivativeInstrumentAssets Derivative Instrument Assets (175)		181,724	3,910,070
64	DerivativeInstrumentAssetsLongTerm (Less) Long-Term Portion of Derivative Instrument Assets (175)			307,812
65	DerivativeInstrumentAssetsHedges Derivative Instrument Assets - Hedges (176)
66	DerivativeInstrumentAssetsHedgesLongTerm (Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67	CurrentAndAccruedAssets Total Current and Accrued Assets (Lines 34 through 66)		381,733,771	395,860,875
68	DeferredDebitsAbstract DEFERRED DEBITS
69	UnamortizedDebtExpense Unamortized Debt Expenses (181)		27,348,138	27,752,848
70	ExtraordinaryPropertyLosses Extraordinary Property Losses (182.1)	230a
71	UnrecoveredPlantAndRegulatoryStudyCosts Unrecovered Plant and Regulatory Study Costs (182.2)	230b
72	OtherRegulatoryAssets Other Regulatory Assets (182.3)	232	1,091,848,099	1,022,722,142
73	PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183)		1,804,085	1,075,051
74	PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges Preliminary Natural Gas Survey and Investigation Charges 183.1)
75	OtherPreliminarySurveyAndInvestigationCharges Other Preliminary Survey and Investigation Charges (183.2)
76	ClearingAccounts Clearing Accounts (184)		2,860,480	28,738
77	TemporaryFacilities Temporary Facilities (185)
78	MiscellaneousDeferredDebits Miscellaneous Deferred Debits (186)	233	87,337,389	87,811,241
79	DeferredLossesFromDispositionOfUtilityPlant Def. Losses from Disposition of Utility Plt. (187)
80	ResearchDevelopmentAndDemonstrationExpenditures Research, Devel. and Demonstration Expend. (188)	352
81	UnamortizedLossOnReacquiredDebt Unamortized Loss on Reaquired Debt (189)		19,164,732	19,607,053
82	AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190)	234	789,294,852	796,516,161
83	UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191)
84	DeferredDebits Total Deferred Debits (lines 69 through 83)		2,019,657,775	1,955,513,234
85	AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84)		9,485,776,718	9,343,558,621

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	ProprietaryCapitalAbstract PROPRIETARY CAPITAL
2	CommonStockIssued Common Stock Issued (201)	250	1,000	1,000
3	PreferredStockIssued Preferred Stock Issued (204)	250
4	CapitalStockSubscribed Capital Stock Subscribed (202, 205)
5	StockLiabilityForConversion Stock Liability for Conversion (203, 206)
6	PremiumOnCapitalStock Premium on Capital Stock (207)		773,510,116	773,510,116
7	OtherPaidInCapital Other Paid-In Capital (208-211)	253	(a) 1,537,639,552	(b) 1,537,639,552
8	InstallmentsReceivedOnCapitalStock Installments Received on Capital Stock (212)	252
9	DiscountOnCapitalStock (Less) Discount on Capital Stock (213)	254
10	CapitalStockExpense (Less) Capital Stock Expense (214)	254b	2,930,253	2,930,253
11	RetainedEarnings Retained Earnings (215, 215.1, 216)	118	735,145,360	736,907,359
12	UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1)	118	12,178,879	12,178,879
13	ReacquiredCapitalStock (Less) Reaquired Capital Stock (217)	250
14	NoncorporateProprietorship Noncorporate Proprietorship (Non-major only) (218)
15	AccumulatedOtherComprehensiveIncome Accumulated Other Comprehensive Income (219)	122(a)(b)	2,379,560	2,423,668
16	ProprietaryCapital Total Proprietary Capital (lines 2 through 15)		3,028,807,336	3,030,525,227
17	LongTermDebtAbstract LONG-TERM DEBT
18	Bonds Bonds (221)	256	92,500,000	92,500,000
19	ReacquiredBonds (Less) Reaquired Bonds (222)	256
20	AdvancesFromAssociatedCompanies Advances from Associated Companies (223)	256
21	OtherLongTermDebt Other Long-Term Debt (224)	256	2,641,300,000	2,441,300,000
22	UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225)
23	UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226)		7,445,278	7,608,992
24	LongTermDebt Total Long-Term Debt (lines 18 through 23)		2,726,354,722	2,526,191,008
25	OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES
26	ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227)		316,409,271	320,966,410
27	AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1)
28	AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2)		1,665,588	1,679,965
29	AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3)		12,187,312	12,960,731
30	AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4)
31	AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229)		1,840,064	927,542
32	LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities		79,921,982	61,986,335
33	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges
34	AssetRetirementObligations Asset Retirement Obligations (230)		63,435,410	67,657,231
35	OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34)		475,459,627	466,178,214
36	CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES
37	NotesPayable Notes Payable (231)		104,000,000	180,000,000
38	AccountsPayable Accounts Payable (232)		169,997,590	211,116,835
39	NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233)
40	AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234)		50,509,991	31,213,117
41	CustomerDeposits Customer Deposits (235)		44,516,249	43,871,889
42	TaxesAccrued Taxes Accrued (236)	262	17,156,915	15,985,601
43	InterestAccrued Interest Accrued (237)		37,990,613	32,440,793
44	DividendsDeclared Dividends Declared (238)
45	MaturedLongTermDebt Matured Long-Term Debt (239)
46	MaturedInterest Matured Interest (240)
47	TaxCollectionsPayable Tax Collections Payable (241)		17,586,611	18,292,621
48	MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242)		10,984,346	6,978,107
49	ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243)		25,903,577	28,052,025
50	DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244)		167,753,007	117,154,613
51	LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities		79,921,982	61,986,335
52	DerivativeInstrumentLiabilitiesHedges Derivative Instrument Liabilities - Hedges (245)
53	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges (Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54	CurrentAndAccruedLiabilities Total Current and Accrued Liabilities (lines 37 through 53)		566,476,917	623,119,266
55	DeferredCreditsAbstract DEFERRED CREDITS
56	CustomerAdvancesForConstruction Customer Advances for Construction (252)		98,545,003	97,645,214
57	AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255)	266	11,873,686	11,978,219
58	DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256)
59	OtherDeferredCredits Other Deferred Credits (253)	269	92,119,681	88,908,125
60	OtherRegulatoryLiabilities Other Regulatory Liabilities (254)	278	897,204,228	919,493,153
61	UnamortizedGainOnReacquiredDebt Unamortized Gain on Reaquired Debt (257)		131,099	133,869
62	AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty Accum. Deferred Income Taxes-Accel. Amort.(281)	272
63	AccumulatedDeferredIncomeTaxesOtherProperty Accum. Deferred Income Taxes-Other Property (282)		1,377,753,100	1,380,871,490
64	AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283)		211,051,319	198,514,836
65	DeferredCredits Total Deferred Credits (lines 56 through 64)		2,688,678,116	2,697,544,906
66	LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)		9,485,776,718	9,343,558,621

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: OtherPaidInCapital

Includes total of $33,521,170 for the Pension due to the implementation of pension measurement guidance in 2006.

(b) Concept: OtherPaidInCapital

Includes total of $33,521,170 for the Pension due to the implementation of pension measurement guidance in 2006.

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

STATEMENT OF INCOME
Quarterly Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter. If additional columns are needed, place them in a footnote. Annual or Quarterly if applicable Do not report fourth quarter data in columns (e) and (f) Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above. Use page 122 for important notes regarding the statement of income for any account thereof. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.	Title of Account (a)	(Ref.) Page No. (b)	Total Current Year to Date Balance for Quarter/Year (c)	Total Prior Year to Date Balance for Quarter/Year (d)	Current 3 Months Ended - Quarterly Only - No 4th Quarter (e)	Prior 3 Months Ended - Quarterly Only - No 4th Quarter (f)	Electric Utility Current Year to Date (in dollars) (g)	Electric Utility Previous Year to Date (in dollars) (h)	Gas Utiity Current Year to Date (in dollars) (i)	Gas Utility Previous Year to Date (in dollars) (j)	Other Utility Current Year to Date (in dollars) (k)	Other Utility Previous Year to Date (in dollars) (l)
1	UtilityOperatingIncomeAbstract UTILITY OPERATING INCOME
2	OperatingRevenues Operating Revenues (400)	300	445,593,064	405,496,304	445,593,064	405,496,304	445,593,064	405,496,304
3	OperatingExpensesAbstract Operating Expenses
4	OperationExpense Operation Expenses (401)	320	292,714,887	255,223,286	292,714,887	255,223,286	292,714,887	255,223,286
5	MaintenanceExpense Maintenance Expenses (402)	320	10,911,526	8,449,581	10,911,526	8,449,581	10,911,526	8,449,581
6	DepreciationExpense Depreciation Expense (403)	336	68,504,008	66,347,260	68,504,008	66,347,260	68,504,008	66,347,260
7	DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1)	336
8	AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405)	336	7,060,151	6,687,120	7,060,151	6,687,120	7,060,151	6,687,120
9	AmortizationOfElectricPlantAcquisitionAdjustments Amort. of Utility Plant Acq. Adj. (406)	336	772,606	772,606	772,606	772,606	772,606	772,606
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)		33,480,715	30,775,855	33,480,715	30,775,855	33,480,715	30,775,855
13	RegulatoryCredits (Less) Regulatory Credits (407.4)		3,613,299	3,613,295	3,613,299	3,613,295	3,613,299	3,613,295
14	TaxesOtherThanIncomeTaxesUtilityOperatingIncome Taxes Other Than Income Taxes (408.1)	262	14,144,722	13,493,910	14,144,722	13,493,910	14,144,722	13,493,910
15	IncomeTaxesOperatingIncome Income Taxes - Federal (409.1)	262	6,260,670	9,391,457	6,260,670	9,391,457	6,260,670	9,391,457
16	IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1)	262	13,700	29,601	13,700	29,601	13,700	29,601
17	ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1)	234, 272	40,417,327	33,530,717	40,417,327	33,530,717	40,417,327	33,530,717
18	ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1)	234, 272	35,048,639	43,475,556	35,048,639	43,475,556	35,048,639	43,475,556
19	InvestmentTaxCreditAdjustments Investment Tax Credit Adj. - Net (411.4)	266	104,533	107,310	104,533	107,310	104,533	107,310
20	GainsFromDispositionOfPlant (Less) Gains from Disp. of Utility Plant (411.6)
21	LossesFromDispositionOfServiceCompanyPlant Losses from Disp. of Utility Plant (411.7)
22	GainsFromDispositionOfAllowances (Less) Gains from Disposition of Allowances (411.8)
23	LossesFromDispositionOfAllowances Losses from Disposition of Allowances (411.9)
24	AccretionExpense Accretion Expense (411.10)
25	UtilityOperatingExpenses TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)		422,965,101	377,505,232	422,965,101	377,505,232	422,965,101	377,505,232
27	NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25)		22,627,963	27,991,072	22,627,963	27,991,072	22,627,963	27,991,072
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)		39,101	39,053	39,101	39,053
34	ExpensesOfNonutilityOperations (Less) Expenses of Nonutility Operations (417.1)		1,983	2,809	1,983	2,809
35	NonoperatingRentalIncome Nonoperating Rental Income (418)
36	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1)	119
37	InterestAndDividendIncome Interest and Dividend Income (419)		8,878,513	4,905,910	8,878,513	4,905,910
38	AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1)		2,570,355	1,429,403	2,570,355	1,429,403
39	MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421)		397,596	1,495,339	397,596	1,495,339
40	GainOnDispositionOfProperty Gain on Disposition of Property (421.1)		1,027,142	1,027,142	1,027,142	1,027,142
41	OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40)		12,910,724	8,894,038	12,910,724	8,894,038
42	OtherIncomeDeductionsAbstract Other Income Deductions
43	LossOnDispositionOfProperty Loss on Disposition of Property (421.2)		75,541	351,632	75,541	351,632
44	MiscellaneousAmortization Miscellaneous Amortization (425)
45	Donations Donations (426.1)		16,280	63,882	16,280	63,882
46	LifeInsurance Life Insurance (426.2)		117,983	118,411	117,983	118,411
47	Penalties Penalties (426.3)		643	146,237	643	146,237
48	ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4)		224,506	144,886	224,506	144,886
49	OtherDeductions Other Deductions (426.5)		5,659,392	3,162,035	5,659,392	3,162,035
50	OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49)		6,094,345	2,991,345	6,094,345	2,991,345
51	TaxesApplicableToOtherIncomeAndDeductionsAbstract Taxes Applic. to Other Income and Deductions
52	TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions Taxes Other Than Income Taxes (408.2)	262	46,721	9,904	46,721	9,904
53	IncomeTaxesFederal Income Taxes-Federal (409.2)	262	775,280	939,885	775,280	939,885
54	IncomeTaxesOther Income Taxes-Other (409.2)	262
55	ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2)	234, 272	3,566	3,566	3,566	3,566
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)		825,567	953,355	825,567	953,355
60	NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59)		5,990,812	4,949,338	5,990,812	4,949,338
61	InterestChargesAbstract Interest Charges
62	InterestOnLongTermDebt Interest on Long-Term Debt (427)		28,960,575	28,658,839	28,960,575	28,658,839
63	AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428)		677,640	667,408	677,640	667,408
64	AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1)		442,321	436,896	442,321	436,896
65	AmortizationOfPremiumOnDebtCredit (Less) Amort. of Premium on Debt-Credit (429)
66	AmortizationOfGainOnReacquiredDebtCredit (Less) Amortization of Gain on Reaquired Debt-Credit (429.1)		2,770	2,770	2,770	2,770
67	InterestOnDebtToAssociatedCompanies Interest on Debt to Assoc. Companies (430)
68	OtherInterestExpense Other Interest Expense (431)		1,478,671	1,366,225	1,478,671	1,366,225
69	AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)		1,175,663	675,314	1,175,663	675,314
70	NetInterestCharges Net Interest Charges (Total of lines 62 thru 69)		30,380,774	30,451,284	30,380,774	30,451,284
71	IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70)		1,761,999	2,489,126	1,761,999	2,489,126
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)		1,761,999	2,489,126	1,761,999	2,489,126

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

STATEMENT OF RETAINED EARNINGS
Do not report Lines 49-53 on the quarterly report. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b). State the purpose and amount for each reservation or appropriation of retained earnings. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order. Show dividends for each class and series of capital stock. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No.	Item (a)	Contra Primary Account Affected (b)	Current Quarter/Year Year to Date Balance (c)	Previous Quarter/Year Year to Date Balance (d)
	UnappropriatedRetainedEarningsAbstract UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1	UnappropriatedRetainedEarnings Balance-Beginning of Period		735,145,644	644,541,715
2	ChangesAbstract Changes
3	AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439)
4	AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit
4.1	AdjustmentsToRetainedEarningsCredit Adjustments to Retained Earnings Credit
9	AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439)
10	AdjustmentsToRetainedEarningsDebitAbstract Adjustments to Retained Earnings Debit
10.1	AdjustmentsToRetainedEarningsDebit Adjustments to Retained Earnings Debit
15	AdjustmentsToRetainedEarningsDebit TOTAL Debits to Retained Earnings (Acct. 439)
16	BalanceTransferredFromIncome Balance Transferred from Income (Account 433 less Account 418.1)		1,761,999	2,489,126
17	AppropriationsOfRetainedEarningsAbstract Appropriations of Retained Earnings (Acct. 436)
22	AppropriationsOfRetainedEarnings TOTAL Appropriations of Retained Earnings (Acct. 436)
23	DividendsDeclaredPreferredStockAbstract Dividends Declared-Preferred Stock (Account 437)
29	DividendsDeclaredPreferredStock TOTAL Dividends Declared-Preferred Stock (Acct. 437)
30	DividendsDeclaredCommonStockAbstract Dividends Declared-Common Stock (Account 438)
30.1	DividendsDeclaredCommonStock Dividends
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)		733,383,645	647,030,841
39	AppropriatedRetainedEarningsAbstract APPROPRIATED RETAINED EARNINGS (Account 215)
39.1	AppropriatedRetainedEarnings Change in Accounting Method of Unbilled Revenue		1,761,715
45	AppropriatedRetainedEarnings TOTAL Appropriated Retained Earnings (Account 215)		1,761,715	1,761,715
	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)		1,761,715	1,761,715
48	RetainedEarnings TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)		735,145,360	648,792,556
	UnappropriatedUndistributedSubsidiaryEarningsAbstract UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49	UnappropriatedUndistributedSubsidiaryEarnings Balance-Beginning of Year (Debit or Credit)
50	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings for Year (Credit) (Account 418.1)
51	DividendsReceived (Less) Dividends Received (Debit)
52	ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
52.1	ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
53	UnappropriatedUndistributedSubsidiaryEarnings Balance-End of Year (Total lines 49 thru 52)

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

STATEMENT OF CASH FLOWS
Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.	Description (See Instructions No.1 for explanation of codes) (a)	Current Year to Date Quarter/Year (b)	Previous Year to Date Quarter/Year (c)
1	NetCashFlowFromOperatingActivitiesAbstract Net Cash Flow from Operating Activities
2	NetIncomeLoss Net Income (Line 78(c) on page 117)	1,761,999	2,489,126
3	NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income:
4	DepreciationAndDepletion Depreciation and Depletion	76,336,765	73,806,986
5	NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details)
5.1	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Unamortized (Gain) Loss on Reacquired Debt	439,551	434,126
5.2	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Deferred Energy Costs	37,237,869	40,594,253
8	DeferredIncomeTaxesNet Deferred Income Taxes (Net)	5,372,254	9,941,273
9	InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net)	104,533	107,310
10	NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables	42,617,934	59,631,670
11	NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory	2,902,396	4,353,280
12	NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory
13	NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses	11,610,046	1,353,170
14	NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets	18,000,453	11,429,593
15	NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities	6,918,406	10,128,024
16	AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction	2,570,355	1,429,403
17	UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies
18	OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote):
18.1	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Net Increase (Decrease) in Other Liabilities	4,158,712	2,311,544
18.2	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Net Increase (Decrease) in Accrued Taxes and Interest	6,721,134	18,042,584
18.3	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Net (Increase) Decrease in Prepayments	17,925,419	18,439,556
18.4	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Net (Increase) Decrease in Other Assets	1,882,526	4,620,480
18.5	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Net (Increase) Decrease in Regulatory Asset for Pension Plan	158,957	903,865
18.6	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Change in Pension and Benefit Assets/Liabilities	1,143,183	1,535,935
18.7	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Net (Increase) Decrease in Accumulated Other Comprehensive Income	44,108	48,205
22	NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)	79,045,066	169,196,421
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)	190,043,998	105,977,813
27	GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel
28	GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant
29	GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant	1,983	2,809
30	AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction	2,570,355	1,429,403
31	OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote):
31.1	OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Customer Advances for Construction	899,789	3,622,878
31.2	OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Contributions in Aid of Construction	4,507,195	3,840,979
34	CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33)	182,064,676	97,081,744
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 Proceeds from Other Investment
53.2	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Proceeds from Sale of Asset
57	CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)	182,064,676	97,081,744
59	CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities:
60	ProceedsFromIssuanceAbstract Proceeds from Issuance of:
61	ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b)	200,000,000
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)	200,000,000
72	PaymentsForRetirementAbstract Payments for Retirement of:
73	PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b)
74	PaymentsForRetirementOfPreferredStockFinancingActivities Preferred Stock
75	PaymentsForRetirementOfCommonStockFinancingActivities Common Stock
76	OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities Other (provide details in footnote):
76.1	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Payments for Finance Lease Obligations	4,472,390	4,093,342
76.2	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Deferred Financing and Debt Issuance Costs	109,217	48,090
78	NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c)	76,000,000
80	DividendsOnPreferredStock Dividends on Preferred Stock
81	DividendsOnCommonStock Dividends on Common Stock
83	CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)	119,418,393	4,141,432
85	NetIncreaseDecreaseInCashAndCashEquivalentsAbstract Net Increase (Decrease) in Cash and Cash Equivalents
86	NetIncreaseDecreaseInCashAndCashEquivalents Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83)	16,398,783	67,973,245
88	CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period	44,775,719	36,403,854
90	CashAndCashEquivalents Cash and Cash Equivalents at End of Period	61,174,502	104,377,099

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

NOTES TO FINANCIAL STATEMENTS

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

NEVADA POWER COMPANY AND SUBSIDIARIES

NOTES TO FINANCIAL STATEMENTS

General

The notes on Page 122 have been excerpted from Nevada Power Company’s Item 1 of Berkshire Hathaway Energy Company’s (“BHE”) Quarterly Report on Form 10-Q for the period ended March 31, 2022 and are prepared in conformity with accounting principles generally accepted in the United States of America (“GAAP”). Accordingly, certain footnotes are not reflective of Nevada Power Company’s Financial Statements contained herein.

Nevada Power Company, together with its subsidiaries ("Nevada Power"), is a wholly owned subsidiary of NV Energy, Inc. ("NV Energy"), a holding company that also owns Sierra Pacific Power Company and its subsidiaries ("Sierra Pacific") and certain other subsidiaries. Nevada Power is a United States regulated electric utility company serving retail customers, including residential, commercial and industrial customers, primarily in the Las Vegas, North Las Vegas, Henderson and adjoining areas. NV Energy is an indirect wholly owned subsidiary of BHE. BHE is a holding company based in Des Moines, Iowa that owns subsidiaries principally engaged in energy businesses. BHE is a consolidated subsidiary of Berkshire Hathaway Inc. ("Berkshire Hathaway").

The preparation of the unaudited Consolidated Financial Statements in conformity with GAAP requires management to make

estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the unaudited Consolidated Financial Statements and the reported amounts of revenue and expenses during the period. Actual results may differ from the estimates used in preparing the unaudited Consolidated Financial Statements. Note 2 of Notes to Consolidated Financial Statements included in Nevada Power's Annual Report on Form 10-K for the year ended December 31, 2021 describes the most significant accounting policies used in the preparation of the unaudited Consolidated Financial Statements. There have been no significant changes in Nevada Power's assumptions regarding significant accounting estimates and policies during the three-month period ended March 31, 2022.

Nevada Power accounts for electric operations are maintained in accordance with the Uniform System of Accounts prescribed by the Federal Energy Regulatory Commission (“FERC”). The principal differences of this basis of accounting from GAAP include, but not necessarily limited to, the accounting for and classification of:

•The requirement to report deferred tax assets and liabilities separately rather than a single amount.

•The classification of cost of removal as accumulated depreciation rather than regulatory liabilities.

•The removal of certain tax liabilities related to the accounting for uncertain tax positions as deferred income taxes and deferred credits.

•The classification of certain assets and liabilities as noncurrent instead of current.

•The classification of certain items as revenue rather than purchased power expense.

•The classification of income taxes as operating expense rather than income tax expense.

•The classification of certain regulatory liabilities as regulatory assets.

•The classification of operating and finance lease assets as plant rather than other assets.

•Certain other reclassifications of balance sheet, income statement and cash flow amounts have been made in order to conform to the FERC basis of presentation. These reclassifications had no effect on net income.

Cash and Cash Equivalents and Restricted Cash and Cash Equivalents

Cash equivalents consist of funds invested in money market mutual funds, U.S. Treasury Bills and other investments with a maturity of three months or less when purchased. Cash and cash equivalents exclude amounts where availability is restricted by legal requirements, loan agreements or other contractual provisions. Restricted cash and cash equivalents consist of funds restricted by the Public Utilities Commission of Nevada ("PUCN") for a certain renewable energy contract. A reconciliation of cash and cash equivalents and restricted cash and cash equivalents as presented in the Statements of Cash Flows is outlined below and disaggregated by the line items in which they appear on the Balance Sheets (in millions):


	As of
	March 31,		December 31,
	2022		2021
Cash and cash equivalents	$	47	$	33
Restricted cash and cash equivalents included in other current assets	14		12
Total cash and cash equivalents and restricted cash and cash equivalents	$	61	$	45

Property, Plant and Equipment, Net

Property, plant and equipment, net consists of the following (in millions):


		As of
	Depreciable Life	March 31,		December 31,
		2022		2021
Utility plant:
Generation	30 - 55 years	$	3,810	$	3,793
Transmission	45 - 70 years	1,508		1,503
Distribution	20 - 65 years	3,979		3,920
General and intangible plant	5 - 65 years	831		836
Utility plant		10,128		10,052
Accumulated depreciation and amortization		(3,478)		(3,406)
Utility plant, net		6,650		6,646
Other non-regulated, net of accumulated depreciation and amortization	45 years	1		1
Plant, net		6,651		6,647
Construction work-in-progress		341		244
Property, plant and equipment, net		$	6,992	$	6,891

Recent Financing Transactions

Long-Term Debt

In January 2022, Nevada Power entered into a $300 million secured delayed draw term loan facility maturing in January 2024. Amounts borrowed under the facility bear interest at variable rates based on the Secured Overnight Financing Rate or a base rate, at Nevada Power's option, plus a pricing margin. In January 2022, Nevada Power borrowed $200 million under the facility at an initial interest rate of 0.55%. Nevada Power may draw all or none of the remaining unused commitment through June 2022. Nevada Power used the proceeds to repay amounts outstanding under its existing secured credit facility and for general corporate purposes.

Employee Benefit Plans

Nevada Power is a participant in benefit plans sponsored by NV Energy. The NV Energy Retirement Plan includes a qualified pension plan ("Qualified Pension Plan") and a supplemental executive retirement plan and a restoration plan (collectively, "Non‑Qualified Pension Plans") that provide pension benefits for eligible employees. The NV Energy Comprehensive Welfare Benefit and Cafeteria Plan provides certain postretirement health care and life insurance benefits for eligible retirees ("Other Postretirement Plans") on behalf of Nevada Power. Amounts attributable to Nevada Power were allocated from NV Energy based upon the current, or in the case of retirees, previous, employment location. Offsetting regulatory assets and liabilities have been recorded related to the amounts not yet recognized as a component of net periodic benefit costs that will be included in regulated rates. Net periodic benefit costs not included in regulated rates are included in accumulated other comprehensive loss, net.

Amounts receivable from (payable to) NV Energy are included on the Balance Sheets and consist of the following (in millions):


	As of
	March 31,		December 31,
	2022		2021
Qualified Pension Plan:
Other non-current assets	$	42	$	42



Non-Qualified Pension Plans:

Other current liabilities	(1)		(1)
Other long-term liabilities	(8)		(8)

Other Postretirement Plans:
Other non-current assets	8		8

Risk Management and Hedging Activities

Nevada Power is exposed to the impact of market fluctuations in commodity prices and interest rates. Nevada Power is principally exposed to electricity, natural gas and coal market fluctuations primarily through Nevada Power's obligation to serve retail customer load in its regulated service territory. Nevada Power's load and generating facilities represent substantial underlying commodity positions. Exposures to commodity prices consist mainly of variations in the price of fuel required to generate electricity and wholesale electricity that is purchased and sold. Commodity prices are subject to wide price swings as supply and demand are impacted by, among many other unpredictable items, weather, market liquidity, generating facility availability, customer usage, storage, and transmission and transportation constraints. The actual cost of fuel and purchased power is recoverable through the deferred energy mechanism. Interest rate risk exists on variable-rate debt and future debt issuances. Nevada Power does not engage in proprietary trading activities.

Nevada Power has established a risk management process that is designed to identify, assess, manage and report on each of the various types of risk involved in its business. To mitigate a portion of its commodity price risk, Nevada Power uses commodity derivative contracts, which may include forwards, futures, options, swaps and other agreements, to effectively secure future supply or sell future production generally at fixed prices. Nevada Power manages its interest rate risk by limiting its exposure to variable interest rates primarily through the issuance of fixed-rate long-term debt and by monitoring market changes in interest rates. Additionally, Nevada Power may from time to time enter into interest rate derivative contracts, such as interest rate swaps or locks, to mitigate Nevada Power's exposure to interest rate risk. Nevada Power does not hedge all of its commodity price and interest rate risks, thereby exposing the unhedged portion to changes in market prices.

There have been no significant changes in Nevada Power's accounting policies related to derivatives. Refer to Fair Value Measurements Note for additional information on derivative contracts.

The following table, which excludes contracts that have been designated as normal under the normal purchases and normal sales exception afforded by GAAP, summarizes the fair value of Nevada Power's derivative contracts, on a gross basis, and reconciles those amounts presented on a net basis on the Balance Sheets (in millions):


			Derivative
	Other		Contracts -		Other
	Current		Current		Long-term
	Assets		Liabilities		Liabilities		Total

As of March 31, 2022
Not designated as hedging contracts (1):

Commodity liabilities	$	—	$	(88)	$	(80)	$	(168)





Total derivative - net basis	$	—	$	(88)	$	(80)	$	(168)

As of December 31, 2021
Not designated as hedging contracts(1):
Commodity assets	$	4	$	—	$	—	$	4
Commodity liabilities	—		(55)		(62)		(117)




Total derivative - net basis	$	4	$	(55)	$	(62)	$	(113)

(1)Nevada Power's commodity derivatives not designated as hedging contracts are included in regulated rates. As of March 31, 2022 a regulatory asset of $168 million was recorded related to the net derivative liability of $168 million. As of December 31, 2021 a regulatory asset of $113 million was recorded related to the net derivative liability of $113 million.

Derivative Contract Volumes

The following table summarizes the net notional amounts of outstanding commodity derivative contracts with fixed price terms that comprise the mark-to-market values as of (in millions):


	Unit of	March 31,	December 31,
	Measure	2022	2021

Electricity purchases	Megawatt hours	3	1
Natural gas purchases	Decatherms	138	119

Credit Risk

Nevada Power is exposed to counterparty credit risk associated with wholesale energy supply and marketing activities with other utilities, energy marketing companies, financial institutions and other market participants. Credit risk may be concentrated to the extent Nevada Power's counterparties have similar economic, industry or other characteristics and due to direct and indirect relationships among the counterparties. Before entering into a transaction, Nevada Power analyzes the financial condition of each significant wholesale counterparty, establishes limits on the amount of unsecured credit to be extended to each counterparty and evaluates the appropriateness of unsecured credit limits on an ongoing basis. To further mitigate wholesale counterparty credit risk, Nevada Power enters into netting and collateral arrangements that may include margining and cross-product netting agreements and obtain third-party guarantees, letters of credit and cash deposits. If required, Nevada Power exercises rights under these arrangements, including calling on the counterparty's credit support arrangement.

Collateral and Contingent Features

In accordance with industry practice, certain wholesale agreements, including derivative contracts, contain credit support provisions that in part base certain collateral requirements on credit ratings for senior unsecured debt as reported by one or more of the recognized credit rating agencies. These agreements may either specifically provide bilateral rights to demand cash or other security if credit exposures on a net basis exceed specified rating-dependent threshold levels "credit-risk-related contingent features") or provide the right for counterparties to demand "adequate assurance" if there is a material adverse change in Nevada Power's creditworthiness. These rights can vary by contract and by counterparty. As of March 31, 2022, Nevada Power's credit ratings for its senior secured debt and its issuer credit ratings for senior unsecured debt from the recognized credit rating agencies were investment grade.

The aggregate fair value of Nevada Power's derivative contracts in liability positions with specific credit-risk-related contingent features totaled $7 million and $6 million as of March 31, 2022 and December 31, 2021, respectively, which represents the amount of collateral to be posted if all credit risk related contingent features for derivative contracts in liability positions had been triggered. Nevada Power's collateral requirements could fluctuate considerably due to market price volatility, changes in credit ratings, changes in legislation or regulation or other factors.

Fair Value Measurements

The carrying value of Nevada Power's cash, certain cash equivalents, receivables, payables, accrued liabilities and short-term borrowings approximates fair value because of the short-term maturity of these instruments. Nevada Power has various financial assets and liabilities that are measured at fair value on the Balance Sheets using inputs from the three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

•Level 1 — Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that Nevada Power has the ability to access at the measurement date.

•Level 2 — Inputs include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).

•Level 3 — Unobservable inputs reflect Nevada Power's judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. Nevada Power develops these inputs based on the best information available, including its own data.

The following table presents Nevada Power's assets and liabilities recognized on the Balance Sheets and measured at fair value on a recurring basis (in millions):


	Input Levels for Fair Value Measurements
	Level 1		Level 2		Level 3		Total
As of March 31, 2022:
Assets:

Money market mutual funds	$	43	$	—	$	—	$	43
Investment funds	3		—		—		3
	$	46	$	—	$	—	$	46

Liabilities - commodity derivatives	$	—	$	—	$	(168)	$	(168)

As of December 31, 2021:
Assets:
Commodity derivatives	$	—	$	—	$	4	$	4
Money market mutual funds	34		—		—		34
Investment funds	3		—		—		3
	$	37	$	—	$	4	$	41

Liabilities - commodity derivatives	$	—	$	—	$	(117)	$	(117)

Derivative contracts are recorded on the Balance Sheets as either assets or liabilities and are stated at estimated fair value unless they are designated as normal purchases or normal sales and qualify for the exception afforded by GAAP. When available, the fair value of derivative contracts is estimated using unadjusted quoted prices for identical contracts in the market in which Nevada Power transacts. When quoted prices for identical contracts are not available, Nevada Power uses forward price curves. Forward price curves represent Nevada Power's estimates of the prices at which a buyer or seller could contract today for delivery or settlement at future dates. Nevada Power bases its forward price curves upon internally developed models, with internal and external fundamental data inputs. Market price quotations for certain electricity and natural gas trading hubs are not as readily obtainable due to markets that are not active. Given that limited market data exists for these contracts, Nevada Power uses forward price curves derived from internal models based on perceived pricing relationships to major trading hubs that are based on unobservable inputs. The model incorporates a mid-market pricing convention (the mid‑point price between bid and ask prices) as a practical expedient for valuing its assets and liabilities measured and reported at fair value. The determination of the fair value for derivative contracts not only includes counterparty risk, but also the impact of Nevada Power's nonperformance risk on its liabilities, which as of March 31, 2022 and December 31, 2021, had an immaterial impact to the fair value of its derivative contracts. As such, Nevada Power considers its derivative contracts to be valued using Level 3 inputs.

Nevada Power's investments in money market mutual funds and investment funds are stated at fair value. When available, a readily observable quoted market price or net asset value of an identical security in an active market is used to record the fair value.

The following table reconciles the beginning and ending balances of Nevada Power's commodity derivative assets and liabilities measured at fair value on a recurring basis using significant Level 3 inputs (in millions):


	Three-Month Periods
	Ended March 31,
	2022		2021

Beginning balance	$	(113)	$	15
Changes in fair value recognized in regulatory assets	(56)		11

Settlements	1		1
Ending balance	$	(168)	$	27

Nevada Power's long-term debt is carried at cost on the Balance Sheets. The fair value of Nevada Power's long‑term debt is a Level 2 fair value measurement and has been estimated based upon quoted market prices, where available, or at the present value of future cash flows discounted at rates consistent with comparable maturities with similar credit risks. The carrying value of Nevada Power's variable-rate long-term debt approximates fair value because of the frequent repricing of these instruments at market rates. The following table presents the carrying value and estimated fair value of Nevada Power's long‑term debt (in millions):


	As of March 31, 2022				As of December 31, 2021
	Carrying		Fair		Carrying		Fair
	Value		Value		Value		Value

Long-term debt	$	2,700	$	2,985	$	2,499	$	3,067

Commitments and Contingencies

Legal Matters

Nevada Power is party to a variety of legal actions arising out of the normal course of business. Plaintiffs occasionally seek punitive or exemplary damages. Nevada Power does not believe that such normal and routine litigation will have a material impact on its consolidated financial results.

Environmental Laws and Regulations

Nevada Power is subject to federal, state and local laws and regulations regarding climate change, renewable portfolio standards, air and water quality, emissions performance standards, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact Nevada Power's current and future operations. Nevada Power believes it is in material compliance with all applicable laws and regulations.

Revenue from Contracts with Customers

The following table summarizes Nevada Power's revenue from contracts with customers ("Customer Revenue") by line of business, with further disaggregation of retail by customer class (in millions):


	Three-Month Periods
	Ended March 31,
	2022		2021
Customer Revenue:
Retail:
Residential	$	214	$	196
Commercial	96		84
Industrial	78		63
Other	1		3
Total fully bundled	389		346
Distribution only service	5		5
Total retail	394		351
Wholesale, transmission and other	16		14
Total Customer Revenue	410		365
Other revenue	5		5
Total revenue	$	415	$	370

Supplemental Cash Flow Disclosures

Total cash and cash equivalents and restricted cash and cash equivalents consist of the following amounts as of March 31 (in millions):


	2022		2021
Cash (131)	$	4	$	6
Temporary cash investments (136)	43		86
Total cash and cash equivalents	$	47	$	92
Restricted cash and cash equivalents (128)	14		12
Total cash and cash equivalents and restricted cash and cash equivalents	$	61	$	104

The summary of supplemental cash flow disclosures (for pages 120 and 121) as of and for the quarter ended March 31 is as follows (in millions):


	2022		2021

Supplemental disclosure of cash flow information:
Interest paid, net of amounts capitalized	$	24	$	23


Supplemental disclosure of non-cash investing and financing transactions:
Accruals related to property, plant and equipment additions	43		42

Subsequent Events

Nevada Power’s management has evaluated the impact of events occurring after March 31, 2022, up to April 29, 2022 the date that Nevada Power’s GAAP financial statements were issued, and has updated such evaluation for disclosure purposes through May 27, 2022. These financial statements include all necessary adjustments and disclosures resulting from these evaluations.

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote. Report data on a year-to-date basis.
Line No.	Item (a)	Unrealized Gains and Losses on Available-For-Sale Securities (b)	Minimum Pension Liability Adjustment (net amount) (c)	Foreign Currency Hedges (d)	Other Adjustments (e)	Other Cash Flow Hedges Interest Rate Swaps (f)	Other Cash Flow Hedges [Specify] (g)	Totals for each category of items recorded in Account 219 (h)	Net Income (Carried Forward from Page 116, Line 78) (i)	Total Comprehensive Income (j)
1	Balance of Account 219 at Beginning of Preceding Year		2,816,612					2,816,612
2	Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3	Preceding Quarter/Year to Date Changes in Fair Value		48,205					48,205
4	Total (lines 2 and 3)		48,205					48,205	2,489,126	2,537,331
5	Balance of Account 219 at End of Preceding Quarter/Year		2,768,407					2,768,407
6	Balance of Account 219 at Beginning of Current Year		2,423,668					2,423,668
7	Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8	Current Quarter/Year to Date Changes in Fair Value		44,108					44,108
9	Total (lines 7 and 8)		44,108					44,108	1,761,999	1,717,891
10	Balance of Account 219 at End of Current Quarter/Year		2,379,560					2,379,560

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION
Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.
Line No.	Classification (a)	Total Company For the Current Year/Quarter Ended (b)	Electric (c)	Gas (d)	Other (Specify) (e)	Other (Specify) (f)	Other (Specify) (g)	Common (h)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlantInServiceAbstract In Service
3	UtilityPlantInServiceClassified Plant in Service (Classified)	10,030,881,840	10,030,881,840
4	UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases	338,214,543	338,214,543
5	UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold
6	UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified
7	UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified
8	UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7)	10,369,096,383	10,369,096,383
9	UtilityPlantLeasedToOthers Leased to Others
10	UtilityPlantHeldForFutureUse Held for Future Use	24,430,705	24,430,705
11	ConstructionWorkInProgress Construction Work in Progress	341,237,004	341,237,004
12	UtilityPlantAcquisitionAdjustment Acquisition Adjustments	72,798,368	72,798,368
13	UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12)	10,807,562,460	10,807,562,460
14	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion	3,823,966,074	3,823,966,074
15	UtilityPlantNet Net Utility Plant (13 less 14)	6,983,596,386	6,983,596,386
16	DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17	AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service:
18	DepreciationUtilityPlantInService Depreciation	3,524,805,190	3,524,805,190
19	AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService Amortization and Depletion of Producing Natural Gas Land and Land Rights
20	AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService Amortization of Underground Storage Land and Land Rights
21	AmortizationOfOtherUtilityPlantUtilityPlantInService Amortization of Other Utility Plant	240,279,542	240,279,542
22	DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21)	3,765,084,732	3,765,084,732
23	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract Leased to Others
24	DepreciationUtilityPlantLeasedToOthers Depreciation
25	AmortizationAndDepletionUtilityPlantLeasedToOthers Amortization and Depletion
26	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers Total Leased to Others (24 & 25)
27	DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract Held for Future Use
28	DepreciationUtilityPlantHeldForFutureUse Depreciation
29	AmortizationUtilityPlantHeldForFutureUse Amortization
30	DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29)
31	AbandonmentOfLeases Abandonment of Leases (Natural Gas)
32	AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment	58,881,342	58,881,342
33	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32)	3,823,966,074	3,823,966,074

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

Electric Plant In Service and Accum Provision For Depr by Function
Report below the original cost of plant in service by function. In addition to Account 101, include Account 102, and Account 106. Report in column (b) the original cost of plant in service and in column(c) the accumulated provision for depreciation and amortization by function.
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	412,642,234	240,279,542
2	Steam Production Plant	191,028,250	156,250,894
3	Nuclear Production Plant
4	Hydraulic Production - Conventional
5	Hydraulic Production - Pumped Storage
6	Other Production	3,571,677,036	1,343,326,994
7	Transmission	1,481,234,885	486,283,903
8	Distribution	3,955,462,911	1,398,611,582
9	Regional Transmission and Market Operation
10	General	418,836,524	140,331,817
11	TOTAL (Total of lines 1 through 10)	10,030,881,840	3,765,084,732

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

Transmission Service and Generation Interconnection Study Costs
Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies. List each study separately. In column (a) provide the name of the study. In column (b) report the cost incurred to perform the study at the end of period. In column (c) report the account charged with the cost of the study. In column (d) report the amounts received for reimbursement of the study costs at end of period. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.	DescriptionOfStudyPerformed Description (a)	StudyCostsIncurred Costs Incurred During Period (b)	StudyCostsAccountCharged Account Charged (c)	StudyCostsReimbursements Reimbursements Received During the Period (d)	StudyCostsAccountReimbursed Account Credited With Reimbursement (e)
1	Transmission Studies
20	Total
21	Generation Studies
22	Company 129/140/147	668	186201
23	Company 151/172	1,026	186201
24	Company 181 Facilities Re-Study	331	186201
25	Company 191 Facilities Study - LGIA Negotiations	1,834	186201
26	Company 192 Facilities Study - LGIA Negotiations	3,262	186201
27	Company 193 Facilities Study Negotiations	20,903	186201
28	Company 194 SIS Re-Study	7,637	186201
29	Company 195 SIS Re-Study	10,350	186201
30	Company 197 Facilities Study	11,096	186201
31	Company 199 SIS	9,177	186201
32	Company 200 SIS	11,357	186201
33	Company 200 Provisional Study	17	186201	5,000	186201
34	Company 201 SIS	9,971	186201
35	Company 201 Provisional Study	17	186201	5,000	186201
36	Company 202 SIS	9,179	186201	75,000	186201
37	Company 203 SIS	9,177	186201	75,000	186201
38	Company 204 SIS	8,341	186201	75,000	186201
39	Company 205 SIS	3,990	186201	75,000	186201
40	Company 206 SIS	8,780	186201	75,000	186201
41	Company 207 SIS	9,280	186201	75,000	186201
42	Company 208 SIS	10,410	186201	75,000	186201
43	Company 209 SIS	9,003	186201
44	Company 210 SIS	4,076	186201	75,000	186201
45	Company 211	10,216	186201	75,000	186201
46	Company 211 SIS	2,108	186201	40,000	186201
47	Company 211 Provisional Study	1,784	186201	5,000	186201
48	Company 212	860	186201	60,000	186201
49	Company 213	1,423	186201	60,000	186201
50	Company 214	1,465	186201	60,000	186201
51	Company 215	1,377	186201	60,000	186201
52	Company 216	1,133	186201	10,000	186201
53	Company 217	1,091	186201	10,000	186201
54	Company 218	1,666	186201	10,000	186201
55	Company 219	115	186201	60,000	186201
56	Company 220	115	186201	60,000	186201
57	Company 221	115	186201	60,000	186201
58	Company 222	1,380	186201	60,000	186201
39	Total	184,730		1,240,000
40	Grand Total	184,730		1,240,000

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

OTHER REGULATORY ASSETS (Account 182.3)
Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Assets being amortized, show period of amortization.
				CREDITS
Line No.	DescriptionAndPurposeOfOtherRegulatoryAssets Description and Purpose of Other Regulatory Assets (a)	OtherRegulatoryAssets Balance at Beginning of Current Quarter/Year (b)	IncreaseDecreaseInOtherRegulatoryAssets Debits (c)	OtherRegulatoryAssetsWrittenOffAccountCharged Written off During Quarter/Year Account Charged (d)	OtherRegulatoryAssetsWrittenOffRecovered Written off During the Period Amount (e)	OtherRegulatoryAssets Balance at end of Current Quarter/Year (f)
1	(a) Refer to footnote for Dkt. Nos. and amort. period
2	Incremental Rate Case Expenses	2,443,568	273,261	419, 928	230,676	2,486,153
3	Voltage and Volt-Ampere Optimization	1,073,430		407	134,179	939,251
4	Non Standard Metering Trial Program Opt Out	279,696		407	34,962	244,734
5	Flexible Prepayment Program	6,783,246	100,574			6,883,820
6	Higgins Transformer	610,093		419, 254	76,262	533,831
7	Renewable Transmission Upgrades	438,453		182	54,807	383,646
8	NV Energize	41,338,615		407	939,514	40,399,101
9	Plant Decommissioning Costs	149,435,726	3,431,869	407	16,408,661	136,458,934
10	ON Line Expense Deferral	47,312,730		407	369,630	46,943,100
11	Net Metering Rate Difference	38,108,965	4,450,299	254, 419, 440, 442, 444-5, 456	709,295	41,849,969
12	Deferred Plant Operating Costs	63,365,083	18,114	407	7,938,749	55,444,448
13	Mohave Station NBV-Decommissioning	720,771	22,027	407	72,920	669,878
14	Navajo Retirement	32,055,288	2,097,320	108, 232, 254, 431	3,252,972	30,899,636
15	Pandemic Customer Relief	5,479,471	5,862,371	142-4, 253, 450, 904	3,026,535	8,315,307
16	Energy Choice	491,165		928	61,396	429,769
17	Merger Goodwill	110,136,453		930	1,237,488	108,898,965
18	Lenzie Plant Depreciation	50,095,650		407	612,185	49,483,465
19	Wynn Impact Fee	2,449,914	43,992			2,493,906
20	Renewable Energy Programs	13,542,019	1,987,076	254, 557	3,223,820	12,305,275
21	Energy Efficiency Implementation		1,242,431	254, 440-5	1,171,834	70,597
22	SB329 Natural Disaster Protection Plan	4,170,659	636,794	407	315,603	4,491,850
23	Deferred Fuel & Purchased Power	273,050,207	52,315,149	407, 419, 431, 557	15,077,280	310,288,076
24	Deferred Risk Management	117,154,613	490,595,051	244, 254	439,996,657	167,753,007
25	Equity Component Carry Charges	2,124,993	915,553			3,040,546
26	Regulatory Deferred Income Taxes	60,061,334	79,501			60,140,835
44	TOTAL	1,022,722,142	564,071,382		494,945,425	1,091,848,099

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets


Regulatory Dockets and Amortization periods:
Line No.	Description	PUCN Docket Numbers	Amortization Period
2	Incremental Rate Case Expenses	17-06003/20-06003	01/2021 - 12/2023*
3	Voltage and Volt-Ampere Optimization	17-06003	01/2018 - 12/2023
4	Non Standard Metering Trial Program Opt Out	17-06003	01/2018 - 12/2023
5	Flexible Prepayment Program	14-10019/15-11003	*
6	Higgins Transformer	20-06003	01/2021 - 12/2023
7	Renewable Transmission Upgrades	17-06003	01/2018 - 12/2023
8	NV Energize	14-05004	01/2015 - 12/2032
9	Plant Decommissioning Costs	17-06003/20-06003	+
10	ON Line Expense Deferral	14-05004/17-06003/20-06003	01/2015 - 12/2053
11	Net Metering Rate Difference	17-07026/20-06003	01/2021 - 12/2026*
12	Deferred Plant Operating Costs	17-06003/20-06003	01/2018 - 12/2023
13	Mohave Station NBV-Decommissioning	17-06003/20-06003	01/2018 - 12/2023
14	Navajo Retirement	17-06003/20-06003	01/2021 - 12/2023*
15	Pandemic Customer Relief	20-03021	*
16	Energy Choice	20-06003	01/2021 - 12/2023
17	Merger Goodwill	03-10001	04/2004 - 03/2044
18	Lenzie Plant Depreciation	06-11022/08-12002	06/2007 - 06/2042
19	Wynn Impact Fee	15-05006	*
20	Renewable Energy Programs	21-03005	10/2021 - 09/2022*
21	Energy Efficiency Implementation	21-03005	10/2021 - 09/2022*
22	SB329 Natural Disaster Protection Plan	21-03004	10/2021 - 09/2022*
23	Deferred Fuel & Purchased Power	21-03005	10/2021 - 09/2022*
24	Deferred Risk Management	Various	Various
25	Equity Component Carry Charges	Various	*
26	Regulatory Deferred Income Taxes	Various	Various

*	All or a portion of the charges are currently being deferred. For the amounts being deferred, the amortization period and treatment to be determined in a future regulatory proceeding.

+	Plant decommissioning costs are composed of decommissioning, environmental remediation and net book value charges. Reid Gardner environmental remediation charges are currently being deferred. Reid Gardner NBV-Decommissioning charges have an amortization period of 01/2018 - 12/2023. Reid Gardner Decommisioning charges have an amortization period of 01/2021 - 12/2023.

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

OTHER REGULATORY LIABILITIES (Account 254)
Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Liabilities being amortized, show period of amortization.
			DEBITS
Line No.	Description and Purpose of Other Regulatory Liabilities (a)	Balance at Beginning of Current Quarter/Year (b)	Account Credited (c)	Amount (d)	Credits (e)	Balance at End of Current Quarter/Year (f)
1	(a) Refer to footnote for Dkt. Nos. and amort. period
2	Gain on Licensing Transaction	8,081,301	421	1,010,163		7,071,138
3	Impact Fees excluding BTER	33,078,922	456	4,071,862	181,463	29,188,523
4	Net Energy Metering	474,828	182, 419, 440, 442, 445, 456	1,731,900	2,640,110	1,383,038
5	Earning Sharing Mechanism	73,315,755			3,410,530	76,726,285
6	PUCN Disallowed costs	13,230,801	190, 407	168,558		13,062,243
7	Navajo Retirement	21,467,513	407	2,683,357		18,784,156
8	ON Line Reallocation Deferral	6,845,097	407, 431	855,637		5,989,460
9	BTER Impact Fees	2,117,146	456	672,495	2,219	1,446,870
10	Energy Efficiency/Renewable Programs	35,690,955	182, 440-5	1,440,818		34,250,137
11	Temporary Renewable Energy Program	13,733,708	144, 440-5	2,262,950	3,596,206	15,066,964
12	Equity Component Carry Charges	44,207,956	419	3,369,457	1,052,012	41,890,511
13	Risk Management	3,910,070	175	4,834,433	1,106,087	181,724
14	Deferred Tax Unamortized ITC	3,184,084	190	27,788		3,156,296
15	Regulatory Deferred Income Taxes	598,072,376	182	4,457,580		593,614,796
16	Excess Deferred Taxes - Non Property	62,082,641	190, 236, 411	6,765,610	75,056	55,392,087
41	TOTAL	919,493,153		34,352,608	12,063,683	897,204,228

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities


Regulatory Dockets and Amortization periods:
Line No.	Description	PUCN Docket Numbers	Amortization Period
2	Gain on Licensing Transaction	15-06019/20-06003	01/2021 - 12/2023
3	Impact Fees excluding BTER	Various	Various
4	Net Energy Metering	17-06003/20-06003	01/2018 - 12/2023*
5	Earning Sharing Mechanism	17-06003/20-06003	*
6	PUCN Disallowed Costs	16-06006/17-06003	Various
7	Navajo Retirement	17-06003/20-06003	01/2021 - 12/2023
8	ON Line Reallocation Deferral	19-05002/20-06003	01/2021 - 12/2023
9	BTER Impact Fees	Various	Various
10	Energy Efficiency/Renewable Programs	21-03005	10/2021 - 09/2022*
11	Temporary Renewable Energy Program	21-03005	10/2021 - 09/2022*
12	Equity Component Carry Charges	Various	Various
13	Risk Management	Various	Various
14	Deferred Tax Unamortized ITC	Various	Various
15	Regulatory Deferred Income Taxes	Various	Various
16	Excess Deferred Taxes - Non Property	18-02010/20-06003	10/2020 - 12/2023

*	All or a portion of the charges are currently being deferred. For the amounts being deferred, the amortization period and treatment to be determined in a future regulatory proceeding.

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

Electric Operating Revenues
The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages. Report below operating revenues for each prescribed account, and manufactured gas revenues in total. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.) See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.	Title of Account (a)	Operating Revenues Year to Date Quarterly/Annual (b)	Operating Revenues Previous year (no Quarterly) (c)	MEGAWATT HOURS SOLD Year to Date Quarterly/Annual (d)	MEGAWATT HOURS SOLD Amount Previous year (no Quarterly) (e)	AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly) (f)	AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly) (g)
1	SalesOfElectricityHeadingAbstract Sales of Electricity
2	ResidentialSalesAbstract (440) Residential Sales	(a) 215,898,459		(f) 1,585,429
3	CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales
4	CommercialSalesAbstract Small (or Comm.) (See Instr. 4)	(b) 97,016,884		(g) 998,085
5	IndustrialSalesAbstract Large (or Ind.) (See Instr. 4)	84,680,250		1,174,551
6	PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting	(c) 2,345,345		(h) 37,537
7	OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities	728,547		8,429
8	SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways
9	InterdepartmentalSalesAbstract (448) Interdepartmental Sales
10	SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers	400,669,485		3,804,031
11	SalesForResaleAbstract (447) Sales for Resale	27,718,385		549,504
12	SalesOfElectricityAbstract TOTAL Sales of Electricity	428,387,870		4,353,535
13	ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds	873,899
14	RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds	427,513,971		4,353,535
15	OtherOperatingRevenuesAbstract Other Operating Revenues
16	ForfeitedDiscounts (450) Forfeited Discounts	1,065,818
17	MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues	(d) 1,141,667
18	SalesOfWaterAndWaterPower (453) Sales of Water and Water Power
19	RentFromElectricProperty (454) Rent from Electric Property	231,733
20	InterdepartmentalRents (455) Interdepartmental Rents
21	OtherElectricRevenue (456) Other Electric Revenues	(e) 7,053,629
22	RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others	10,869,580
23	RegionalTransmissionServiceRevenues (457.1) Regional Control Service Revenues
24	MiscellaneousRevenue (457.2) Miscellaneous Revenues
25	OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues
25.1	OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues
26	OtherOperatingRevenues TOTAL Other Operating Revenues	18,079,093
27	ElectricOperatingRevenues TOTAL Electric Operating Revenues	445,593,064
Line12, column (b) includes $ 9,178,725 of unbilled revenues.
Line12, column (d) includes 164,791 MWH relating to unbilled revenues

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: ResidentialSales


Unmetered Sales	Revenue
440 Private Area Lighting - Residential	$	18,517

(b) Concept: SmallOrCommercialSalesElectricOperatingRevenue


Unmetered Sales	Revenue
442 Private Area Lighting - Commercial	$	62,244


Unmetered Sales	Revenue
444 Street Lights	$	19,164

(d) Concept: MiscellaneousServiceRevenues


Description	Amount
Misc. Service Revenue - Service Charges	$	(1,428,475)
Remaining Misc. Revenue Under $250,000 Threshold	286,808
Total	$	(1,141,667)

(e) Concept: OtherElectricRevenue


Description	Amount
Other Electric Revenue - CIAC Amortization and Gross-Ups	$	2,226,321
DOS Impact Fee and Amort of Impact Fee	4,766,768
Remaining Other Revenue Under $250,000 Threshold	60,540
Total	$	7,053,629

(f) Concept: MegawattHoursSoldResidentialSales


Unmetered Sales			MWH
440 Private Area Lighting - Residential			151

(g) Concept: MegawattHoursSoldSmallOrCommercial


Unmetered Sales			MWH
442 Private Area Lighting - Commercial			563

(h) Concept: MegawattHoursSoldPublicStreetAndHighwayLighting


Unmetered Sales			MWH
444 Street Lights			190

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

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

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

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)	1,238,865
3	SteamPowerGenerationMaintenanceExpense Steam Power Generation – Maintenance (510-515)	147,084
4	PowerProductionExpensesSteamPower Total Power Production Expenses - Steam Power	1,385,949
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)	152,194,876
12	MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration Other Power Generation – Maintenance (551-554.1)	7,007,209
13	MaintenanceOfMiscellaneousOtherPowerGenerationPlant Total Power Production Expenses - Other Power	159,202,085
14	OtherPowerSuplyExpensesAbstract Other Power Supply Expenses
15	PurchasedPower (555) Purchased Power	121,233,748
15.1	PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations
16	SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching
17	OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses	30,441,958
18	OtherPowerSupplyExpense Total Other Power Supply Expenses (line 15-17)	90,791,790
19	PowerProductionExpenses Total Power Production Expenses (Total of lines 4, 7, 10, 13 and 18)	251,379,824
20	TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES
21	TransmissionExpensesOperationAbstract Transmission Operation Expenses
22	OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering	101,861
24	LoadDispatchReliability (561.1) Load Dispatch-Reliability
25	LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System	525,436
26	LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling	93,444
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	192,214
32	StationExpensesTransmissionExpense (562) Station Expenses	56,876
32.1	OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment
33	OverheadLineExpense (563) Overhead Lines Expenses	436,384
34	UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses
35	TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others	506,850
36	MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses	1,241,576
37	RentsTransmissionElectricExpense (567) Rents	9,310,916
38	OperationSuppliesAndExpensesTransmissionExpense (567.1) Operation Supplies and Expenses (Non-Major)
39	TransmissionOperationExpense TOTAL Transmission Operation Expenses (Lines 22 - 38)	12,465,557
40	TransmissionMaintenanceAbstract Transmission Maintenance Expenses
41	MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering	199
42	MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures	8,635
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	284,612
47.1	MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment
48	MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines	47,756
49	MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines
50	MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant	4,913
51	MaintenanceOfTransmissionPlant (574) Maintenance of Transmission Plant
52	TransmissionMaintenanceExpenseElectric TOTAL Transmission Maintenance Expenses (Lines 41 – 51)	346,115
53	TransmissionExpenses Total Transmission Expenses (Lines 39 and 52)	12,811,672
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)	3,448,694
74	DistributionMaintenanceExpenseElectric Distribution Maintenance Expenses (590-598)	2,770,951
75	DistributionExpenses Total Distribution Expenses (Lines 73 and 74)	6,219,645

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

Electric Customer Accts, Service, Sales, Admin and General Expenses
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	8,510,786
2	CustomerServiceAndInformationExpenses (907-910) Customer Service and Information Expenses	2,764,660
3	SalesExpenses (911-917) Sales Expenses	87,303
4	AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
5	AdministrativeAndGeneralExpensesOperationAbstract Operation
6	AdministrativeAndGeneralSalaries (920) Administrative and General Salaries	6,222,678
7	OfficeSuppliesAndExpenses (921) Office Supplies and Expenses	3,104,128
8	AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit	1,777,317
9	OutsideServicesEmployed (923) Outside Services Employed	2,538,696
10	PropertyInsurance (924) Property Insurance	129,139
11	InjuriesAndDamages (925) Injuries and Damages	1,800,717
12	EmployeePensionsAndBenefits (926) Employee Pensions and Benefits	3,864,673
13	FranchiseRequirements (927) Franchise Requirements
14	RegulatoryCommissionExpenses (928) Regulatory Commission Expenses	2,634,375
15	DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr.	463,458
16	GeneralAdvertisingExpenses (930.1) General Advertising Expenses
17	MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses	1,435,485
18	RentsAdministrativeAndGeneralExpense (931) Rents	1,723,240
19	AdministrativeAndGeneralOperationExpense TOTAL Operation (Total of lines 6 thru 18)	21,212,356
20	AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance
21	MaintenanceOfGeneralPlant (935) Maintenance of General Plant	640,167
22	AdministrativeAndGeneralExpenses TOTAL Administrative and General Expenses (Total of lines 19 and 21)	21,852,523

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

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

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

TRANSFER OF ENERGY

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS

Line No.

(a)

(b)

(c)

(d)

(e)

(f)

(g)

(h)

(i)

(j)

(k)

(l)

(m)

(n)

Arizona Electric Power Cooperative

Western Area Power Administration, Lower Colorado Region

NV Energy Marketing

V1-1,2,8

MEAD230

Mercury138

1,258

6,478

(h)

939

7,417

Arizona Electric Power Cooperative

Various

V1-1,2,8

Various

35,057

(i)

5,107

40,164

Bonneville Power Administration

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

M345

MEAD230

(j)

Brookfield Energy Marketing

CAISO

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

Summit120

MEAD230

(k)

Brookfield Energy Marketing

Los Angeles Department of Water and Power

V1-1,2,8

NAVAJO500

McCulloug500

312

1,853

(l)

262

2,115

Brookfield Energy Marketing

Los Angeles Department of Water and Power

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

NAVAJO500

MEAD230

446

(m)

509

Brookfield Energy Marketing

Western Area Power Administration, Lower Colorado Region

(b)

CAISO

V1-1,2,8

MEAD230

HA500

287

(n)

328

Brookfield Energy Marketing

Various

V1-1,2,8

Various

328

(o)

375

ConocoPhillips Company

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

M345

MEAD230

194

784

(p)

119

903

ConocoPhillips Company

(a)

PacifiCorp East

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

REDB

MEAD230

374

(q)

427

Coral Power LLC

Idaho Power Company

CAISO

V1-1,2,8

M345

ELDORADO230

5,321

26,849

(r)

3,905

30,754

Coral Power LLC

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

M345

MEAD230

5,586

24,899

(s)

3,709

28,608

Coral Power LLC

Los Angeles Department of Water and Power

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

NAVAJO500

MEAD230

200

666

(t)

106

772

Coral Power LLC

NV Energy Marketing

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

NORTHSYS

MEAD230

115

513

(u)

589

Coral Power LLC

PacifiCorp East

CAISO

V1-1,2,8

GON.PAV

ELDORADO230

183

609

(v)

706

Coral Power LLC

PacifiCorp East

CAISO

V1-1,2,8

REDB

ELDORADO230

334

1,384

(w)

209

1,593

Coral Power LLC

PacifiCorp East

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

REDB

MEAD230

844

3,737

(x)

557

4,294

Coral Power LLC

Western Area Power Administration, Lower Colorado Region

PacifiCorp East

V1-1,2,8

MEAD230

REDB

5,504

31,692

(y)

4,504

36,196

Coral Power LLC

Various

V1-1,2,8

Various

23,597

(z)

3,361

26,958

Dynasty Power Inc.

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

M345

MEAD230

425

1,611

(aa)

249

1,860

Dynasty Power Inc.

PacifiCorp East

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

REDB

MEAD230

167

(ab)

194

Dynasty Power Inc.

Various

V1-1,2,8

Various

28,652

(ac)

4,219

32,871

Eagle Energy Partners

Various

V1-1,2,8

Various

5,239

(ad)

749

5,988

Enel Trading North America

PacifiCorp East

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

REDB

MEAD500

552

2,300

(ae)

329

2,629

Enel Trading North America

Various

V1-1,2,8

Various

4,600

(af)

657

5,257

Energy Keepers

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

M345

MEAD230

5,920

23,186

(ag)

3,416

26,602

Energy Keepers

Idaho Power Company

CAISO

SFP

V1-1,2,8

M345

ELDORADO230

1,416

5,900

(ah)

843

6,743

Energy Keepers

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

SFP

V1-1,2,8

M345

MEAD230

5,304

22,100

(ai)

3,158

25,258

Energy Keepers

Various

V1-1,2,8

Various

8,361

(aj)

1,217

9,578

Guzman Energy

Idaho Power Company

Los Angeles Department of Water and Power

V1-1,2,8

M345

NAVAJO500

160

533

(ak)

618

Guzman Energy

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

M345

MEAD230

130

720

(al)

103

823

Guzman Energy

Los Angeles Department of Water and Power

PacifiCorp East

SFP

V1-1,2,8

McCulloug500

REDB

8,400

28,500

(am)

4,426

32,926

Guzman Energy

Various

V1-1,2,8

Various

1,037

(an)

161

1,198

MacQuarie Cook Power Inc.

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

M345

MEAD230

2,616

8,711

(ao)

1,386

10,097

MacQuarie Cook Power Inc.

Various

V1-1,2,8

Various

19,450

(ap)

2,838

22,288

Morgan Stanley Capital Group Inc

Idaho Power Company

CAISO

LFP

V1-1,2,7

M345

ELDORADO230

108,000

370,500

(aq)

57,543

428,043

Morgan Stanley Capital Group Inc

Bonneville Power Administration

CAISO

V1-1,2,8

HILLTOP345

ELDORADO230

225

1,076

(ar)

158

1,234

Morgan Stanley Capital Group Inc

CAISO

PacifiCorp East

V1-1,2,8

ELDORADO230

REDB

(as)

Morgan Stanley Capital Group Inc

Idaho Power Company

CAISO

V1-1,2,8

M345

ELDORADO230

252,645

1,035,348

(at)

151,162

1,186,510

Morgan Stanley Capital Group Inc

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

M345

MEAD230

271

1,036

(au)

159

1,195

Morgan Stanley Capital Group Inc

PacifiCorp East

CAISO

V1-1,2,8

REDB

ELDORADO230

9,468

41,856

(av)

6,245

48,101

Morgan Stanley Capital Group Inc

PacifiCorp East

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

REDB

MEAD230

374

2,044

(aw)

293

2,337

Morgan Stanley Capital Group Inc

Western Area Power Administration, Lower Colorado Region

CAISO

V1-1,2,8

MEAD230

ELDORADO230

143

604

(ax)

695

Morgan Stanley Capital Group Inc

CAISO

PacifiCorp East

SFP

V1-1,2,8

ELDORADO230

REDB

16,800

57,000

(ay)

8,853

65,853

Morgan Stanley Capital Group Inc

Idaho Power Company

CAISO

SFP

V1-1,2,8

M345

ELDORADO230

25,968

103,230

(az)

15,105

118,335

Morgan Stanley Capital Group Inc

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

SFP

V1-1,2,8

M345

MEAD230

240

1,000

(ba)

143

1,143

Morgan Stanley Capital Group Inc

PacifiCorp East

CAISO

SFP

V1-1,2,8

REDB

ELDORADO230

17,904

72,600

(bb)

10,495

83,095

Morgan Stanley Capital Group Inc

PacifiCorp East

Western Area Power Administration, Lower Colorado Region

SFP

V1-1,2,8

REDB

MEAD230

1,584

6,600

(bc)

943

7,543

Morgan Stanley Capital Group Inc

Western Area Power Administration, Lower Colorado Region

PacifiCorp East

SFP

V1-1,2,8

MEAD230

REDB

25,536

86,640

(bd)

13,456

100,096

Morgan Stanley Capital Group Inc

Various

V1-1,2,7,8

Various

459,698

(be)

67,855

527,553

Open Mountain Energy LLC

NV Energy Marketing

Los Angeles Department of Water and Power

LFP

V1-1,2,7

NORTHSYS

MCCULLOUG500

41,040

140,790

(bf)

21,866

162,656

Open Mountain Energy LLC

Various

V1-1,2,7

Various

43,575

(bg)

9,240

34,335

ON Line Allocation to Sierra Pacific Power Company

Various

V1-1,2,7,8

Various

164,598

(bh)

17,738

182,336

Ormat Technologies

NV Energy Marketing

Los Angeles Department of Water and Power

LFP

V1-1,2,7

NORTHSYS

CRYSTAL500

168,480

(c)

577,980

Ormat Technologies

NV Energy Marketing

Los Angeles Department of Water and Power

LFP

V1-1,2,7

NORTHSYS

McCulloug500

14,160

(d)

49,400

Ormat Technologies

NV Energy Marketing

Western Area Power Administration, Lower Colorado Region

LFP

V1-1,2,7

NORTHSYS

MEAD230

302,400

1,037,400

(bi)

258,560

1,295,960

Ormat Technologies

NV Energy Marketing

Los Angeles Department of Water and Power

V1-1,2,8

NORTHSYS

CRYSTAL500

1,485

6,527

(bj)

972

7,499

Ormat Technologies

NV Energy Marketing

Los Angeles Department of Water and Power

V1-1,2,8

NORTHSYS

MCCULLOUG500

9,270

47,077

(bk)

6,838

53,915

Ormat Technologies

NV Energy Marketing

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

NORTHSYS

MEAD230

334

1,921

(bl)

273

2,194

Ormat Technologies

Various

V1-1,2,7,8

Various

481,628

(bm)

38,502

520,130

PacifiCorp

PacifiCorp East

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

GON.PAV

MEAD230

260

1,257

(bn)

184

1,441

PacifiCorp

PacifiCorp East

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

REDB

MEAD230

9,425

33,473

(bo)

5,243

38,716

PacifiCorp

Western Area Power Administration, Lower Colorado Region

NV Energy Marketing

V1-1,2,8

MEAD230

Southsys

260

1,257

(bp)

184

1,441

PacifiCorp

Western Area Power Administration, Lower Colorado Region

PacifiCorp East

V1-1,2,8

5200

MEAD230

5,200

30,888

(bq)

4,368

35,256

PacifiCorp

PacifiCorp East

Western Area Power Administration, Lower Colorado Region

SFP

V1-1,2,8

REDB

MEAD230

6,000

23,000

(br)

3,408

26,408

PacifiCorp

Various

V1-1,2,8

Various

107,334

(bs)

15,579

122,913

PacifiCorp Power Marketing

Bonneville Power Administration

Arizona Public Service

V1-1,2,8

HILLTOP345

NAVAJO500

155

660

(bt)

759

PacifiCorp Power Marketing

Bonneville Power Administration

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

HILLTOP345

MEAD230

297

(bu)

339

PacifiCorp Power Marketing

Various

V1-1,2,8

Various

4,268

(bv)

613

4,881

Powerex (BC Power Exchange)

Bonneville Power Administration

Western Area Power Administration, Lower Colorado Region

LFP

V1-1,2,7

HILLTOP345

MEAD230

45,360

155,610

(bw)

36,828

192,438

Powerex (BC Power Exchange)

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

LFP

V1-1,2,7

M345

MEAD230

23,760

(e)

81,510

Powerex (BC Power Exchange)

Idaho Power Company

CAISO

V1-1,2,8

M345

ELDORADO230

6,122

33,885

(bx)

4,848

38,733

Powerex (BC Power Exchange)

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

M345

MEAD230

4,175

22,492

(by)

3,233

25,725

Powerex (BC Power Exchange)

PacifiCorp East

CAISO

V1-1,2,8

REDB

ELDORADO230

131

(bz)

149

Powerex (BC Power Exchange)

PacifiCorp East

Los Angeles Department of Water and Power

V1-1,2,8

REDB

NAVAJO500

280

(ca)

325

Powerex (BC Power Exchange)

PacifiCorp East

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

GON.PAV

MEAD230

143

(cb)

163

Powerex (BC Power Exchange)

PacifiCorp East

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

REDB

MEAD230

1,078

6,228

(cc)

885

7,113

Powerex (BC Power Exchange)

PacifiCorp East

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

REDB

MEAD230

1,416

4,940

(cd)

767

5,707

Powerex (BC Power Exchange)

Various

V1-1,2,7,8

Various

77,183

(ce)

11,724

88,907

Rainbow Energy South

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

M345

MEAD230

172

990

(cf)

141

1,131

Rainbow Energy South

Various

V1-1,2,8

Various

1,485

(cg)

210

1,695

Salt River Project

PacifiCorp East

Los Angeles Department of Water and Power

LFP

V1-1,2,7

REDB

NAVAJO500

54,000

185,250

(ch)

28,772

214,022

Southern California Edison

PacifiCorp East

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

REDB

MEAD230

1,881

8,344

(ci)

1,244

9,588

Tenaska Energy Management

Idaho Power Company

Los Angeles Department of Water and Power

V1-1,2,8

M345

NAVAJO500

475

(cj)

542

Tenaska Energy Management

Western Area Power Administration, Lower Colorado Region

PacifiCorp East

SFP

V1-1,2,8

MEAD230

REDB

168

700

(ck)

100

800

The Energy Authority

Arizona Public Service

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

MOENKOPI500

MEAD230

117

(cl)

136

The Energy Authority

Bonneville Power Administration

CAISO

V1-1,2,8

HILLTOP345

ELDORADO230

446

(cm)

509

The Energy Authority

Idaho Power Company

CAISO

V1-1,2,8

M345

ELDORADO230

6,255

21,429

(cn)

3,386

24,815

The Energy Authority

Idaho Power Company

Los Angeles Department of Water and Power

V1-1,2,8

M345

NAVAJO500

120

556

(co)

638

The Energy Authority

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

M345

MEAD230

12,405

53,448

(cp)

8,016

61,464

The Energy Authority

Western Area Power Administration, Lower Colorado Region

CAISO

V1-1,2,8

MEAD230

ELDORADO230

400

2,376

(cq)

336

2,712

The Energy Authority

Various

V1-1,2,8

Various

974

(cr)

994

TransAlta Energy Marketing

CAISO

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

Summit120

MEAD230

(cs)

TransAlta Energy Marketing

Idaho Power Company

Los Angeles Department of Water and Power

V1-1,2,8

M345

MCCULLOUG500

1,620

6,843

(ct)

1,031

7,874

TransAlta Energy Marketing

Idaho Power Company

Los Angeles Department of Water and Power

V1-1,2,8

M345

NAVAJO500

200

1,058

(cu)

153

1,211

TransAlta Energy Marketing

Idaho Power Company

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

M345

MEAD230

279

929

(cv)

148

1,077

TransAlta Energy Marketing

PacifiCorp East

Los Angeles Department of Water and Power

V1-1,2,8

REDB

MCCULLOUG500

305

1,055

(cw)

166

1,221

TransAlta Energy Marketing

PacifiCorp East

Western Area Power Administration, Lower Colorado Region

V1-1,2,8

REDB

MEAD230

400

1,332

(cx)

212

1,544

TransAlta Energy Marketing

Various

V1-1,2,8

Various

5,290

(cy)

741

6,031

100

Various Customers

Unknown

V1-7,8

Various

(cz)

13,992

101

Various Customers

Unknown

V1-7,8

Various

(f)

34,357

102

Air Liquide South

Various

Air Liquide South

FNO

V1 1,2,3,5,6,H

Hilltop345

Mead 230

3,349

(da)

843

4,192

103

Caesars Entertainment South

Various

Caesars Entertainment South

FNO

V1 1,2,3,5,6,H

Mead230

Southsys

159

377,833

(db)

100,493

478,326

104

Circus Circus LV LLC

Various

Circus Circus LV LLC

FNO

V1 1,2,3,5,6,H

Mead230

Southsys

38,201

(dc)

10,166

48,367

105

CRC-BMI Ancillary Services

N/A

V1 1,2,3,5,6

N/A

(dd)

32,821

106

Exelon Generation for Wynn Resorts

Various

Wynn/Encore Resorts

FNO

V1 1,2,3,5,6,H

Mead230

Southsys

136,554

(de)

36,299

172,853

107

Georgia Pacific Gypsum LLC

Various

Georgia Pacific

FNO

V1 1,2,3,5,6,H

Mead230

Southsys

21,561

(df)

5,722

27,283

108

MGM Resorts NITS

Various

MGM Resorts International

FNO

V1 1,2,3,5,6,H

Mead230

Southsys

276

651,136

(dg)

173,267

824,403

109

Overton LTP Agreement

Various

TS Power Plant

FNO

V1 1,2,3,5,6,H

Mead230

Southsys

176

301,638

(dh)

69,066

370,704

110

Sahara Las Vegas Resort Holding LLC

Various

Sahara Las Vegas

FNO

V1 1,2,3,5,6,H

Mead230

Southsys

20,955

(di)

5,574

26,529

111

Southern California Public Power Authority

APEX LS

Los Angeles Dept of Water & Power

LFP

V1 1,2,3,5,6,7

Harry Allen 500

Mead 230

1,500

3,705,000

(dj)

127,500

3,832,500

112

Southern Nv Water Authority

Various

Southern Nv Water Authority

FNO

V1 1,2,3,5,6,H

Harry Allen 500

Mead 230

123

306,646

(dk)

81,623

388,269

113

SWITCH-South

Various

Switch-South

FNO

V1 1,2,3,5,6,H

Mead230

Southsys

234

574,981

(dl)

152,908

727,889

114

Basic Management Inc

Western Area Power Admin

Basic Management Inc

OLF

RS 61

Mead Substation

Clark Substation

6,576

(g)

3,288

TOTAL

9,203

1,223,146

9,497,457

1,372,123

10,869,580

Name of Respondent:

Nevada Power Company, d/b/a NV Energy

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

05/27/2022

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName

This footnote applies to all occurrences of "PacifiCorp" on Pages 328-330. PacifiCorp is an indirect subsidiary of Berkshire Hathaway Energy Company, Nevada Power Company's indirect parent company.

(b) Concept: TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName

This footnote applies to all occurrences of "CAISO" on pages 328-330. Complete name is California Independent System Operator.

Ancillary service provided.

(d) Concept: EnergyChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(e) Concept: EnergyChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(f) Concept: EnergyChargesRevenueTransmissionOfElectricityForOthers

Wind induced vibration settlement reserve.

(g) Concept: EnergyChargesRevenueTransmissionOfElectricityForOthers

Basic Management Inc - five year written notice to terminate.

(h) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided. For all occurrences of "Ancillary services provided" on page 328-330, NV Energy filed on March 10, 2022 and FERC ordered on May 9, 2022 with an effective date of March 11, 2022 the elimination of schedule 2 from the Open Access Transmission Tariff (OATT).

(i) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(j) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(k) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(l) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(m) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(n) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(o) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(p) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(q) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(r) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(s) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(t) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(u) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(v) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(w) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(x) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(y) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(z) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(aa) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(ab) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(ac) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(ad) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(ae) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(af) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(ag) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(ah) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(ai) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(aj) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(ak) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(al) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(am) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(an) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(ao) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(ap) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(aq) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(ar) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(as) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(at) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(au) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(av) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(aw) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(ax) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(ay) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(az) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(ba) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bb) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bc) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bd) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(be) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Pursuant to Nevada Commission an allocator is used to allocate a portion of revenue to Sierra Pacific Power Company. Allocator is based on ON Line use.

(bf) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bg) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Pursuant to Nevada Commission an allocator is used to allocate a portion of revenue to Sierra Pacific Power Company. Allocator is based on ON Line use.

(bh) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Pursuant to Nevada Commission an allocator is used to allocate a portion of revenue to Sierra Pacific Power Company. Allocator is based on ON Line use.

(bi) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bj) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bk) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bl) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bm) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Pursuant to Nevada Commission an allocator is used to allocate a portion of revenue to Sierra Pacific Power Company. Allocator is based on ON Line use.

(bn) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bo) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bp) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bq) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(br) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bs) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(bt) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bu) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bv) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(bw) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bx) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(by) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(bz) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(ca) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cb) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cc) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cd) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(ce) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(cf) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cg) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(ch) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(ci) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cj) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(ck) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cl) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cm) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cn) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(co) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cp) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cq) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cr) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(cs) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(ct) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cu) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cv) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cw) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cx) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary service provided.

(cy) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Out of period adjustment. Timing of accrual.

(cz) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Schedule 1 A transactions due to participation in CAISO Energy Imbalance Market.

(da) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Network transmission service under the Open Access Transmission Tariff Volume 1.

(db) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Network transmission service under the Open Access Transmission Tariff Volume 1.

(dc) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Network transmission service under the Open Access Transmission Tariff Volume 1.

(dd) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Ancillary services only agreement under Open Access Transmission Tariff Volume 1.

(de) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Network transmission service under the Open Access Transmission Tariff Volume 1.

(df) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Network transmission service under the Open Access Transmission Tariff Volume 1.

(dg) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Network transmission service under the Open Access Transmission Tariff Volume 1.

(dh) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Overton Power District No. 5 - Transmission Service Charge. Agreement is effective until Overton's State allocation of federal power is terminated.

(di) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Network transmission service under the Open Access Transmission Tariff Volume 1.

(dj) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Long Term Firm transmission service under Open Access Transmission Tariff Volume 1 , Scheduling, system control and dispatch service.

(dk) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Network transmission service under the Open Access Transmission Tariff Volume 1.

(dl) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Network transmission service under the Open Access Transmission Tariff Volume 1.

TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. Enter ""TOTAL"" in column (a) as the last line. Footnote entries and provide explanations following all required data.
			TRANSFER OF ENERGY		EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.	NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	TransmissionOfElectricityByOthersEnergyReceived MegaWatt Hours Received (c)	TransmissionOfElectricityByOthersEnergyDelivered MegaWatt Hours Delivered (d)	DemandChargesTransmissionOfElectricityByOthers Demand Charges ($) (e)	EnergyChargesTransmissionOfElectricityByOthers Energy Charges ($) (f)	OtherChargesTransmissionOfElectricityByOthers Other Charges ($) (g)	ChargesForTransmissionOfElectricityByOthers Total Cost of Transmission ($) (h)
1	Arizona Public Service Company	NF					(c) 11,879	11,879
2	(a) CAISO - EIM	LFP					(d) 142,318	142,318
3	Fort Mohave Indian Tribe/AMPS	OS
4	Idaho Power	NF	36	36		229		229
5	Los Angeles Department of Water	SFP	218	218		44,472	(e) 541	45,013
6	(b) PacifiCorp	NF	58,669	58,669			(f) 277,070	277,070
7	Salt River Project	NF
8	Western Area Power Administration	NF					(g) 30,341	30,341
	TOTAL		58,923	58,923		44,701	462,149	506,850

Deprec, Depl and Amort of Elec Plant (403,403.1,404,and 405) (except Amortization of Acquisition Adjustments)
Report the year to date amounts of depreciation expense, asset retirement cost depreciation, depletion and amortization, except amortization of acquisition adjustments for the accounts indicated and classified according to the plant functional groups described.
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			7,060,151		7,060,151
2	Steam Production Plant	1,215,474				1,215,474
3	Nuclear Production Plant
4	Hydraulic Production Plant-Conventional
5	Hydraulic Production Plant-Pumped Storage
6	Other Production Plant	30,817,887				30,817,887
7	Transmission Plant	6,489,878				6,489,878
8	Distribution Plant	23,390,508				23,390,508
9	General Plant	6,590,261				6,590,261
10	Common Plant-Electric
11	TOTAL	68,504,008		7,060,151		75,564,159

AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No.	Description of Item(s) (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1	Energy
2	Net Purchases (Account 555)	1,218,915
2.1	Net Purchases (Account 555.1)
3	Net Sales (Account 447)	1,071,133
4	Transmission Rights
5	Ancillary Services
6	Other Items (list separately)
7	Energy Imbalance Market (Account 555)	3,555,930
46	TOTAL	3,408,148

Monthly Peak Loads and Energy Output
Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system. Report in column (b) by month the system’s output in Megawatt hours for each month. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).
Line No.	MonthAxis Month (a)	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: NPC TRANSMISSION SYSTEM
1	January	1,660,938	210,586	2,423	3	19
2	February	1,420,697	203,810	2,408	2	19
3	March	1,495,475	135,108	2,702	26	18
4	Total for Quarter 1	4,577,110	549,504
5	April
6	May
7	June
8	Total for Quarter 2
9	July
10	August
11	September
12	Total for Quarter 3
41	Total

MONTHLY TRANSMISSION SYSTEM PEAK LOAD
Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No.	Month (a)	Monthly Peak MW - Total (b)	Day of Monthly Peak (c)	Hour of Monthly Peak (d)	Firm Network Service for Self (e)	Firm Network Service for Others (f)	Long-Term Firm Point-to-point Reservations (g)	Other Long-Term Firm Service (h)	Short-Term Firm Point-to-point Reservation (i)	Other Service (j)
	NAME OF SYSTEM: NPC TRANSMISSION SYSTEM
1	January	3,519	3	19	2,423	291	746			59
2	February	3,505	2	19	2,408	292	745			60
3	March	3,838	26	18	2,702	345	745			46
4	Total for Quarter 1				7,533	928	2,236			165
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				7,533	928	2,236			165




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

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

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

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

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

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

GENERAL INFORMATION

Purpose

Who Must Submit

What and Where to Submit

When to Submit

Where to Send Comments on Public Reporting Burden.

GENERAL INSTRUCTIONS

EXCERPTS FROM THE LAW

GENERAL PENALTIES

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