FERC Form

THIS FILING IS

Item 1:

☐ An Initial (Original) Submission

OR

☑ Resubmission No.




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

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

Exact Legal Name of Respondent (Company)

Entergy Louisiana, LLC

Year/Period of Report

End of:

2021

/

Q4

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

GENERAL INFORMATION

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

What and Where to Submit

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

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

The CPA Certification Statement should:

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

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

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

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

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

GENERAL INSTRUCTIONS

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

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

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

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

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

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

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

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

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

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

DEFINITIONS

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

EXCERPTS FROM THE LAW

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

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

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

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

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

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

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

"Sec. 304.

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

"Sec. 309.

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

GENERAL PENALTIES

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

FERC FORM NO.

1

REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER

IDENTIFICATION

01 Exact Legal Name of Respondent

Entergy Louisiana, LLC

02 Year/ Period of Report

End of:

2021

/

Q4

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

/

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

4809 Jefferson Highway, Jefferson, Louisiana 70121

05 Name of Contact Person

Gina G. Bellott

06 Title of Contact Person

Sr. Staff Accountant

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

639 Loyola Avenue, New Orleans, Louisiana 70113

08 Telephone of Contact Person, Including Area Code

(504) 858-3276

09 This Report is An Original / A Resubmission

(1)

☐ An Original

(2)

☑ A Resubmission

10 Date of Report (Mo, Da, Yr)

04/19/2022

Annual Corporate Officer Certification

The undersigned officer certifies that:

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

01 Name

Kimberly A. Fontan

02 Title

Sr. VP & Chief Accounting Officer

03 Signature

Kimberly A. Fontan

04 Date Signed (Mo, Da, Yr)

04/19/2022

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

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

LIST OF SCHEDULES (Electric Utility)
Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".
Line No.	Title of Schedule (a)	Reference Page No. (b)	Remarks (c)
	ScheduleIdentificationAbstract Identification	1
	ScheduleListOfSchedulesAbstract List of Schedules	2
1	ScheduleGeneralInformationAbstract General Information	101
2	ScheduleControlOverRespondentAbstract Control Over Respondent	102
3	ScheduleCorporationsControlledByRespondentAbstract Corporations Controlled by Respondent	103
4	ScheduleOfficersAbstract Officers	104
5	ScheduleDirectorsAbstract Directors	105
6	ScheduleInformationOnFormulaRatesAbstract Information on Formula Rates	106
7	ScheduleImportantChangesDuringTheQuarterYearAbstract Important Changes During the Year	108
8	ScheduleComparativeBalanceSheetAbstract Comparative Balance Sheet	110
9	ScheduleStatementOfIncomeAbstract Statement of Income for the Year	114
10	ScheduleRetainedEarningsAbstract Statement of Retained Earnings for the Year	118
12	ScheduleStatementOfCashFlowsAbstract Statement of Cash Flows	120
12	ScheduleNotesToFinancialStatementsAbstract Notes to Financial Statements	122
13	ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract Statement of Accum Other Comp Income, Comp Income, and Hedging Activities	122a
14	ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep	200
15	ScheduleNuclearFuelMaterialsAbstract Nuclear Fuel Materials	202
16	ScheduleElectricPlantInServiceAbstract Electric Plant in Service	204
17	ScheduleElectricPropertyLeasedToOthersAbstract Electric Plant Leased to Others	213	N/A
18	ScheduleElectricPlantHeldForFutureUseAbstract Electric Plant Held for Future Use	214
19	ScheduleConstructionWorkInProgressElectricAbstract Construction Work in Progress-Electric	216
20	ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract Accumulated Provision for Depreciation of Electric Utility Plant	219
21	ScheduleInvestmentsInSubsidiaryCompaniesAbstract Investment of Subsidiary Companies	224
22	ScheduleMaterialsAndSuppliesAbstract Materials and Supplies	227
23	ScheduleAllowanceInventoryAbstract Allowances	228
24	ScheduleExtraordinaryPropertyLossesAbstract Extraordinary Property Losses	230a	N/A
25	ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract Unrecovered Plant and Regulatory Study Costs	230b
26	ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract Transmission Service and Generation Interconnection Study Costs	231	N/A
27	ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets	232
28	ScheduleMiscellaneousDeferredDebitsAbstract Miscellaneous Deferred Debits	233
29	ScheduleAccumulatedDeferredIncomeTaxesAbstract Accumulated Deferred Income Taxes	234
30	ScheduleCapitalStockAbstract Capital Stock	250	N/A
31	ScheduleOtherPaidInCapitalAbstract Other Paid-in Capital	253
32	ScheduleCapitalStockExpenseAbstract Capital Stock Expense	254b	N/A
33	ScheduleLongTermDebtAbstract Long-Term Debt	256
34	ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax	261
35	ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract Taxes Accrued, Prepaid and Charged During the Year	262
36	ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract Accumulated Deferred Investment Tax Credits	266
37	ScheduleOtherDeferredCreditsAbstract Other Deferred Credits	269
38	ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract Accumulated Deferred Income Taxes-Accelerated Amortization Property	272
39	ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract Accumulated Deferred Income Taxes-Other Property	274
40	ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract Accumulated Deferred Income Taxes-Other	276
41	ScheduleOtherRegulatoryLiabilitiesAbstract Other Regulatory Liabilities	278
42	ScheduleElectricOperatingRevenuesAbstract Electric Operating Revenues	300
43	ScheduleRegionalTransmissionServiceRevenuesAbstract Regional Transmission Service Revenues (Account 457.1)	302
44	ScheduleSalesOfElectricityByRateSchedulesAbstract Sales of Electricity by Rate Schedules	304
45	ScheduleSalesForResaleAbstract Sales for Resale	310
46	ScheduleElectricOperationsAndMaintenanceExpensesAbstract Electric Operation and Maintenance Expenses	320
47	SchedulePurchasedPowerAbstract Purchased Power	326
48	ScheduleTransmissionOfElectricityForOthersAbstract Transmission of Electricity for Others	328
49	ScheduleTransmissionOfElectricityByIsoOrRtoAbstract Transmission of Electricity by ISO/RTOs	331	N/A
50	ScheduleTransmissionOfElectricityByOthersAbstract Transmission of Electricity by Others	332
51	ScheduleMiscellaneousGeneralExpensesAbstract Miscellaneous General Expenses-Electric	335
52	ScheduleDepreciationDepletionAndAmortizationAbstract Depreciation and Amortization of Electric Plant (Account 403, 404, 405)	336
53	ScheduleRegulatoryCommissionExpensesAbstract Regulatory Commission Expenses	350
54	ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract Research, Development and Demonstration Activities	352
55	ScheduleDistributionOfSalariesAndWagesAbstract Distribution of Salaries and Wages	354
56	ScheduleCommonUtilityPlantAndExpensesAbstract Common Utility Plant and Expenses	356	N/A
57	ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract Amounts included in ISO/RTO Settlement Statements	397
58	SchedulePurchasesSalesOfAncillaryServicesAbstract Purchase and Sale of Ancillary Services	398
59	ScheduleMonthlyTransmissionSystemPeakLoadAbstract Monthly Transmission System Peak Load	400
60	ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract Monthly ISO/RTO Transmission System Peak Load	400a	N/A
61	ScheduleElectricEnergyAccountAbstract Electric Energy Account	401a
62	ScheduleMonthlyPeakAndOutputAbstract Monthly Peaks and Output	401b
63	ScheduleSteamElectricGeneratingPlantStatisticsAbstract Steam Electric Generating Plant Statistics	402
64	ScheduleHydroelectricGeneratingPlantStatisticsAbstract Hydroelectric Generating Plant Statistics	406	N/A
65	SchedulePumpedStorageGeneratingPlantStatisticsAbstract Pumped Storage Generating Plant Statistics	408	N/A
66	ScheduleGeneratingPlantStatisticsAbstract Generating Plant Statistics Pages	410	N/A
0	ScheduleEnergyStorageOperationsLargePlantsAbstract Energy Storage Operations (Large Plants)	414	N/A
67	ScheduleTransmissionLineStatisticsAbstract Transmission Line Statistics Pages	422
68	ScheduleTransmissionLinesAddedAbstract Transmission Lines Added During Year	424
69	ScheduleSubstationsAbstract Substations	426
70	ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract Transactions with Associated (Affiliated) Companies	429
71	FootnoteDataAbstract Footnote Data	450	N/A
	StockholdersReportsAbstract Stockholders' Reports (check appropriate box)
	Stockholders' Reports Check appropriate box: ☐ Two copies will be submitted ☑ No annual report to stockholders is prepared

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

GENERAL INFORMATION
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept. Kimberly A. Fontan Senior Vice President and Chief Accounting Officer 639 Loyola Avenue, New Orleans, LA 70113
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized. State of Incorporation: TX Date of Incorporation: 2015-07-07 Incorporated Under Special Law:
3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased. N/A (a) Name of Receiver or Trustee Holding Property of the Respondent: (b) Date Receiver took Possession of Respondent Property: (c) Authority by which the Receivership or Trusteeship was created: (d) Date when possession by receiver or trustee ceased:
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated. Louisiana - Electric and Gas utility service
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements? (1) ☐ Yes (2) ☑ No

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.

As of December 31, 2021 all of the common membership interests in Entergy Louisiana are held by Entergy Utility Holding Company. As of December 31, 2021, Entergy Utility Holding Company's membership interests are held by: Entergy Corporation 3.5% 386,954 shares Entergy Utility Affiliates 22.2% multiple securities Entergy Utility Assets 29.7% 3,276,704 shares Entergy Utility Enterprises 12.5% 1,381,535 shares Entergy Utility Group 3.2% 350,173 shares Entergy Utility Property 27.2% 3,006,086 shares Unaffiliated third parties 1.7% multiple securities

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

CORPORATIONS CONTROLLED BY RESPONDENT
Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests. Definitions See the Uniform System of Accounts for a definition of control. Direct control is that which is exercised without interposition of an intermediary. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party.
Line No.	NameOfCompanyControlledByRespondent Name of Company Controlled (a)	CompanyControlledByRespondentKindOfBusinessDescription Kind of Business (b)	VotingStockOwnedByRespondentPercentage Percent Voting Stock Owned (c)	FootnoteReferences Footnote Ref. (d)
1	Prudential Oil & Gas L.L.C.		57.5	(a) See Footnote
2	Varibus, L.L.C.		100	(b) See Footnote
3	Southern Gulf Railway LLC		57.5	(c) See Footnote
4	Nelson Industrial Steam Company		1	(d) See Footnote

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: FootnoteReferences

Formerly in the business of exploring, developing, and operating oil and gas properties in Texas and Louisiana - presently inactive. The other interest is Entergy Texas with 42.5%.

(b) Concept: FootnoteReferences

Operates intrastate gas pipelines in Louisiana.

(c) Concept: FootnoteReferences

Owns several miles of rail track constructed in Louisiana for the purpose of transporting coal for use as boiler fuel at Nelson Unit 6. The other interest is Entergy Texas with 42.5%.

(d) Concept: FootnoteReferences

Nelson Industrial Steam Company is a joint venture between Entergy Louisiana and Citco, Sasol, and Conoco.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

OFFICERS
Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made.
Line No.	OfficerTitle Title (a)	OfficerName Name of Officer (b)	OfficerSalary Salary for Year (c)	DateOfficerIncumbencyStarted Date Started in Period (d)	DateOfficerIncumbencyEnded Date Ended in Period (e)
1	President and Chief Executive Officer of Entergy Louisiana	Phillip R. May, Jr.	413,752
2	Chief Executive Officer and Chairman of the Board of Entergy Corporation	Leo P. Denault	(a) 0
3	Executive Vice President and Chief Financial Officer	Andrew S. Marsh	(b) 0
4	Executive Vice President and Chief Operating Officer	Paul D. Hinnenkamp	(c) 0
5	Executive Vice President and General Counsel	Marcus V. Brown	(d) 0
6	Group President - Utility Operations	Roderick K. West	(e) 0
7	Executive Vice President and Chief Nuclear Officer	A.Christopher Bakken, III	(f) 0
8	Senior Vice President and Chief Accounting Officer	Kimberly A. Fontan	(g) 0
9	Senior Vice President and General Tax Counsel	Joseph T. Henderson	(h) 0		2021-08-02
10	Vice President and General Tax Counsel	Steven W. Brady	(i) 0	2021-08-02

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Louisiana.

(b) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Louisiana.

(c) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Louisiana.

(d) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Louisiana.

(e) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Louisiana.

(f) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Louisiana.

(g) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Louisiana.

(h) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Louisiana.

(i) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Louisiana.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

DIRECTORS
Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), name and abbreviated titles of the directors who are officers of the respondent. Provide the principle place of business in column (b), designate members of the Executive Committee in column (c), and the Chairman of the Executive Committee in column (d).
Line No.	NameAndTitleOfDirector Name (and Title) of Director (a)	PrincipalBusinessAddress Principal Business Address (b)	MemberOfTheExecutiveCommittee Member of the Executive Committee (c)	ChairmanOfTheExecutiveCommittee Chairman of the Executive Committee (d)
1	Phillip R. May, Jr. - President and Chief Executive Officer of Entergy Louisiana	4809 Jefferson Highway, Jefferson, LA 70121	false	false
2	Andrew S. Marsh - Executive Vice President and Chief Financial Officer	639 Loyola Avenue, New Orleans, LA 70113	true	false
3	Paul D. Hinnenkamp - Executive Vice President and Chief Operating Officer	639 Loyola Avenue, New Orleans, LA 70113	true	false
4	Roderick K. West - Group President Utility Operations	639 Loyola Avenue, New Orleans, LA 70113	true	false

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

INFORMATION ON FORMULA RATES
Does the respondent have formula rates?		☑ Yes ☐ No
Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate.
Line No.	RateScheduleTariffNumber FERC Rate Schedule or Tariff Number (a)	ProceedingDocketNumber FERC Proceeding (b)
1	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Baseline Tariff	Docket No. ER13-1508
2	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER16-218
3	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER16-2199
4	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER18-1247
5	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER21-915
6	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER21-1720
7	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER21-1997
8	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER21-2169
9	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER21-489
10	Midcontinent Indepedent System Operator (MISO) FERC Electric Tariff - Fifth Revised Volume 1	Docket No. ER13-948
11	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER14-649
12	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER15-358
13	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER15-1436
14	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER16-227
15	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER16-1322
16	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-215
17	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-1549
18	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-1777
19	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-2579
20	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER18-1260
21	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER18-1982
22	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER19-652
23	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER19-1503
24	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-827
25	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER20-1449
26	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER20-1472
27	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER21-200
28	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER21-262
29	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER21-1564
30	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER21-2693

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)?			☑ Yes ☐ No
If yes, provide a listing of such filings as contained on the Commission's eLibrary website.
Line No.	AccessionNumber Accession No. (a)	DocumentDate Document Date / Filed Date (b)	DocketNumber Docket No. (c)	DescriptionOfFiling Description (d)	RateScheduleTariffNumber Formula Rate FERC Rate Schedule Number or Tariff Number (e)
1	20210315-5351	03/15/2021	ER21-1429	(a) Annual Informational MISO Attachment O Transmission Formula Rate Update

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: DescriptionOfFiling

Pursuant to the Federal Energy Regulatory Commission’s orders in Docket Nos. EL12-35 and ER13-2379 and the Annual Update, Information Exchange, and Challenge Procedures of the Entergy Operating Companies set forth in Attachment O of the Midcontinent Independent System Operator, Inc.’s Open Access Transmission, Energy and Operating Reserve Markets Tariff, Entergy Services shall submit an annual Informational Filing on March 15 based on data for the second preceding calendar year data. The 2019 update was filed on March 15, 2021 in Docket No. ER21-1429. This Informational Filing is not a rate filing. It shows the development of the Entergy Operating Companies’ annual transmission revenue requirements for billing June 1, 2020 through May 31, 2021 through the application of data for the Calendar Year 2019 under the Attachment O MISO Tariff.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

INFORMATION ON FORMULA RATES - Formula Rate Variances
If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from amounts reported in the Form 1. The footnote should provide a narrative description explaining how the "rate" (or billing) was derived if different from the reported amount in the Form 1. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote.
Line No.	PageNumberOfFormulaRateVariances Page No(s). (a)	ScheduleOfFormulaRateVariances Schedule (b)	ColumnOfFormulaRateVariances Column (c)	LineNumberOfFormulaRateVariances Line No. (d)
1	(a) 111	Comparative Balance Sheet	(c)	57
2	117	Statement of Income for the Year	(c)	70
3	118	Statement of Retained Earnings	(c)	29
4	118	Statement of Retained Earnings	(c)	36
5	204,206	Electric Plant in Service	(g)	8-14,18-24,27-34
6	204,206	Electric Plant in Service	(g)	37-43, 50
7	204,206	Electric Plant in Service	(g)	4, 86-95
8	206	Electric Plant in Service	(g)	97
9	219	Accumulated Provision for Depreciation	(c)	1
10	227	Materials and Supplies	(c)	1-2
11	227	Materials and Supplies	(c)	12,16
12	234	Accumulated Deferred Income Taxes (Account 190)	(c)	2
13	262	Taxes Accrued, Prepaid and Charged During the Year	(d)	17
14	262	Taxes Accrued, Prepaid and Charged During the Year	(d)	2,9
15	262	Taxes Accrued, Prepaid and Charged During the Year	(d)	3,4,10
16	266	Accumulated Deferred Investment Credits	(f)	8
17	275	Accumulated Deferred Income Taxes (Account 282)	(k)	2
18	277	Accumulated Deferred Income Taxes (Account 283)	(k)	3
19	320	Electric Operations and Maintenance Expense	(c)	4, 6, 11, 15-19
20	320-321	Electric Operations and Maintenance Expense	(b)	4,6-11,15-19,24,26-30, 35-39,44-49, 53-57, 62, 64-66, and 69-72
21	321	Electric Operations and Maintenance Expense	(b)	93, 107
22	323	Electric Operations and Maintenance Expense	(b)	181-184, 186-193
23	323	Electric Operations and Maintenance Expense	(b)	185
24	336	Depreciation Expense	(f)	2-7
25	336	Depreciation Expense	(f)	10

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: PageNumberOfFormulaRateVariances


Line No.	Page No(s).	Schedule	Column	Line No.
	All	The following footnotes relate to RS No. 705, Unit Power Sales/Designated Power Purchase Tariff (UPS/DPPT)
1	111	Comparative Balance Sheet Prepayments used in UPS/DPPT, differs from Form 1 amounts because the formula rate reflects an allocation of the balance at the last day of the previous month, allocated using plant ratios	(c)	57
2	117	Statement of Income for the Year Interest expense used in UPS/DPPT, differs from Form 1 amounts because the formula rate reflects the embedded cost of debt at the last day of the previous month times the Debt Capitalization ratio at the last day of the previous month	(c)	70
3	118	Statement of Retained Earnings Return on Preferred Stock used UPS/DPPT, differs from Form 1 amounts because the formula rate calculates Return on Preferred Stock using the embedded cost of Preferred Stock at the last day of the previous month/year times the Preferred Stock Capitalization ratio at the last day of the previous month	(d)	29
4	118	Statement of Retained Earnings Return on Common Equity used in 4th Rev. RS No. 69, Service Schedules MSS-1, MSS-2 and MSS-4, differs from Form 1 amounts because the formula rate calculates Return on Common Equity using a stated Return on Equity of 11.0 percent times the Common Stock Capitalization ratio at December 31 of the previous year	(c)(d)	36
5,6	204, 206	Electric Plant in Service Plant investment used in UPS/DPPT, differs from Form 1 amounts because the formula rate only reflects the cost of the Designated Generating Unit, plus the cost of step-up transformers and associated transmission equipment related to the Designated Generating Unit, at the last day of the previous month	(b),(g)	8-14, 18-24, 27-34, 37-43 and 50
7	204, 206	Electric Plant in Service Plant investment used in UPS/DPPT differs from Form 1 amounts because the formula rate reflects an allocation of Misc. Intangible and General Plant investment at the last day of the previous month using a Labor Ratio	(b)	4, 86-95


8	206	Electric Plant in Service Plant investment used in UPS/DPPT, differs from Form 1 amounts because the formula rate includes a direct assignment of the cost of any coal mining equipment associated with the Designated Generating Unit at the last day of the previous month	(b)	97
9	219	Accumulated Provision for Depreciation APD used in UPS/DPPT, differs from Form 1 amounts because the formula rate only reflects the APD related to the Designated Generating Unit at the last day of the previous month based on wholesale depreciation rates	(b)	1
10	227	Materials and Supplies-Fuel Inventory Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate only reflects the Fuel Inventory related to the Designated Generating Unit at the last day of the previous month	(b)	1-2
11	227	Materials and Supplies Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate only reflects the Materials and Supplies related to the Designated Generating Unit at the last day of the previous month	(c)	12, 16
12	234	Accumulated Deferred Income Taxes (ADIT) (Account 190) Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate either directly assigns any ADIT related to the Designated Generating Unit or allocates ADIT based on a Plant Ratio including applicable adjustments associated with the Amortization of Protected & Unprotected Excess Deferred Income Taxes	(c)	2
13	262	Taxes Accrued, Prepaid and Charged During Year Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate allocates Corporate Franchise Taxes based on a Plant Ratio	(d)	10
14	262	Taxes Accrued, Prepaid and Charged During Year Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate only reflects the ad valorem taxes related to the Designated Generating Unit	(d)	16
15	262	Taxes Accrued, Prepaid and Charged During Year Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rates calculate State and Federal income taxes using the incremental statutory rate	(d)	4, 15
16	262	Taxes Accrued, Prepaid and Charged During Year Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate allocates Payroll Taxes based on a Labor Ratio	(d)	2, 3, 9
17	266	Accumulated Deferred Investment Tax Credits Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate either directly assigns any ITC Amortization related to the Designated Generating Unit or allocates ITC Amortization based on a Plant Ratio	(f)	8


18	275	Accumulated Deferred Income Taxes (Account 282) Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate either directly assigns any ADIT related to the Designated Generating Unit or allocates ADIT based on a Plant Ratio including applicable adjustments associated with the Amortization of Protected & Unprotected Excess Deferred Income Taxes	(k)	2
19	277	Accumulated Deferred Income Taxes (Account 283) Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate either directly assigns any ADIT related to the Designated Generating Unit or allocates ADIT based on a Plant Ratio including applicable adjustments associated with the Amortization of Protected & Unprotected Excess Deferred Income Taxes	(k)	3
20, 21, 22	320-321	Electric Operations and Maintenance Expense Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate only reflects the non-fuel Production O&M Expenses related to the Designated Generating Unit	(b)	4, 6-11, 15-19, 24, 26-32, 35-39, 44-49, 53-57, 62, 64-66 and 69-72
23	321	Electric Operations and Maintenance Expense Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate only reflects the Transmission O&M Expenses related to the step-up transformers and associated transmission equipment related to the Designated Generating Unit	(c)	93, 107
24	323	Electric Operations and Maintenance Expenses Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate allocate A&G costs using a Labor Ratio	(c)	181-184 And 186-193
25	323	Electric Operations and Maintenance Expense Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate only reflects the Insurance Expense related to the Designated Generating Unit	(c)	185
26	336	Depreciation Expense Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate only reflects the monthly Depreciation Expense related to the Designated Generating Unit, plus the Depreciation Expense for the step-up transformers and associated transmission equipment related to the Designated Generating Unit based on Wholesale depreciation rates	(f)	2-7
27	336	Depreciation Expense Costs used in UPS/DPPT, differ from Form 1 amounts because the formula rate only reflects an allocation of the monthly General Plant Depreciation Expense using a Labor Ratio based on Wholesale depreciation rates	(f)	10

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

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

1.None
2. None
3. None
4. None
5. None
6. See Entergy Louisiana’s 2021 FERC Form 1 Notes to Financial Statements, Notes 4, 5, and 8.
7. None
8. Transmission, distribution, utility support, and corporate business services employees are represented by the International Brotherhood of Electrical Workers, AFL-CIO Local Union 2286. The Company and the Union agreed to a contract effective October 18, 2020 through October 18, 2023. Effective October 17, 2021, the wage increase was 2.0%. Fossil operating employees are represented by the International Brotherhood of Electrical Workers, AFL-CIO Local Union 2286. The Company and the Union agreed to a contract effective August 1, 2020 through July 31, 2023. Effective August 8, 2021, the wage increase was 2.0%. Effective April 1, 2021, executive and senior management, middle management, professionals, and non-represented operating, maintenance, and support staff pay increases averaged approximately 3.0%. River Bend Operating, maintenance, engineering, technical, and administrative employees are represented by the International Brotherhood of Electrical Workers, AFL-CIO Local Union 2286. The Company and the Union agreed to a contract effective July 14, 2019 through July 16, 2022. Effective July 11, 2021 the wage increase was 2.25%. Security employees are represented by the International Union, Security, Police and Fire Professionals of America, Local Union 707. The Company and the Union agreed to a contract effective May 1, 2018 through April 30, 2021. The Company and the Union agreed to a new contract effective May 1, 2021 through April 30, 2024. Effective May 1, 2021, the wage increase was 2.5%. Waterford 3 Security employees are represented by the International Union, Security, Police and Fire Professionals of America, Local Union 709. The Company and the Union agreed to a contract effective May 1, 2019 through April 30, 2022. Effective May 1, 2021, the wage increase was 2.5%.
9. See Entergy Louisiana’s 2021 FERC Form 1 Notes to Financial Statements, Notes 2 and 8.
10. None
12. See Entergy Louisiana’s 2021 FERC Form 1 Notes to Financial Statements.
13. See Entergy Louisiana’s 2021 FERC Form 1 pages 104 and 105 for Officer and Director changes that occurred in 2021.
14. Not applicable

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlant Utility Plant (101-106, 114)	200	28,534,201,705	26,071,311,988
3	ConstructionWorkInProgress Construction Work in Progress (107)	200	851,178,196	669,277,201
4	UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3)		29,385,379,901	26,740,589,189
5	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)	200	(a) 9,190,174,494	(c) 9,246,885,390
6	UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5)		20,195,205,407	17,493,703,799
7	NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)	202	53,678,389	27,242,522
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)		(b) 144,520,560	(d) 168,249,152
12	AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)	202	11,218,601	14,636,665
13	NuclearFuelNet Net Nuclear Fuel (Enter Total of lines 7-11 less 12)		209,417,550	210,128,339
14	UtilityPlantAndNuclearFuelNet Net Utility Plant (Enter Total of lines 6 and 13)		20,404,622,957	17,703,832,138
15	OtherElectricPlantAdjustments Utility Plant Adjustments (116)
16	GasStoredUndergroundNoncurrent Gas Stored Underground - Noncurrent (117)
17	OtherPropertyAndInvestmentsAbstract OTHER PROPERTY AND INVESTMENTS
18	NonutilityProperty Nonutility Property (121)		636,235,621	608,866,996
19	AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122)		239,891,786	224,380,572
20	InvestmentInAssociatedCompanies Investments in Associated Companies (123)		1,390,587,308	1,393,142,339
21	InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1)	224	4,922,429	989,345
23	NoncurrentPortionOfAllowances Noncurrent Portion of Allowances	228
24	OtherInvestments Other Investments (124)		13,744,170	13,399,220
25	SinkingFunds Sinking Funds (125)
26	DepreciationFund Depreciation Fund (126)
27	AmortizationFundFederal Amortization Fund - Federal (127)
28	OtherSpecialFunds Other Special Funds (128)		2,115,310,376	1,795,037,292
29	SpecialFunds Special Funds (Non Major Only) (129)
30	DerivativeInstrumentAssetsLongTerm Long-Term Portion of Derivative Assets (175)
31	DerivativeInstrumentAssetsHedgesLongTerm Long-Term Portion of Derivative Assets - Hedges (176)
32	OtherPropertyAndInvestments TOTAL Other Property and Investments (Lines 18-21 and 23-31)		3,911,063,260	3,587,054,620
33	CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS
34	CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130)
35	Cash Cash (131)		75,334	1,120,536
36	SpecialDeposits Special Deposits (132-134)			4,141,784
37	WorkingFunds Working Fund (135)
38	TemporaryCashInvestments Temporary Cash Investments (136)		17,104,563	725,407,214
39	NotesReceivable Notes Receivable (141)
40	CustomerAccountsReceivable Customer Accounts Receivable (142)		355,264,604	315,484,939
41	OtherAccountsReceivable Other Accounts Receivable (143)		39,187,558	44,127,453
42	AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144)		29,230,533	45,692,807
43	NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145)
44	AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146)		98,796,281	83,819,022
45	FuelStock Fuel Stock (151)	227	42,930,214	50,409,320
46	FuelStockExpensesUndistributed Fuel Stock Expenses Undistributed (152)	227	19	181,734
47	Residuals Residuals (Elec) and Extracted Products (153)	227
48	PlantMaterialsAndOperatingSupplies Plant Materials and Operating Supplies (154)	227	438,894,803	398,855,687
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	27,427	89,304
53	NoncurrentPortionOfAllowances (Less) Noncurrent Portion of Allowances	228
54	StoresExpenseUndistributed Stores Expense Undistributed (163)	227	46,430,420	39,077,556
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)		40,713,089	29,495,559
58	AdvancesForGas Advances for Gas (166-167)
59	InterestAndDividendsReceivable Interest and Dividends Receivable (171)		5,673,934	5,685,017
60	RentsReceivable Rents Receivable (172)
61	AccruedUtilityRevenues Accrued Utility Revenues (173)		174,768,391	178,840,254
62	MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174)		39,714,677	48,562,726
63	DerivativeInstrumentAssets Derivative Instrument Assets (175)		11,591,503	5,637,702
64	DerivativeInstrumentAssetsLongTerm (Less) Long-Term Portion of Derivative Instrument Assets (175)
65	DerivativeInstrumentAssetsHedges Derivative Instrument Assets - Hedges (176)
66	DerivativeInstrumentAssetsHedgesLongTerm (Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67	CurrentAndAccruedAssets Total Current and Accrued Assets (Lines 34 through 66)		1,281,942,284	1,885,243,000
68	DeferredDebitsAbstract DEFERRED DEBITS
69	UnamortizedDebtExpense Unamortized Debt Expenses (181)		68,867,669	60,635,131
70	ExtraordinaryPropertyLosses Extraordinary Property Losses (182.1)	230a
71	UnrecoveredPlantAndRegulatoryStudyCosts Unrecovered Plant and Regulatory Study Costs (182.2)	230b	93,902,411	98,956,366
72	OtherRegulatoryAssets Other Regulatory Assets (182.3)	232	2,996,755,026	1,456,065,086
73	PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183)		1,403,414	683,247
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)		17,413	32,966
77	TemporaryFacilities Temporary Facilities (185)
78	MiscellaneousDeferredDebits Miscellaneous Deferred Debits (186)	233	6,301,032	6,486,455
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)		26,926,669	26,629,271
82	AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190)	234	2,495,474,613	1,779,382,782
83	UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191)
84	DeferredDebits Total Deferred Debits (lines 69 through 83)		5,689,648,247	3,428,871,304
85	AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84)		31,287,276,748	26,605,001,062

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility

Includes a debit balance for removal costs of $848,242,785.

(b) Concept: NuclearFuelUnderCapitalLeases

FUEL LEASE FOR WATERFORD AND RIVER BEND

LESSOR: RIVER BEND FUEL SERVICES INC. AND RIVER FUEL COMPANY #2

Investment of River Bend Fuel Services, Inc. & River Fuel Company #2 Lease at December 31, 2021


Investment at December 31,2020			$168,249,152

Additional investment in fuel			69,647,496

Daily lease charges allocated to and included in capitalized costs			305,671

Less: Burn-up charges paid to lessor			93,681,759

Total Investment at December 31, 2021			$144,520,560


Costs Incurred under River Bend Fuel Services Inc. and River Fuel Company #2 Lease for the Year Ended December 31, 2021
Daily Lease Charges			$5,549,768

(c) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility

Includes a debit balance for removal costs of $302,611,823.

(d) Concept: NuclearFuelUnderCapitalLeases

As of December 31, 2021, arrangements to lease nuclear fuel existed in an aggregate amount up to $300 million for Entergy Louisiana, LLC. The lessors finance the acquisition and ownership of nuclear fuel through loans made under revolving credit agreements, the issuance of commercial paper, and the issuance of intermediate-term notes. The credit agreement for Entergy Louisiana has a termination date of June 10, 2024. The termination dates may be extended from time to time with the consent of the lenders. The intermediate-term notes issued pursuant to these fuel lease arrangements have varying maturities through June 15, 2027. It is expected that additional financing under the leases will be arranged as needed to acquire additional fuel, to pay interest, and to pay maturing debt. However, if such additional financing cannot be arranged, the lessee in each case must repurchase sufficient nuclear fuel to allow the lessor to meet its obligations in accordance with the fuel lease.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	ProprietaryCapitalAbstract PROPRIETARY CAPITAL
2	CommonStockIssued Common Stock Issued (201)	250
3	PreferredStockIssued Preferred Stock Issued (204)	250
4	CapitalStockSubscribed Capital Stock Subscribed (202, 205)
5	StockLiabilityForConversion Stock Liability for Conversion (203, 206)
6	PremiumOnCapitalStock Premium on Capital Stock (207)
7	OtherPaidInCapital Other Paid-In Capital (208-211)	253	3,063,204,555	2,938,204,555
8	InstallmentsReceivedOnCapitalStock Installments Received on Capital Stock (212)	252
9	DiscountOnCapitalStock (Less) Discount on Capital Stock (213)	254
10	CapitalStockExpense (Less) Capital Stock Expense (214)	254b
11	RetainedEarnings Retained Earnings (215, 215.1, 216)	118	5,131,241,528	4,547,397,427
12	UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1)	118	22,452,931	32,593,037
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)	8,278,216	4,327,348
16	ProprietaryCapital Total Proprietary Capital (lines 2 through 15)		8,180,271,368	7,457,336,293
17	LongTermDebtAbstract LONG-TERM DEBT
18	Bonds Bonds (221)	256	10,490,000,000	8,690,000,000
19	ReacquiredBonds (Less) Reaquired Bonds (222)	256
20	AdvancesFromAssociatedCompanies Advances from Associated Companies (223)	256		1,001,812
21	OtherLongTermDebt Other Long-Term Debt (224)	256	327,234,006	202,265,044
22	UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225)		14,864,329	15,380,196
23	UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226)		22,387,199	18,235,531
24	LongTermDebt Total Long-Term Debt (lines 18 through 23)		10,809,711,136	8,890,411,521
25	OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES
26	ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227)		101,813,873	91,063,573
27	AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1)
28	AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2)		19,067,825	20,559,965
29	AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3)		251,660,865	253,991,179
30	AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4)		4,446,168	3,375,725
31	AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229)			43,380,168
32	LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities
33	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges
34	AssetRetirementObligations Asset Retirement Obligations (230)		1,653,197,992	1,573,307,379
35	OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34)		2,030,186,723	1,985,677,989
36	CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES
37	NotesPayable Notes Payable (231)
38	AccountsPayable Accounts Payable (232)		1,481,901,713	1,449,795,345
39	NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233)
40	AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234)		210,896,891	123,938,282
41	CustomerDeposits Customer Deposits (235)		150,696,808	152,612,245
42	TaxesAccrued Taxes Accrued (236)	262	300,894,297	270,345,219
43	InterestAccrued Interest Accrued (237)		96,619,676	94,913,128
44	DividendsDeclared Dividends Declared (238)
45	MaturedLongTermDebt Matured Long-Term Debt (239)
46	MaturedInterest Matured Interest (240)
47	TaxCollectionsPayable Tax Collections Payable (241)		4,477,726	3,486,847
48	MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242)		34,503,549	30,729,491
49	ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243)		108,141,868	135,915,702
50	DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244)			1,642,626
51	LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities
52	DerivativeInstrumentLiabilitiesHedges Derivative Instrument Liabilities - Hedges (245)
53	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges (Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54	CurrentAndAccruedLiabilities Total Current and Accrued Liabilities (lines 37 through 53)		2,388,132,528	2,263,378,885
55	DeferredCreditsAbstract DEFERRED CREDITS
56	CustomerAdvancesForConstruction Customer Advances for Construction (252)		17,017,924	14,255,367
57	AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255)	266	102,588,033	107,317,339
58	DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256)
59	OtherDeferredCredits Other Deferred Credits (253)	269	699,972,623	793,584,313
60	OtherRegulatoryLiabilities Other Regulatory Liabilities (254)	278	2,374,030,941	1,403,349,543
61	UnamortizedGainOnReacquiredDebt Unamortized Gain on Reaquired Debt (257)
62	AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty Accum. Deferred Income Taxes-Accel. Amort.(281)	272	1,179,297	1,193,225
63	AccumulatedDeferredIncomeTaxesOtherProperty Accum. Deferred Income Taxes-Other Property (282)		3,648,970,108	3,062,292,140
64	AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283)		1,035,216,067	626,204,447
65	DeferredCredits Total Deferred Credits (lines 56 through 64)		7,878,974,993	6,008,196,374
66	LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)		31,287,276,748	26,605,001,062

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

STATEMENT OF INCOME
Quarterly Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter. If additional columns are needed, place them in a footnote. Annual or Quarterly if applicable Do not report fourth quarter data in columns (e) and (f) Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above. Use page 122 for important notes regarding the statement of income for any account thereof. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.	Title of Account (a)	(Ref.) Page No. (b)	Total Current Year to Date Balance for Quarter/Year (c)	Total Prior Year to Date Balance for Quarter/Year (d)	Current 3 Months Ended - Quarterly Only - No 4th Quarter (e)	Prior 3 Months Ended - Quarterly Only - No 4th Quarter (f)	Electric Utility Current Year to Date (in dollars) (g)	Electric Utility Previous Year to Date (in dollars) (h)	Gas Utiity Current Year to Date (in dollars) (i)	Gas Utility Previous Year to Date (in dollars) (j)	Other Utility Current Year to Date (in dollars) (k)	Other Utility Previous Year to Date (in dollars) (l)
1	UtilityOperatingIncomeAbstract UTILITY OPERATING INCOME
2	OperatingRevenues Operating Revenues (400)	300	5,056,733,116	4,046,097,663			4,982,744,421	3,995,298,536	73,988,695	50,799,127
3	OperatingExpensesAbstract Operating Expenses
4	OperationExpense Operation Expenses (401)	320	2,902,283,398	2,082,043,884			2,854,902,642	2,049,762,801	47,380,756	32,281,083
5	MaintenanceExpense Maintenance Expenses (402)	320	297,352,736	275,439,019			295,271,244	273,514,704	2,081,492	1,924,315
6	DepreciationExpense Depreciation Expense (403)	336	574,953,945	537,313,284			566,334,547	529,511,200	8,619,398	7,802,084
7	DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1)	336	13,286,493	13,286,490			13,286,493	13,286,490
8	AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405)	336	62,215,210	53,072,897			60,780,107	52,176,285	1,435,103	896,612
9	AmortizationOfElectricPlantAcquisitionAdjustments Amort. of Utility Plant Acq. Adj. (406)	336	4,416,726	4,416,726			4,416,726	4,416,726
10	AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)		5,053,955	5,053,955			5,010,204	5,010,204	43,751	43,751
11	AmortizationOfConversionExpenses Amort. of Conversion Expenses (407.2)
12	RegulatoryDebits Regulatory Debits (407.3)		121,052,849	100,155,874			120,668,178	99,759,928	384,671	395,946
13	RegulatoryCredits (Less) Regulatory Credits (407.4)		97,296,295	126,406,903			96,547,692	125,856,747	748,603	550,156
14	TaxesOtherThanIncomeTaxesUtilityOperatingIncome Taxes Other Than Income Taxes (408.1)	262	224,078,993	208,901,838			218,244,321	203,555,602	5,834,672	5,346,236
15	IncomeTaxesOperatingIncome Income Taxes - Federal (409.1)	262	37,051,292	447,750,389			35,883,539	447,375,658	1,167,753	374,731
16	IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1)	262	19,568,726	21,609,607			20,025,949	21,481,162	457,223	128,445
17	ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1)	234, 272	3,906,049,913	2,884,855,490			3,896,652,835	2,879,573,730	9,397,078	5,281,760
18	ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1)	234, 272	3,773,495,443	2,779,010,505			3,767,183,670	2,771,986,688	6,311,773	7,023,817
19	InvestmentTaxCreditAdjustments Investment Tax Credit Adj. - Net (411.4)	266	4,399,498	4,478,081			4,398,418	4,476,930	1,080	1,151
20	GainsFromDispositionOfPlant (Less) Gains from Disp. of Utility Plant (411.6)
21	LossesFromDispositionOfServiceCompanyPlant Losses from Disp. of Utility Plant (411.7)			1,422,093				1,422,093
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)		68,575,393	65,224,610			68,575,393	65,224,610
25	UtilityOperatingExpenses TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)		4,286,645,809	2,851,930,675			4,220,155,320	2,806,037,188	66,490,489	45,893,487
27	NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25)		770,087,307	1,194,166,988			762,589,101	1,189,261,348	7,498,206	4,905,640
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)		4,385,450	4,538,514
34	ExpensesOfNonutilityOperations (Less) Expenses of Nonutility Operations (417.1)		19,225,908	17,426,237
35	NonoperatingRentalIncome Nonoperating Rental Income (418)
36	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1)	119	10,136,608	213,492
37	InterestAndDividendIncome Interest and Dividend Income (419)		297,808,234	233,083,814
38	AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1)		28,647,926	38,150,658
39	MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421)		67,948,624	60,440,776
40	GainOnDispositionOfProperty Gain on Disposition of Property (421.1)		65,953	1,078,688
41	OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40)		253,869,639	198,771,169
42	OtherIncomeDeductionsAbstract Other Income Deductions
43	LossOnDispositionOfProperty Loss on Disposition of Property (421.2)		374,677	126,245
44	MiscellaneousAmortization Miscellaneous Amortization (425)
45	Donations Donations (426.1)		4,323,263	3,743,985
46	LifeInsurance Life Insurance (426.2)		342,908	290,741
47	Penalties Penalties (426.3)		289,414	420,240
48	ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4)		4,367,182	3,446,762
49	OtherDeductions Other Deductions (426.5)		2,272,243	2,370,176
50	OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49)		11,283,871	5,076,315
51	TaxesApplicableToOtherIncomeAndDeductionsAbstract Taxes Applic. to Other Income and Deductions
52	TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions Taxes Other Than Income Taxes (408.2)	262	16,388,000	8,267,900
53	IncomeTaxesFederal Income Taxes-Federal (409.2)	262	3,758,651	2,890,534
54	IncomeTaxesOther Income Taxes-Other (409.2)	262	2,222,651	74,406
55	ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2)	234, 272	515,628	515,628
56	ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions (Less) Provision for Deferred Income Taxes-Cr. (411.2)	234, 272	667,128	667,128
57	InvestmentTaxCreditAdjustmentsNonutilityOperations Investment Tax Credit Adj.-Net (411.5)		383,090	383,529
58	InvestmentTaxCredits (Less) Investment Tax Credits (420)
59	TaxesOnOtherIncomeAndDeductions TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)		21,834,712	4,916,743
60	NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59)		220,751,056	188,778,111
61	InterestChargesAbstract Interest Charges
62	InterestOnLongTermDebt Interest on Long-Term Debt (427)		326,014,598	307,392,984
63	AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428)		9,063,428	6,380,517
64	AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1)		2,248,658	1,968,267
65	AmortizationOfPremiumOnDebtCredit (Less) Amort. of Premium on Debt-Credit (429)		515,866	117,804
66	AmortizationOfGainOnReacquiredDebtCredit (Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67	InterestOnDebtToAssociatedCompanies Interest on Debt to Assoc. Companies (430)		3,209	162,305
68	OtherInterestExpense Other Interest Expense (431)		12,917,793	3,954,068
69	AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)		12,877,664	19,147,045
70	NetInterestCharges Net Interest Charges (Total of lines 62 thru 69)		336,854,156	300,593,292
71	IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70)		653,984,207	1,082,351,807
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	0
77	ExtraordinaryItemsAfterTaxes Extraordinary Items After Taxes (line 75 less line 76)
78	NetIncomeLoss Net Income (Total of line 71 and 77)		653,984,207	1,082,351,807

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

STATEMENT OF RETAINED EARNINGS
Do not report Lines 49-53 on the quarterly report. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b). State the purpose and amount for each reservation or appropriation of retained earnings. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order. Show dividends for each class and series of capital stock. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No.	Item (a)	Contra Primary Account Affected (b)	Current Quarter/Year Year to Date Balance (c)	Previous Quarter/Year Year to Date Balance (d)
	UnappropriatedRetainedEarningsAbstract UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1	UnappropriatedRetainedEarnings Balance-Beginning of Period		4,547,397,427	3,486,325,671
2	ChangesAbstract Changes
3	AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439)
4	AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit
9	AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439)
10	AdjustmentsToRetainedEarningsDebitAbstract Adjustments to Retained Earnings Debit
15	AdjustmentsToRetainedEarningsDebit TOTAL Debits to Retained Earnings (Acct. 439)
16	BalanceTransferredFromIncome Balance Transferred from Income (Account 433 less Account 418.1)		643,847,599	1,082,565,299
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 Distributions declared on common equity	131	60,000,000	21,500,000
36	DividendsDeclaredCommonStock TOTAL Dividends Declared-Common Stock (Acct. 438)		60,000,000	21,500,000
37	TransfersFromUnappropriatedUndistributedSubsidiaryEarnings Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings	123, 131	3,498	6,457
38	UnappropriatedRetainedEarnings Balance - End of Period (Total 1,9,15,16,22,29,36,37)		5,131,241,528	4,547,397,427
39	AppropriatedRetainedEarningsAbstract APPROPRIATED RETAINED EARNINGS (Account 215)
45	AppropriatedRetainedEarnings TOTAL Appropriated Retained Earnings (Account 215)
	AppropriatedRetainedEarningsAmortizationReserveFederalAbstract APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46	AppropriatedRetainedEarningsAmortizationReserveFederal TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)
47	AppropriatedRetainedEarningsIncludingReserveAmortization TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)
48	RetainedEarnings TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)		5,131,241,528	4,547,397,427
	UnappropriatedUndistributedSubsidiaryEarningsAbstract UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49	UnappropriatedUndistributedSubsidiaryEarnings Balance-Beginning of Year (Debit or Credit)		32,593,037	32,373,088
50	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings for Year (Credit) (Account 418.1)		10,136,608	213,492
51	DividendsReceived (Less) Dividends Received (Debit)		3,498	6,457
52	ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
53	UnappropriatedUndistributedSubsidiaryEarnings Balance-End of Year (Total lines 49 thru 52)		22,452,931	32,593,037

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

STATEMENT OF CASH FLOWS
Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.	Description (See Instructions No.1 for explanation of codes) (a)	Current Year to Date Quarter/Year (b)	Previous Year to Date Quarter/Year (c)
1	NetCashFlowFromOperatingActivitiesAbstract Net Cash Flow from Operating Activities
2	NetIncomeLoss Net Income (Line 78(c) on page 117)	653,984,207	1,082,351,807
3	NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income:
4	DepreciationAndDepletion Depreciation and Depletion	728,501,722	678,367,962
5	NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details)
5.1	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Amortization of debt discount and expense and premium on debt and amortization of loss on reacquired debt	11,312,086	8,348,784
8	DeferredIncomeTaxesNet Deferred Income Taxes (Net)	132,402,970	105,693,485
9	InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net)	4,782,588	4,861,610
10	NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables	69,786,233	83,667,020
11	NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory	39,731,159	93,059,207
12	NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory	61,877	78,169
13	NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses	151,320,603	645,723,386
14	NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets	1,540,689,940	125,919,514
15	NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities	970,681,398	10,053,343
16	AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction	28,647,926	38,150,658
17	UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies
18	OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote):
18.1	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other working capital	2,963,541	3,534,088
18.2	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other	15,260,251	1,254,002,531
22	NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)	976,923,727	934,490,484
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)	3,621,716,527	1,960,787,542
27	GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel	85,419,175	92,830,526
28	GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant
29	GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant
30	AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction	28,647,926	38,150,658
31	OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote):
31.1	OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Payment for purchase of assets		236,998,734
31.2	OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Decommissioning trust funds	60,184,597	25,205,842
31.3	OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Proceeds from sale of nuclear fuel	63,683,888	99,357,952
34	CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33)	3,674,988,485	2,178,314,034
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	16,035,880
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 Litigation proceeds for reimbursement of spent nuclear fuel storage costs	8,691,444	5,089,751
53.2	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Payments to storm reserve escrow account		1,487,927
53.3	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Receipts from storm reserve escrow account		297,363,015
53.4	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Changes in money pool receivables - net	1,112,651	13,426,098
57	CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)	3,651,373,812	1,890,775,293
59	CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities:
60	ProceedsFromIssuanceAbstract Proceeds from Issuance of:
61	ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b)	2,174,665,778	2,347,682,756
62	ProceedsFromIssuanceOfPreferredStockFinancingActivities Preferred Stock
63	ProceedsFromIssuanceOfCommonStockFinancingActivities Common Stock
64	OtherAdjustmentsToCashFlowsFromFinancingActivities Other (provide details in footnote):
64.1	OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription Other (provide details in footnote):
64.2	OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription Capital contribution from parent	125,000,000
66	NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c)
67	OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote):
67.1	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Changes in credit borrowing - net	125,000,000
70	CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69)	2,424,665,778	2,347,682,756
72	PaymentsForRetirementAbstract Payments for Retirement of:
73	PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b)	398,711,038	550,029,675
74	PaymentsForRetirementOfPreferredStockFinancingActivities Preferred Stock
75	PaymentsForRetirementOfCommonStockFinancingActivities Common Stock
76	OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities Other (provide details in footnote):
76.1	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Other	852,508	10,569,562
76.2	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Change in money pool payable - net		82,825,688
76.3	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Dividends on common equity	60,000,000	21,500,000
78	NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c)
80	DividendsOnPreferredStock Dividends on Preferred Stock
81	DividendsOnCommonStock Dividends on Common Stock
83	CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)	1,965,102,232	1,682,757,831
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)	709,347,853	726,473,022
88	CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period	726,527,750	54,728
90	CashAndCashEquivalents Cash and Cash Equivalents at End of Period	17,179,897	726,527,750

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

NOTES TO FINANCIAL STATEMENTS

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

A. CASH FLOW STATEMENT, ADDITIONAL INFORMATION:

Cash and Cash Equivalents at December 31, 2021

Cash (Account 131) $75,334

Temporary Cash Investments (Account 136) 17,104,563

Total Cash and Cash Equivalents $17,179,897

==========

SUPPLEMENTAL DISCLOSURE OF CASH FLOW STATEMENT (in 000s)

Cash paid (received) during the period for:

Interest – net of amt capitalized $336,929

Income Taxes ($18,453)

B. FERC FORM 1 PRESENTATION COMPARED TO GENERALLY ACCEPTED ACCOUNTING PRINCIPLES

The accompanying financial statements have been prepared in accordance with the accounting requirements of the FERC as set forth in the Uniform System of Accounts and accounting releases, which differs from GAAP. Additional comparative data, including the 2020 data for the statement of retained earnings and cash flows, are needed to present the financial position and results of operations in order to satisfy GAAP. In addition, GAAP requires the disclosure of the current and long-term portion of assets and liabilities. In accordance with FERC reporting requirements, the aforementioned disclosures were not included in these financial statements.

As required by the FERC, Entergy Louisiana, LLC classifies certain items in the income statement (primarily the classification of operating expenses and other deductions) and in the balance sheet (primarily the classification of the components of accumulated deferred income taxes, taxes accrued, certain other miscellaneous current and accrued liabilities, maturities of long-term debt, deferred debits, deferred credits, plant in service, and accumulated depreciation) in a manner different than that required by GAAP.

GAAP requires Entergy Louisiana to consolidate the company from which it leases nuclear fuel, whereas this company is not consolidated for the FERC Form 1 presentation. The significant difference that results from this is the elimination from the GAAP balance sheet of the obligations under capital leases with the nuclear fuel companies and the addition to the GAAP balance sheet of the nuclear fuel companies’ credit facility borrowings, commercial paper, and notes payable.

Finally, GAAP requires that Entergy Louisiana consolidate its majority owned subsidiary, Entergy Louisiana Investment Recovery Funding I, L.L.C., whereas the investment in the company is presented in the Form 1 using the equity method. The significant difference that results from this is the inclusion on Entergy Louisiana’s GAAP-basis balance sheet of an investment recovery property regulatory asset that is the property of and investment recovery bonds that are the obligations of the subsidiary.

C. The Notes to the Financial Statements included herein are adapted from the Entergy Corporation and subsidiaries Form 10-K for the Year Ended December 31, 2021. The Form 10-K Notes to the Financial Statements are prepared in conformity with GAAP, and thus may differ in certain instances from the financial statements contained herein.

"Entergy" when used in these Notes means Entergy Corporation and its direct and indirect subsidiaries.

"Registrant Subsidiaries" when used in these Notes means Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc.

"Utility" when used in the Notes means Entergy's business segment that generates, transmits, distributes, and sells electric power, with a small amount of natural gas distribution.

"Utility operating companies" when used in these Notes means Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas.

NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Use of Estimates in the Preparation of Financial Statements

In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used.

Property, Plant, and Equipment

Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens.

Details of property, plant, and equipment by functional category are presented on FERC Form 1 pages 204-207 and details of accumulated depreciation by functional category are presented on FERC Form 1 page 219.

Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
2021	2.7%	2.4%	3.6%	3.2%	3.2%	1.9%
2020	2.6%	2.4%	3.5%	3.1%	3.1%	2.1%
2019	2.5%	2.4%	3.2%	3.2%	3.0%	2.1%

As of December 31, 2021, construction expenditures included in accounts payable are $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy. As of December 31, 2020, construction expenditures included in accounts payable are $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 million for System Energy.

Jointly-Owned Generating Stations

Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows:


Generating Stations		Fuel Type	Total Megawatt Capability (a)	Ownership	Investment	Accumulated Depreciation
					(In Millions)
Utility business:
Entergy Arkansas -
Independence	Unit 1	Coal	822	31.50%	$143	$106
Independence	Common Facilities	Coal		15.75%	$43	$31
White Bluff	Units 1 and 2	Coal	1,639	57.00%	$587	$390
Ouachita (b)	Common Facilities	Gas		66.67%	$173	$156
Union (c)	Common Facilities	Gas		25.00	$29	$9
Entergy Louisiana -
Roy S. Nelson	Unit 6	Coal	521	40.25%	$294	$212
Roy S. Nelson	Unit 6 Common Facilities	Coal		19.57%	$21	$10
Big Cajun 2	Unit 3	Coal	540	24.15%	$151	$131
Big Cajun 2	Unit 3 Common Facilities	Coal		8.05%	$5	$3
Ouachita (b)	Common Facilities	Gas		33.33%	$91	$78
Acadia	Common Facilities	Gas		50.00%	$21	$2
Union (c)	Common Facilities	Gas		50.00	$59	$10
Entergy Mississippi -
Independence	Units 1 and 2 and Common Facilities	Coal	1,246	25.00%	$286	$179
Entergy New Orleans -
Union (c)	Common Facilities	Gas		25.00	$29	$8
Entergy Texas -
Roy S. Nelson	Unit 6	Coal	521	29.75%	$208	$120
Roy S. Nelson	Unit 6 Common Facilities	Coal		14.47%	$7	$3
Big Cajun 2	Unit 3	Coal	540	17.85%	$113	$84


Big Cajun 2	Unit 3 Common Facilities	Coal		5.95%	$4	$1
Montgomery County	Unit 1	Gas	909	92.44%	$728	$18
System Energy -
Grand Gulf (d)	Unit 1	Nuclear	1,404	90.00	$5,363	$3,317

a.“Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.

b.Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units.

c.Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units.

d.Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.

Nuclear Refueling Outage Costs

Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line.

Allowance for Funds Used During Construction (AFUDC)

AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers.

Income Taxes

Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward.

Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “Other Tax Matters - Tax Cuts and Jobs Act” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017.

The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment.

Accounting for the Effects of Regulation

Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet.

An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets.

Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders.

Regulatory Asset or Liability for Income Taxes

Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements.

Cash and Cash Equivalents

Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents.

Allowance for Doubtful Accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements.

Investments

Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. The assessment of whether an investment in an available-for-sale debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Effective January 1, 2020, with the adoption of ASU 2016-13, Entergy estimates the expected credit losses for its available for sale securities based on the current credit rating and remaining life of the securities. To the extent an expected credit loss is realized, the individual security comprising the loss is written off against this allowance. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds.

Equity Method Investments

Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support.

Derivative Financial Instruments and Commodity Derivatives

The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries.

Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered.

For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis.

Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of

the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value.

Impairment of Long-lived Assets

Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets.

River Bend AFUDC

The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025.

Reacquired Debt

The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment.

Taxes Imposed on Revenue-Producing Transactions

Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.

NOTE 2. RATE AND REGULATORY MATTERS

Regulatory Assets and Regulatory Liabilities

Regulatory assets represent probable future revenues associated with costs that Entergy expects to recover from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory liabilities represent probable future reductions in revenues associated with amounts that Entergy expects to benefit customers through the regulatory ratemaking process under which the Utility business operates. Details of regulatory assets in FERC account 182.3 are presented on FERC Form 1 page 232. Details of regulatory liabilities in FERC account 254 are presented on FERC Form 1 page 278.

Hurricane Ida

In August 2021, Hurricane Ida caused extensive damage to the Entergy distribution and, to a lesser extent, transmission systems across Louisiana resulting in widespread power outages. Total restoration costs

for the repair and/or replacement of the electrical system damaged by Hurricane Ida for Entergy Louisiana and Entergy New Orleans are currently estimated to be approximately $2.7 billion. Also, Utility revenues in 2021 were adversely affected by extended power outages resulting from the hurricane.

Entergy has recorded accounts payable for the estimated costs incurred that were necessary to return customers to service. Entergy recorded the regulatory assets in accordance with its accounting policies and based on the historic treatment of such costs in its service area because management believes that recovery through some form of regulatory mechanism is probable. There are well-established mechanisms and precedent for addressing these catastrophic events and providing for recovery of prudently incurred storm costs in accordance with applicable regulatory and legal principles. Because Entergy has not gone through the regulatory process regarding these storm costs, there is an element of risk, and Entergy is unable to predict with certainty the degree of success it may have in its recovery initiatives, the amount of restoration costs that it may ultimately recover, or the timing of such recovery.

Entergy is considering all available avenues to recover storm-related costs from Hurricane Ida, including federal government assistance and securitization financing. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, as discussed below in “Storm Cost Filings with Retail Regulators - Entergy Louisiana - Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida,” Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review. In September 2021, Entergy New Orleans withdrew $39 million from its funded storm reserves. Storm cost recovery or financing will be subject to review by applicable regulatory authorities. In February 2022, Entergy New Orleans filed with the City Council a securitization application requesting that the City Council review Entergy New Orleans’s storm reserve and increase the storm reserve funding level to $150 million, to be funded through securitization.

Regulatory activity regarding the Tax Cuts and Jobs Act

See the “Other Tax Matters - Tax Cuts and Jobs Act” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes.

Entergy Louisiana

In an electric formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the

analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing which, as discussed below, Entergy Louisiana filed in June 2018.

Fuel and purchased power cost recovery

The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review.


	2021	2020
	(In Millions)
Entergy Arkansas (a)	$177.6	$15.2
Entergy Louisiana (b)	$213.5	$170.4
Entergy Mississippi	$121.9	($14.7)
Entergy New Orleans (b)	($3.5)	$6.2
Entergy Texas	$48.3	($85.4)

a.Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.

b.Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.

Entergy Louisiana

Entergy Louisiana recovers electric fuel and purchased power costs for the billing month based upon the level of such costs incurred two months prior to the billing month. Entergy Louisiana’s purchased gas adjustments include estimates for the billing month adjusted by a surcharge or credit that arises from an annual reconciliation of fuel costs incurred with fuel cost revenues billed to customers, including carrying charges.

In July 2014 the LPSC authorized its staff to initiate an audit of the fuel adjustment clause filings by Entergy Gulf States Louisiana, whose business was combined with Entergy Louisiana in 2015. The audit includes a review of the reasonableness of charges flowed through Entergy Gulf States Louisiana’s fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $900,000, plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require no refund to customers.

In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million, plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.3 million, plus interest, as compared to the LPSC staff’s recommendation of $7.3 million, plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs.

In November 2019 the pending LPSC proceedings for the 2010-2013 Entergy Louisiana and Entergy Gulf States Louisiana audits were consolidated to facilitate a settlement of both fuel audits. In December 2019 an unopposed settlement was reached that requires a refund to legacy Entergy Louisiana customers of approximately $2.3 million, including interest, and no refund to legacy Entergy Gulf States Louisiana customers. The LPSC approved the settlement in January 2020. A one-time refund was made in February 2020.

In March 2020 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2016 through 2019. In September 2021 the LPSC submitted its audit report and found that all costs recovered through the fuel adjustment clause were reasonable and eligible for recovery through the fuel adjustment clause. Intervenors are conducting discovery regarding the LPSC staff’s report.

In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over five months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. The final amount of incremental fuel costs is subject to change through the resettlement process. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC-jurisdictional utilities. At its June 2021 meeting, the LPSC approved the hiring of consultants to assist its staff in this review. Discovery is ongoing.

In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. Discovery is ongoing, and no audit report has been filed.

Retail Rate Proceedings

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2017 Formula Rate Plan Filing

In June 2018, Entergy Louisiana filed its formula rate plan evaluation report for its 2017 calendar year operations. The 2017 test year evaluation report produced an earned return on equity of 8.16%, due in large part to revenue-neutral realignments to other recovery mechanisms. Without these realignments, the evaluation report produces an earned return on equity of 9.88% and a resulting base rider formula rate plan revenue increase of $4.8 million. Excluding the Tax Cuts and Jobs Act credits provided for by the tax reform adjustment mechanisms, total formula rate plan revenues were further increased by a total of $98 million as a result of the evaluation report due to adjustments to the additional capacity and MISO cost recovery mechanisms of the formula rate plan, and implementation of the transmission recovery mechanism. In August 2018, Entergy Louisiana filed a supplemental formula rate plan evaluation report to reflect changes from the 2016 test year formula rate plan proceedings, a decrease to the transmission recovery mechanism to reflect lower actual capital additions, and a decrease to evaluation period expenses to reflect the terms of a new power sales agreement. Based on the August 2018 update, Entergy Louisiana recognized a total decrease in formula rate plan revenue of approximately $17.6 million. Results of the updated 2017 evaluation report filing were implemented with the September 2018 billing month subject to refund and review by the LPSC staff and intervenors. In accordance with the terms of the formula rate plan, in September 2018 the LPSC staff and intervenors submitted their responses to Entergy Louisiana’s original formula rate plan evaluation report and supplemental compliance updates. The LPSC staff asserted objections/reservations regarding (1) Entergy Louisiana’s proposed rate adjustments associated with the return of excess accumulated deferred income taxes pursuant to the Tax Cuts and Jobs Act and the treatment of accumulated deferred income taxes related to reductions of rate base; (2) Entergy Louisiana’s reservation regarding treatment of a regulatory asset related to certain special orders by the LPSC; and (3) test year expenses billed from Entergy Services to Entergy Louisiana. Intervenors also objected to Entergy Louisiana’s treatment of the regulatory asset related to certain special orders by the LPSC. In August 2021 the LPSC staff issued a letter updating its objections/reservations for the 2017 test year formula rate plan evaluation report. In its letter, the LPSC staff reiterated its original objections/reservations pertaining to Entergy Louisiana’s proposed rate adjustments associated with the return of excess accumulated deferred income taxes pursuant to the Tax Cuts and Jobs Act and the treatment of accumulated deferred income taxes related to reductions of rate base, specifically how the accumulated deferred income taxes associated with uncertain tax positions have been accounted for, and test year expenses billed from Entergy Services to Entergy Louisiana. The LPSC staff further reserved its rights for future proceedings and to dispute future proposed adjustments to the 2017 test year formula rate plan evaluation report. The LPSC staff withdrew all other objections/reservations. A procedural schedule has not yet been established to resolve these issues.

Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes.

Commercial operation at J. Wayne Leonard Power Station (formerly St. Charles Power Station) commenced in May 2019. In May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. In June 2020, Entergy Louisiana submitted information to the LPSC to review the prudence of Entergy Louisiana’s management of the project. In August 2020 discovery commenced and a procedural schedule was established with a hearing in July 2021. In February 2021 the LPSC staff filed

testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. The LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. In July 2021 the LPSC approved a settlement between the LPSC staff and Entergy Louisiana finding that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers.

2018 Formula Rate Plan Filing

In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million. While base rider formula rate plan revenue will decrease as a result of this filing, overall formula rate plan revenues will increase by approximately $118.7 million. This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund.

Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing.

Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana responded to all such requests. In August 2021 the LPSC staff issued a letter updating its objections/reservations for the 2018 test year formula rate plan evaluation report. In its letter, the LPSC staff reiterated its original objection/reservation pertaining to test year expenses billed from Entergy Services to Entergy Louisiana and outstanding issues from the 2017 test year formula rate plan evaluation report. The LPSC staff withdrew all other objections/reservations.

Commercial operation at Lake Charles Power Station commenced in March 2020. In March 2020, Entergy Louisiana filed an update to its 2018 formula rate plan evaluation report to include the estimated first-year revenue requirement of $108 million associated with the Lake Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of April 2020.

In an effort to narrow the remaining issues in formula rate plan test years 2017 and 2018, Entergy Louisiana provided notice to the parties in October 2020 that it was withdrawing its request to combine residential rates. Entergy Louisiana noted that the withdrawal is without prejudice to Entergy Louisiana’s right to seek to combine residential rates in a future proceeding.

2019 Formula Rate Plan Filing

In May 2020, Entergy Louisiana filed with the LPSC its formula rate plan evaluation report for its 2019 calendar year operations. The 2019 test year evaluation report produced an earned return on common equity of 9.66%. As such, no change to base rider formula rate plan revenue is required. Although base rider formula rate plan revenue did not change as a result of this filing, overall formula rate plan revenues increased by approximately $103 million. This outcome is driven by the removal of prior year credits associated with the sale of the Willow Glen Power Station and an increase in the transmission recovery mechanism. Also contributing to the overall change was an increase in legacy formula rate plan revenue requirements driven by legacy Entergy Louisiana capacity cost true-ups and higher annualized legacy Entergy Gulf States Louisiana revenues due to higher billing determinants, offset by reductions in MISO cost recovery mechanism and tax reform adjustment mechanism revenue requirements. In August 2020 the LPSC staff submitted a list of items for which it needs additional information to confirm the accuracy and compliance of the 2019 test year evaluation report. The LPSC staff objected to a proposed revenue neutral adjustment regarding a certain rider as being beyond the scope of permitted formula rate plan adjustments. Rates reflected in the May 2020 filing, with the exception of a revenue neutral rider adjustment, and as updated in an August 2020 filing, were implemented in September 2020, subject to refund. Entergy Louisiana is in the process of providing additional information and details on the May 2020 filing as requested by the LPSC staff. In August 2021 the LPSC staff issued a letter updating its objections/reservations for the 2019 test year formula rate plan filing. In its letter, the LPSC staff disputes Entergy Louisiana’s exclusion of approximately $251 thousand of interest income allocated from Entergy Operations and Entergy Services to Entergy Louisiana to the extent that there are other adjustments that would move Entergy Louisiana out of the formula rate plan deadband. The LPSC staff reserved the right to further contest the issue in future proceedings. The LPSC staff further reserved outstanding issues from the 2017 and 2018 formula rate plan evaluation reports and withdrew all other remaining objections/reservations.

In November 2020, Entergy Louisiana accepted ownership of the Washington Parish Energy Center and filed an update to its 2019 formula rate plan evaluation report to include the estimated first-year revenue requirement of $35 million associated with the Washington Parish Energy Center. The resulting interim adjustment to rates became effective with the first billing cycle of December 2020. In January 2021, Entergy Louisiana filed an update to its 2019 formula rate plan evaluation report to include the implementation of a scheduled step-up in its nuclear decommissioning revenue requirement and a true-up for under-collections of nuclear decommissioning expenses. The total rate adjustment would increase formula rate plan revenues by approximately $1.2 million. The resulting interim adjustment to rates became effective with the first billing cycle of February 2021.

Request for Extension and Modification of Formula Rate Plan

In May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. In its application, Entergy Louisiana sought to maintain a 9.8% return on equity, with a bandwidth of 60 basis points above and below the midpoint, with a first-year midpoint reset. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. In May 2021 the LPSC approved the uncontested settlement. Key terms of the settlement include: a three year term (test years

2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.

2020 Formula Rate Plan Filing

In June 2021, Entergy Louisiana filed its formula rate plan evaluation report for its 2020 calendar year operations. The 2020 test year evaluation report produced an earned return on common equity of 8.45%, with a base formula rate plan revenue increase of $63 million. Certain reductions in formula rate plan revenue driven by lower sales volumes, reductions in capacity cost and net MISO cost, and higher credits resulting from the Tax Cuts and Jobs Act offset the base formula rate plan revenue increase, leading to a net increase in formula rate plan revenue of $50.7 million. The report also included multiple new adjustments to account for, among other things, the calculation of distribution recovery mechanism revenues. The effects of the changes to total formula rate plan revenue are different for each legacy company, primarily due to differences in the legacy companies’ capacity cost changes, including the effect of true-ups. Legacy Entergy Louisiana formula rate plan revenues will increase by $27 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $23.7 million. Subject to refund and LPSC review, the resulting changes became effective for bills rendered during the first billing cycle of September 2021. Discovery commenced in the proceeding. In August 2021, Entergy Louisiana submitted an update to its evaluation report to account for various changes. Relative to the June 2021 filing, the total formula rate plan revenue increased by $14.2 million to an updated total of $64.9 million. Legacy Entergy Louisiana formula rate plan revenues will increase by $32.8 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $32.1 million. The results of the 2020 test year evaluation report bandwidth calculation were unchanged as there was no change in the earned return on common equity of 8.45%. In September 2021 the LPSC staff filed a letter with a general statement of objections/reservations because it had not completed its review, and indicated it would update the letter once its review was complete. Should the parties be unable to resolve any objections, those issues will be set for hearing, with recovery of the associated costs subject to refund.

Investigation of Costs Billed by Entergy Services

In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As stated in the notice of proceeding, the LPSC observed an increase in capital construction-related costs incurred by Entergy Services. Discovery was issued and included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. There has been no further activity in the investigation since May 2019.

COVID-19 Orders

In April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated

with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. The suspension of late fees and disconnects for non-pay was extended until the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that had not made payment arrangements. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of December 31, 2021, Entergy Louisiana had a regulatory asset of $56.3 million for costs associated with the COVID-19 pandemic.

Entergy Arkansas Opportunity Sales Proceeding

In June 2009 the LPSC filed a complaint requesting that the FERC determine that certain of Entergy Arkansas’s sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocated the energy generated by Entergy System resources; (b) imprudently denied the Entergy System and its ultimate consumers the benefits of low-cost Entergy System generating capacity; and (c) violated the provision of the System Agreement that prohibited sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. The LPSC’s complaint challenged sales made beginning in 2002 and requested refunds. In July 2009 the Utility operating companies filed a response to the complaint arguing among other things that the System Agreement contemplates that the Utility operating companies may make sales to third parties for their own account, subject to the requirement that those sales be included in the load (or load shape) for the applicable Utility operating company. The FERC subsequently ordered a hearing in the proceeding.

After a hearing, the ALJ issued an initial decision in December 2010. The ALJ found that the System Agreement allowed for Entergy Arkansas to make the sales to third parties but concluded that the sales should be accounted for in the same manner as joint account sales. The ALJ concluded that “shareholders” should make refunds of the damages to the Utility operating companies, along with interest. Entergy disagreed with several aspects of the ALJ’s initial decision and in January 2011 filed with the FERC exceptions to the decision.

The FERC issued a decision in June 2012 and held that, while the System Agreement is ambiguous, it does provide authority for individual Utility operating companies to make opportunity sales for their own account and Entergy Arkansas made and priced these sales in good faith. The FERC found, however, that the System Agreement does not provide authority for an individual Utility operating company to allocate the energy associated with such opportunity sales as part of its load but provides a different allocation authority. The FERC further found that the after-the-fact accounting methodology used to allocate the energy used to supply the sales was inconsistent with the System Agreement. The FERC in its decision established further hearing procedures to quantify the effect of repricing the opportunity sales in accordance with the FERC’s June 2012 decision. The hearing was held in May 2013 and the ALJ issued an initial decision in August 2013. The LPSC, the APSC, the City Council, and FERC staff filed briefs on exceptions and/or briefs opposing exceptions. Entergy filed a brief on exceptions requesting that the FERC reverse the initial decision and a brief opposing certain exceptions taken by the LPSC and FERC staff.

In April 2016 the FERC issued orders addressing requests for rehearing filed in July 2012 and the ALJ’s August 2013 initial decision. The first order denied Entergy’s request for rehearing and affirmed the FERC’s earlier rulings that Entergy’s original methodology for allocating energy costs to the opportunity sales was incorrect and, as a result, Entergy Arkansas must make payments to the other Utility operating companies to put them in the same position that they would have been in absent the incorrect allocation. The FERC clarified that interest should be included with the payments. The second order affirmed in part, and

reversed in part, the rulings in the ALJ’s August 2013 initial decision regarding the methodology that should be used to calculate the payments Entergy Arkansas is to make to the other Utility operating companies. The FERC affirmed the ALJ’s ruling that a full re-run of intra-system bills should be performed but required that methodology be modified so that the sales have the same priority for purposes of energy allocation as joint account sales. The FERC reversed the ALJ’s decision that any payments by Entergy Arkansas should be reduced by 20%. The FERC also reversed the ALJ’s decision that adjustments to other System Agreement service schedules and excess bandwidth payments should not be taken into account when calculating the payments to be made by Entergy Arkansas. The FERC held that such adjustments and excess bandwidth payments should be taken into account but ordered further proceedings before an ALJ to address whether a cap on any reduction due to bandwidth payments was necessary and to implement the other adjustments to the calculation methodology.

In May 2016, Entergy Services filed a request for rehearing of the FERC’s April 2016 order arguing that payments made by Entergy Arkansas should be reduced as a result of the timing of the LPSC’s approval of certain contracts. Entergy Services also filed a request for clarification and/or rehearing of the FERC’s April 2016 order addressing the ALJ’s August 2013 initial decision. The APSC and the LPSC also filed requests for rehearing of the FERC’s April 2016 order. In September 2017 the FERC issued an order denying the request for rehearing on the issue of whether any payments by Entergy Arkansas to the other Utility operating companies should be reduced due to the timing of the LPSC’s approval of Entergy Arkansas’s wholesale baseload contract with Entergy Louisiana. In November 2017 the FERC issued an order denying all of the remaining requests for rehearing of the April 2016 order. In November 2017, Entergy Services filed a petition for review in the D.C. Circuit of the FERC’s orders in the first two phases of the opportunity sales case. In December 2017 the D.C. Circuit granted Entergy Services’ request to hold the appeal in abeyance pending final resolution of the related proceeding before the FERC. In January 2018 the APSC and the LPSC filed separate petitions for review in the D.C. Circuit, and the D.C. Circuit consolidated the appeals with Entergy Services’ appeal.

The hearing required by the FERC’s April 2016 order was held in May 2017. In July 2017 the ALJ issued an initial decision addressing whether a cap on any reduction due to bandwidth payments was necessary and whether to implement the other adjustments to the calculation methodology. In August 2017 the Utility operating companies, the LPSC, the APSC, and FERC staff filed individual briefs on exceptions challenging various aspects of the initial decision. In September 2017 the Utility operating companies, the LPSC, the APSC, the MPSC, the City Council, and FERC staff filed separate briefs opposing exceptions taken by various parties.

Based on testimony previously submitted in the case and its assessment of the April 2016 FERC orders, in the first quarter 2016, Entergy Arkansas recorded a liability of $87 million, which included interest, for its estimated increased costs and payment to the other Utility operating companies, and a deferred fuel regulatory asset of $75 million. Following its assessment of the course of the proceedings, including the FERC’s denial of rehearing in November 2017 described above, in the fourth quarter 2017, Entergy Arkansas recorded an additional liability of $35 million and a regulatory asset of $31 million.

In October 2018 the FERC issued an order addressing the ALJ’s July 2017 initial decision. The FERC reversed the ALJ’s decision to cap the reduction in Entergy Arkansas’s payment to account for the increased bandwidth payments that Entergy Arkansas made to the other operating companies. The FERC also reversed the ALJ’s decision that Grand Gulf sales from January through September 2000 should be included in the calculation of Entergy Arkansas’s payment. The FERC affirmed on other grounds the ALJ’s rejection of the LPSC’s claim that certain joint account sales should be accounted for as part of the calculation of

Entergy Arkansas’s payment. In November 2018 the LPSC requested rehearing of the FERC’s October 2018 decision. In December 2019 the FERC denied the LPSC’s request for rehearing. In January 2020 the LPSC appealed the December 2019 decision to the D.C. Circuit.

In December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018:


	Total refunds including interest
	Payment/(Receipt)
	(In Millions)
	Principal	Interest	Total
Entergy Arkansas	$68	$67	$135
Entergy Louisiana	($30)	($29)	($59)
Entergy Mississippi	($18)	($18)	($36)
Entergy New Orleans	($3)	($4)	($7)
Entergy Texas	($17)	($16)	($33)

As described above, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. Briefing was completed in September 2020 and oral argument was heard in December 2020. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders.

In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In November 2019 the FERC issued an order denying the LPSC’s complaint. The order concluded that the settlement agreement approved by the FERC in December 2015 terminating the System Agreement barred the LPSC’s new complaint. In December 2019 the LPSC requested rehearing of the FERC’s November 2019 order, and in July 2020 the FERC issued an order dismissing the LPSC’s request for rehearing. In September 2020 the LPSC appealed to the D.C. Circuit the FERC’s orders dismissing the new opportunity sales complaint. In November 2020 the D.C. Circuit issued an order establishing that briefing will occur in January 2021 through April 2021. Oral argument was held in September 2021. In December 2021 the D.C. Circuit denied the LPSC’s Petition for Review of the new opportunity sales complaint. The opportunity sales cases are complete at FERC and at the D.C. Circuit and no additional refund amounts are owed by Entergy Arkansas.

Storm Cost Recovery Filings with Retail Regulators

Entergy Louisiana

Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida

In August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread

outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild.

In October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana withdrew $257 million from its funded storm reserves.

In February 2021 two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice accumulation sagged or downed trees, limbs and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing additional outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana recovered the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by these storms are currently estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, is eligible for recovery from customers. Additionally, Entergy Louisiana is requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million is appropriate. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021. As previously discussed, in August 2021, Hurricane Ida caused extensive damage to Entergy Louisiana’s distribution and, to a lesser extent, transmission systems resulting in widespread power outages. In September 2021, Entergy Louisiana supplemented the application with a request to establish and securitize a $1 billion restricted storm escrow account for Hurricane Ida related restoration costs, subject to a subsequent prudence review. In total, Entergy Louisiana requested authorization for the issuance of system restoration bonds in one or more series in an aggregate principal amount of $3.18 billion, which includes the costs of re-establishing and funding a storm damage escrow account, carrying costs and unamortized debt costs on interim financing, and issuance costs. After filing of testimony by LPSC staff and intervenors, which generally supported or did not oppose Entergy Louisiana’s requests, the parties negotiated and executed an uncontested stipulated settlement which was filed with the LPSC in February 2022. The settlement agreement contains the following key terms: $2.1 billion of restoration costs from Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri were prudently incurred and are eligible for recovery; carrying costs of $51 million are recoverable; a $290 million cash storm reserve should be re-established; a $1 billion reserve should be established to partially pay for Hurricane Ida restoration costs; and Entergy Louisiana is authorized to finance $3.186 billion utilizing the

securitization process authorized by Act 55, as supplemented by Act 293. The LPSC voted to approve the settlement at its February 2022 meeting.

Hurricane Isaac

In August 2012, Hurricane Isaac caused extensive damage to Entergy Louisiana’s service area. In June 2014 the LPSC authorized Entergy Louisiana to utilize Louisiana Act 55 financing for Hurricane Isaac system restoration costs. Entergy Louisiana committed to pass on to customers a minimum of $30.8 million of customer benefits through annual customer credits of approximately $6.2 million for five years. Approvals for the Act 55 financings were obtained from the Louisiana Utilities Restoration Corporation (LURC) and the Louisiana State Bond Commission.

In August 2014 the Louisiana Local Government Environmental Facilities and Community Development Authority (LCDA) issued $314.85 million in bonds under Louisiana Act 55. From the $309 million of bond proceeds loaned by the LCDA to the LURC, the LURC deposited $16 million in a restricted escrow account as a storm damage reserve for Entergy Louisiana and transferred $293 million directly to Entergy Louisiana. Entergy Louisiana used the $293 million received from the LURC to acquire 2,935,152.69 Class C preferred, non-voting, membership interest units of Entergy Holdings Company LLC, a company wholly-owned and consolidated by Entergy, that carry a 7.5% annual distribution rate. Distributions are payable quarterly commencing on September 15, 2014, and the membership interests have a liquidation price of $100 per unit. The preferred membership interests are callable at the option of Entergy Holdings Company LLC after ten years under the terms of the LLC agreement. The terms of the membership interests include certain financial covenants to which Entergy Holdings Company LLC is subject, including the requirement to maintain a net worth of at least $1.75 billion.

Entergy and Entergy Louisiana do not report the bonds issued by the LCDA on their balance sheets because the bonds are the obligation of the LCDA and there is no recourse against Entergy or Entergy Louisiana in the event of a bond default. To service the bonds, Entergy Louisiana collects a system restoration charge on behalf of the LURC and remits the collections to the bond indenture trustee. Entergy and Entergy Louisiana do not report the collections as revenue because Entergy Louisiana is merely acting as the billing and collection agent for the state.

In the first quarter 2020, Entergy and the IRS agreed upon and settled on the treatment of funds received by Entergy Louisiana in conjunction with the Act 55 financing of Hurricane Isaac storm costs, which resulted in a net reduction of income tax expense of approximately $32 million. As a result of the settlement, the position was partially sustained and Entergy Louisiana recorded a reduction of income tax expense of approximately $58 million primarily due to the reversal of liabilities for uncertain tax positions in excess of the agreed-upon settlement. Entergy recorded an increase to income tax expense of $26 million primarily resulting from the reduction of the deferred tax asset, associated with utilization of the net operating loss as a result of the settlement. This adjustment recorded by Entergy also accounted for the tax rate change of the Tax Cuts and Jobs Act. As a result of the IRS settlement, Entergy Louisiana recorded a $29 million ($21 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to the LPSC Hurricane Isaac Act 55 financing order.

Hurricane Gustav and Hurricane Ike

In September 2008, Hurricane Gustav and Hurricane Ike caused catastrophic damage to Entergy Louisiana’s service territory. In December 2009, Entergy Louisiana entered into a stipulation agreement with the LPSC staff regarding its storm costs. In March and April 2010, Entergy Louisiana and other parties to the

proceeding filed with the LPSC an uncontested stipulated settlement that included Entergy Louisiana’s proposal to utilize Act 55 financing, which included a commitment to pass on to customers a minimum of $43.3 million of customer benefits through a prospective annual rate reduction of $8.7 million for five years. In April 2010 the LPSC approved the settlement and subsequently issued financing orders and a ratemaking order intended to facilitate the implementation of the Act 55 financings. In June 2010 the Louisiana State Bond Commission approved the Act 55 financing. The settlement agreement allowed for an adjustment to the credits if there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Louisiana Act 55 financing savings obligation regulatory liability related to Hurricane Gustav and Hurricane Ike was reduced by $2.7 million, with a corresponding increase to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements.

In July 2010 the LCDA issued two series of bonds totaling $713.0 million under Act 55. From the $702.7 million of bond proceeds loaned by the LCDA to the LURC, the LURC deposited $290 million in a restricted escrow account as a storm damage reserve for Entergy Louisiana and transferred $412.7 million directly to Entergy Louisiana. From the bond proceeds received by Entergy Louisiana from the LURC, Entergy Louisiana used $412.7 million to acquire 4,126,940.15 Class B preferred, non-voting, membership interest units of Entergy Holdings Company LLC, a company wholly-owned and consolidated by Entergy, that carry a 9% annual distribution rate. Distributions are payable quarterly commencing on September 15, 2010, and the membership interests have a liquidation price of $100 per unit. The preferred membership interests are callable at the option of Entergy Holdings Company LLC after ten years under the terms of the LLC agreement. The terms of the membership interests include certain financial covenants to which Entergy Holdings Company LLC is subject, including the requirement to maintain a net worth of at least $1 billion.

Entergy and Entergy Louisiana do not report the bonds issued by the LCDA on their balance sheets because the bonds are the obligation of the LCDA, and there is no recourse against Entergy or Entergy Louisiana in the event of a bond default. To service the bonds, Entergy Louisiana collects a system restoration charge on behalf of the LURC and remits the collections to the bond indenture trustee. Entergy and Entergy Louisiana do not report the collections as revenue because Entergy Louisiana is merely acting as the billing and collection agent for the state.

Hurricane Katrina and Hurricane Rita

In August and September 2005, Hurricanes Katrina and Rita caused catastrophic damage to Entergy Louisiana’s service territory. In March 2008, Entergy Louisiana and the LURC filed at the LPSC an application requesting that the LPSC grant a financing order authorizing the financing of Entergy Louisiana storm costs, storm reserves, and issuance costs pursuant to Louisiana Act 55. Entergy Louisiana also filed an application requesting LPSC approval for ancillary issues including the mechanism to flow charges and savings to customers via a storm cost offset rider. In April 2008 the Louisiana Public Facilities Authority (LPFA), which is the issuer of the bonds pursuant to the Act 55 financing, approved requests for the Act 55 financing. Also in April 2008, Entergy Louisiana and the LPSC staff filed with the LPSC an uncontested stipulated settlement that included Entergy Louisiana’s proposal under the Act 55 financing, which included a commitment to pass on to customers a minimum of $40 million of customer benefits through a prospective annual rate reduction of $8 million for five years. The LPSC subsequently approved the settlement and issued two financing orders and one ratemaking order intended to facilitate implementation of the Act 55 financing. In May 2008 the Louisiana State Bond Commission granted final approval of the Act 55 financing. The settlement agreement allowed for an adjustment to the credits if there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and

the lowering of the federal corporate income tax rate from 35% to 21%, the Louisiana Act 55 financing savings obligation regulatory liability related to Hurricanes Katrina and Rita was reduced by $22.3 million, with a corresponding increase to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements.

In July 2008 the LPFA issued $687.7 million in bonds under the aforementioned Act 55. From the $679 million of bond proceeds loaned by the LPFA to the LURC, the LURC deposited $152 million in a restricted escrow account as a storm damage reserve for Entergy Louisiana and transferred $527 million directly to Entergy Louisiana. From the bond proceeds received by Entergy Louisiana from the LURC, Entergy Louisiana invested $545 million, including $17.8 million that was withdrawn from the restricted escrow account as approved by the April 16, 2008 LPSC orders, in exchange for 5,449,861.85 Class A preferred, non-voting, membership interest units of Entergy Holdings Company LLC, a company wholly-owned and consolidated by Entergy, that carry a 10% annual distribution rate. In August 2008 the LPFA issued $278.4 million in bonds under the aforementioned Act 55. From the $274.7 million of bond proceeds loaned by the LPFA to the LURC, the LURC deposited $87 million in a restricted escrow account as a storm damage reserve for Entergy Louisiana and transferred $187.7 million directly to Entergy Louisiana. From the bond proceeds received by Entergy Louisiana from the LURC, Entergy Louisiana invested $189.4 million, including $1.7 million that was withdrawn from the restricted escrow account as approved by the April 16, 2008 LPSC orders, in exchange for 1,893,918.39 Class A preferred, non-voting, membership interest units of Entergy Holdings Company LLC that carry a 10% annual distribution rate. Distributions are payable quarterly commencing on September 15, 2008 and have a liquidation price of $100 per unit. The preferred membership interests are callable at the option of Entergy Holdings Company LLC after ten years under the terms of the LLC agreement. The terms of the membership interests include certain financial covenants to which Entergy Holdings Company LLC is subject, including the requirement to maintain a net worth of at least $1 billion.

The bonds were repaid in 2018. Entergy and Entergy Louisiana did not report the bonds issued by the LPFA on their balance sheets because the bonds are the obligation of the LPFA, and there was no recourse against Entergy or Entergy Louisiana in the event of a bond default. To service the bonds, Entergy Louisiana collected a system restoration charge on behalf of the LURC and remitted the collections to the bond indenture trustee. Entergy and Entergy Louisiana did not report the collections as revenue because Entergy Louisiana was merely acting as the billing and collection agent for the state.

NOTE 3. INCOME TAXES

Details regarding income taxes are presented on FERC Form 1 pages 261-267 and 272-277.

Carryovers

The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows:

Entergy Arkansas

Entergy Louisiana

Entergy Mississippi

Entergy New Orleans

Entergy Texas

System Energy

Federal net operating losses before 1/1/2018

$— billion

$1.7 billion

$— billion

$0.9 billion

$— billion

Year(s) of expiration

N/A

2035-2037

N/A

2037

N/A

Federal net operating losses - 1/1/2018 forward

$4.5 billion

$2.1 billion

$0.7 billion

$2.6 billion

$— billion

Year(s) of expiration

N/A

State net operating losses

$4.8 billion

$7.2 billion

$2.3 billion

$1.7 billion

$— million

Year(s) of expiration

2023-2026

N/A

2038-2041

N/A

Misc. federal credits

$4.7 million

$12.3 million

$1.8 million

$15.3 million

$3.1 million

$1.5 million

Year(s) of expiration

2038-2041

2035-2041

2038-2041

2037-2041

2036-2041

State credits

$— million

$1.3 million

$—million

$2.9 million

$9 million

Year(s) of expiration

N/A

2022-2025

N/A

2027

2022-2025

As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers and tax credit carryovers.

Unrecognized tax benefits

Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded.

A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows:


2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Gross balance at January 1, 2021	$1,364,635	$640,295	$549,717	$639,546	$521,932	$21,652
Additions based on tax positions related to the current year	30,419	13,437	684	1,050	32,616	1,753
Additions for tax positions of prior years	15,013	9,304	1,504	6	2,315	1,897
Reductions for tax positions of prior years	(1,573)	(58,408)	(2,336)	(1,105)	(4,568)	(1,946)
Gross balance at December 31, 2021	1,408,494	604,628	549,569	639,497	552,295	23,356
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers	(992,643)	(604,628)	(388,728)	(484,899)	(540,694)	(8,576)
Unrecognized tax benefits net of unused tax attributes and payments	$415,851	$—	$160,841	$154,598	$11,601	$14,780


2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Gross balance at January 1, 2020	$1,341,242	$2,381,653	$566,287	$716,773	$21,406	$473,331


Additions based on tax positions related to the current year (a)	9,403	35,681	5,619	2,430	504,362	4,013
Additions for tax positions of prior years	13,400	10,508	1,156	294	799	4,606
Reductions for tax positions of prior years	(11,346)	(679,601)	(24,173)	(80,267)	(5,559)	(41,466)
Settlements	11,936	(1,107,946)	828	316	924	(418,832)
Gross balance at December 31, 2020	1,364,635	640,295	549,717	639,546	521,932	21,652
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers	(1,112,628)	(640,295)	(465,679)	(451,922)	(507,720)	(7,413)
Unrecognized tax benefits net of unused tax attributes and payments	$252,007	$—	$84,038	$187,624	$14,212	$14,239


2019	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Gross balance at January 1, 2019	$1,298,662	$2,400,171	$508,765	$686,687	$17,802	$467,487
Additions based on tax positions related to the current year	84,335	28,705	68,594	40,676	2,312	5,496
Additions for tax positions of prior years	20,399	25,090	1,651	489	1,299	2,186
Reductions for tax positions of prior years	(62,154)	(72,313)	(12,723)	(11,079)	(7)	(1,838)
Gross balance at December 31, 2019	1,341,242	2,381,653	566,287	716,773	21,406	473,331
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers	(1,134,187)	(1,573,257)	(506,976)	(445,430)	(3,944)	(8,392)
Unrecognized tax benefits net of unused tax attributes and payments	$207,055	$808,396	$59,311	$271,343	$17,462	$464,939

a.The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “Other Tax Matters - Tax Accounting Methods” below.

The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows:


	December 31,
	2021	2020	2019
	(In Millions)
Entergy Arkansas	$262.1	$259.3	$203.3
Entergy Louisiana	$66.3	$63.8	$556.3
Entergy Mississippi	$51.7	$50.7	$1.9
Entergy New Orleans	$228.6	$203.5	$242.7
Entergy Texas	$2.6	$6.1	$5.7
System Energy	$1.7	$0.5	$—

Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows:


	December 31,
	2021	2020	2019
	(In Millions)
Entergy Arkansas	$2.7	$2.3	$3.1
Entergy Louisiana	$3.7	$3.4	$14.2
Entergy Mississippi	$2.4	$1.9	$1.7
Entergy New Orleans	$5.2	$3.9	$4.7
Entergy Texas	$1.1	$0.9	$1.1
System Energy	$12.1	$11.9	$14.5

The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2021, 2020, and 2019. Interest (net-of-tax) was recorded as follows:


	2021	2020	2019
	(In Millions)
Entergy Arkansas	$0.4	($0.8)	$1.4
Entergy Louisiana	$0.3	($10.8)	($3.7)
Entergy Mississippi	$0.5	$0.2	$0.5
Entergy New Orleans	$1.3	($0.8)	$2.0
Entergy Texas	$0.2	($0.2)	$0.2
System Energy	$0.2	($2.6)	$1.3

Income Tax Audits

Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2016. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months.

2014-2015 IRS Audit

The IRS completed its examination of the 2014 and 2015 tax years and issued its 2014-2015 RAR in November 2020. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of the adjustments associated with the audit in 2020.

In October 2015 two of Entergy’s Louisiana utilities, Entergy Gulf States Louisiana and Entergy Louisiana, combined their businesses into a legal entity which is identified as Entergy Louisiana herein. The structure of the business combination required Entergy to recognize a gain for income tax purposes which resulted in an increase in the tax basis of the assets for Entergy Louisiana. This resulted in recognition in 2015 of a $334 million permanent difference and income tax benefit, net of the uncertain tax position recorded on the transaction.

Primarily related to resolution of the business combination issues, completion of the 2014-2015 IRS audit in 2020 resulted in a $230 million reduction to deferred income tax expense for Entergy. This reduction

to deferred income tax expense includes: Entergy Louisiana reversing its provision for uncertain tax position with respect to the business combination, which resulted in a reduction to deferred income tax expense of $383 million.

The completion of the 2014-2015 tax audit also resulted in a $31 million reduction to income tax expense associated with Entergy Louisiana’s method of accounting related to the adoption of tangible property regulations. As a result of the settlement of the tangible property regulation tax position, Entergy Louisiana was required to record a $33 million ($24 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to a prior regulatory settlement.

In the first quarter 2020, Entergy and the IRS agreed on the treatment of funds received by Entergy Louisiana in conjunction with the Act 55 financing of Hurricane Isaac storm costs, which resulted in a net reduction of income tax expense of approximately $32 million. As a result of the settlement, the position was partially sustained, and Entergy Louisiana recorded a reduction of income tax expense of approximately $58 million primarily due to the reversal of a provision for uncertain tax positions in excess of the agreed-upon settlement. As a result of the IRS settlement, Entergy Louisiana recorded a $29 million ($21 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to the LPSC Hurricane Isaac Act 55 financing order.

Additional effects of the completion of the 2014-2015 IRS tax audit are discussed below within Tax Accounting Methods.

Other Tax Matters

Tax Cuts and Jobs Act (TCJA)

The most significant effect of the TCJA for Entergy and the Registrant Subsidiaries was the change in the federal corporate income tax rate from 35% to 21%, effective January 1, 2018.

TCJA also limited the deduction for net business interest expense to 30 percent of adjusted taxable income, which is similar to earnings before interest, taxes, depreciation, and amortization. The limitation does not apply to interest expense that is properly allocable to a trade or business classified as a regulated public utility. This was further modified by a temporary provision of the CARES Act resulting in an increase of the adjusted taxable income limitation from 30% to 50% for tax years that begin in 2019 or 2020.

The IRS issued final regulations which are effective for Entergy beginning with the 2021 tax year. The regulations provide that if 90% of a tax group’s consolidated assets consist of regulated utility property, the entire consolidated tax group will be treated as a regulated public utility and all of the consolidated group’s interest expense will be currently tax deductible. Entergy expects that this provision will continue to apply to Entergy’s business operations making the application of this limitation to Entergy less likely. The provision has not resulted in Entergy having to report any significant business interest expense limitations on its tax returns.

With respect to the federal corporate income tax rate change from 35% to 21% in 2017, Entergy and the Registrant Subsidiaries recorded a regulatory liability associated with the decrease in the net accumulated deferred income tax liability, which is often referred to as “excess ADIT,” a significant portion of which has been paid to customers in 2019, 2020 and 2021 in the form of lower rates. Entergy’s December 31, 2021 and December 31, 2020 balance sheets reflect a regulatory liability of $1.3 billion and $1.6 billion, respectively, as a result of the re-measurement of deferred tax assets and liabilities from the income tax rate change, amortization of excess ADIT, and payments to customers during 2019, 2020 and 2021. Entergy’s regulatory

liability for income taxes includes a gross-up at the applicable tax rate because of the effect that excess ADIT has on the ratemaking formula. The regulatory liability for income taxes includes the effect of a) the reduction of the net deferred tax liability resulting in excess ADIT, and b) the tax gross-up of excess ADIT. The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows:


	2021	2020
	(In Millions)
Entergy Arkansas	$432	$467
Entergy Louisiana	$338	$479
Entergy Mississippi	$212	$224
Entergy New Orleans	$42	$59
Entergy Texas	$171	$205
System Energy	$113	$152

Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows:


	2021	2020
	(In Millions)
Entergy Arkansas	$463	$490
Entergy Louisiana	$669	$721
Entergy Mississippi	$237	$248
Entergy New Orleans	$56	$61
Entergy Texas	$208	$215
System Energy	$148	$173

Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows:


	2021	2020
	(In Millions)
Entergy Arkansas	$12	$11


Entergy Louisiana	$148	$223
Entergy New Orleans	$—	$3
Entergy Texas	$26	$54
System Energy	$—	$16

The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020:


	2021	2020
	(In Millions)
Entergy	$88	$74
Entergy Arkansas	$8	$8
Entergy Louisiana	$33	$31
Entergy New Orleans	$1	$6
Entergy Texas	$28	$29
System Energy	$18	$—

In addition to the protected and unprotected excess ADIT amounts, the net regulatory liability for income taxes includes other regulatory assets and liabilities for income taxes associated with AFUDC, which is described in Note 1 to the financial statements.

Included in the effect of the computation of the changes in deferred tax assets and liabilities is the recognition threshold and measurement of uncertain tax positions resulting in unrecognized tax benefits. The final economic outcome of such unrecognized tax benefits is generally the result of a negotiated settlement with the IRS that often differs from the amount that is recorded as realizable under GAAP. The intrinsic uncertainty with respect to all such tax positions means that the difference between current estimates of such amounts likely to be realized and actual amounts realized upon settlement may have an effect on income tax expense and the regulatory liability for income taxes in future periods.

Entergy anticipates that the effect of TCJA may continue to have ramifications that require adjustments in the future as certain events occur. These events include: 1) IRS audit adjustments to or amendments of federal and state income tax returns that include modifications to the computation of taxable income resulting from TCJA; and 2) additional guidance, interpretations, or rulings by the U.S. Department of the Treasury or the IRS. The potential exists for these types of events to result in future tax expense adjustments because of the difference in the federal corporate income tax rate between past and future periods and the effect of the tax rate change on ratemaking. In turn, these events also could potentially affect the regulatory liability for income taxes.

Coronavirus Aid, Relief, and Economic Security Act

In response to the economic impacts of the COVID-19 pandemic, President Trump signed the Coronavirus Aid, Relief, and Economic Security Act (CARES Act) into law on March 27, 2020. The CARES Act provisions that result in the most significant opportunities for tax relief to Entergy and the Registrant Subsidiaries are (i) permitting a five-year carryback of 2018-2020 NOLs, (ii) removing the 80 percent limitation on NOLs carried to tax years beginning before 2021, (iii) increasing the limitation on interest expense deductibility for 2019 and 2020, (iv) accelerating available refunds for minimum tax credit carryforwards, modifying limitations on charitable contributions during 2020, and (v) delaying the payment of

employer payroll taxes. Entergy deferred approximately $64 million of 2020 payroll tax payments, payable in equal installments over two years. The initial installment of $32 million was paid in December 2021. The second installment will be paid in December 2022.

Tax Accounting Methods

In the fourth quarter 2015, System Energy and Entergy Louisiana adopted a new method of accounting for income tax return purposes in which their nuclear decommissioning costs will be treated as production costs of electricity includable in cost of goods sold. The new method resulted in a reduction of taxable income of $1.2 billion for System Energy and $2.2 billion for Energy Louisiana.

In conjunction with the 2014-2015 IRS audit discussed above, the IRS issued proposed adjustments concerning the nuclear decommissioning tax position allowing System Energy to include $102 million of its decommissioning liability in cost of goods sold, and Entergy Louisiana to include $221 million of its decommissioning liability in cost of goods sold. Entergy, System Energy, and Entergy Louisiana agreed to the proposed adjustments included in the RAR.

As a result of Entergy Louisiana being allowed to include part of its decommissioning liability in cost of goods sold, Entergy Louisiana and Entergy recorded a deferred tax liability of $60 million. Both Entergy Louisiana and Entergy utilized tax loss carryovers to offset the taxable income adjustment and accordingly did not record taxes payable as a result of the outcome of this uncertain tax position.

The partial disallowance of this uncertain tax position to include the decommissioning liability in cost of goods sold resulted in a $1.5 billion decrease in the balance of unrecognized tax benefits related to federal and state taxes for Entergy. Additionally, both System Energy and Entergy Louisiana recorded a reduction to their balances of unrecognized tax benefits for federal and state taxes of $461 million and $1.1 billion, respectively.

In 2016, Entergy Louisiana elected mark-to-market income tax treatment for various wholesale electric power purchase and sale agreements, including Entergy Louisiana’s contract to purchase electricity from the Vidalia hydroelectric facility and from System Energy under the Unit Power Sales Agreement. The election resulted in a $2.2 billion deductible temporary difference.

Arkansas and Louisiana Corporate Income Tax Rate Changes

Pursuant to legislation enacted in 2021 and approved by Louisiana citizens by amendment to the state constitution, beginning January 1, 2022, federal income taxes paid will no longer be deductible for state income tax purposes, and the top Louisiana corporate income tax rate will be reduced from 8% to 7.5%. As a result of this change in Louisiana tax law, the Louisiana applicable tax rate increased by 0.85%. Accordingly, deferred tax assets and liabilities were adjusted to reflect the new applicable federal and state rates. Legislation enacted in 2021 also provides that Louisiana net operating losses generally have an indefinite carryover period.

Entergy recorded a net increase to its deferred tax asset of $27 million. Entergy Louisiana and Entergy New Orleans recorded net increases to their deferred tax liabilities before consideration of the tax gross-up of $77 million and $8 million, respectively, which were offset by regulatory assets for income taxes. Therefore, these increases had no effect on tax expense. However, the increase of deferred tax assets associated with certain assets reduced tax expense for Entergy Louisiana and Entergy New Orleans by $6 million and $2 million, respectively.

Consolidated Income Tax Return of Entergy Corporation

In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly-owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group. As a result of these four Utility operating companies re-joining the Entergy Corporation consolidated tax return group, Entergy was able to recognize a $41 million deferred tax asset associated with a previously unrecognized net operating loss carryover.

Stock Compensation

In accordance with stock compensation accounting rules, Entergy and the Registrant Subsidiaries recognized excess tax deductions as a reduction of income tax expense in the first quarter 2020. Due to the vesting and exercise of certain Entergy stock-based awards, Entergy recorded a permanent tax reduction of approximately $24.7 million, including $4.8 million for Entergy Arkansas, $8.6 million for Entergy Louisiana, $2.7 million for Entergy Mississippi, $1.5 million for Entergy New Orleans, $2.7 million for Entergy Texas, and $1.3 million for System Energy.

NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows:


Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of December 31, 2021	Letters of Credit Outstanding as of December 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	—	—
Entergy Arkansas	June 2026	$150 million (c)	1.23%	—	—
Entergy Louisiana	June 2026	$350 million (c)	1.32%	$125 million	—
Entergy Mississippi	April 2022	$10 million (d)	1.60%	—	—
Entergy Mississippi	April 2022	$35 million (d)	1.60%	—	—
Entergy Mississippi	April 2022	$37.5 million (d)	1.60%	—	—
Entergy New Orleans	June 2024	$25 million (c)	1.73%	—	—
Entergy Texas	June 2026	$150 million (c)	1.60%	—	$1.3 million

a.The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility.

b.Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

c.The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

d.Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire

facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021:

Company

Amount of Uncommitted Facility

Letter of Credit Fee

Letters of Credit Issued as of December 31, 2021 (a) (b)

Entergy Arkansas

$25 million

0.78%

$8.5 million

Entergy Louisiana

$125 million

0.78%

$15.0 million

Entergy Mississippi

$65 million

0.78%

$9.3 million

Entergy New Orleans

$15 million

1.00%

$1.0 million

Entergy Texas

$80 million

0.875%

$79.6 million

(a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights.

(b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:


	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$140
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$—
Entergy Texas	$200	$80
System Energy	$200	$—

NOTE 5. LONG - TERM DEBT

Details of long-term debt are presented on FERC Form 1 pages 256-257. Entergy Louisiana has obtained long-term financing authorizations from the FERC that extend through October 2023.

NOTE 6. PREFERRED EQUITY AND NONCONTROLLING INTEREST

Note 6 to the financial statements is not applicable to Entergy Louisiana.

NOTE 7. COMMON EQUITY

Comprehensive Income

Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy Louisiana.

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2021:


						Pension and Other Postretirement Liabilities
						(In Thousands)

Beginning balance, January 1, 2021						$4,327
Other comprehensive income (loss) before reclassifications						4,084
Amounts reclassified from accumulated other comprehensive income (loss)						(133)
Net other comprehensive income (loss) for the period						3,951
Ending balance, December 31, 2021						$8,278

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2020:


						Pension and Other Postretirement Liabilities
						(In Thousands)

Beginning balance, January 1, 2020						$4,562
Other comprehensive income (loss) before reclassifications						3,002
Amounts reclassified from accumulated other comprehensive income (loss)						(3,237)
Net other comprehensive income (loss) for the period						(235)
Ending balance, December 31, 2020						$4,327

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2021 and 2020 are as follows:

Amounts reclassified from AOCI

Income Statement Location


	2021	2020
	(In Thousands)

Pension and other postretirement liabilities
Amortization of prior-service costs	$4,920	$6,179	(a)
Amortization of loss	(2,322)	(1,557)	(a)
Settlement loss	(2,484)	(243)	(a)
Total amortization	114	4,379
Income taxes	19	(1,142)	Income taxes
Total amortization (net of tax)	133	3,237

Total reclassifications for the period (net of tax)	$133	$3,237


(a)			These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details

NOTE 8. COMMITMENTS AND CONTINGENCIES

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements.

Vidalia Purchased Power Agreement

Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $128.5 million in 2021, $132.7 million in 2020, and $135.5 million in 2019. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137 million in 2022, and a total of $1.23 billion for the years 2023 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause.

In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Pursuant to legislation enacted in 2021

and approved by Louisiana citizens by amendment to the state constitution, beginning January 1, 2022, federal income taxes paid will no longer be deductible for state income tax purposes, and the top Louisiana corporate income tax rate will be reduced from 8% to 7.5%. As a result of this change in Louisiana tax law, deferred taxes must be adjusted to reflect the applicable federal and state rates which has a corresponding effect on the Vidalia regulatory liability. Such effect is not expected to be significant.

Spent Nuclear Fuel Litigation

Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014.

Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2019, 2020, and 2021 related to Entergy’s nuclear owner licensee subsidiaries’ litigation with the DOE.

In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously recorded as plant.

In April 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $33 million in favor of Entergy Louisiana against the DOE in the second round Waterford 3 damages case. Entergy Louisiana received payment from the U.S. Treasury in June 2020. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The Waterford 3 damages awarded included $20 million related to costs previously recorded as nuclear fuel expense, $8 million related to costs previously recorded as other operation and maintenance expenses, and $5 million in costs previously recorded as plant.

In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $9 million in costs previously capitalized, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expense.

Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards.

Nuclear Insurance

Third Party Liability Insurance

The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage:

1.The primary level is private insurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $450 million for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies.

2.Secondary Financial Protection: Currently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $13 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers.

Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maximum of approximately $137.6 million per reactor per incident. This retrospective premium is assessable at approximately $21 million per year per incident per nuclear power reactor.

3 Total insurance coverage available is approximately $13.5 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g. off-site property and environmental damage, off-site bodily injury and on-site third-party bodily injury (i.e. contractors)). These coverages also respond to an accident caused by terrorism. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027.

Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would

share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act).

Property Insurance

Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants and Entergy Wholesale Commodity plants are in compliance with the financial protection requirements of the NRC.

The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.5 billion per occurrence at each plant with an additional $100 million per nuclear property occurrence that is shared among the plants. The nuclear property deductible is $10 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from wind for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million.

In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below:

•100% of the weekly indemnity for each week for the first payment period of 52 weeks; then

•80% of the weekly indemnity for each week for the second payment period of 52 weeks; and thereafter

•80% of the weekly indemnity for an additional 58 weeks for the third and final payment period.

Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows:


			Assessments
			(In Millions)
Utility:
Entergy Arkansas			$27.6
Entergy Louisiana			$49.2
Entergy Mississippi			$0.11
Entergy New Orleans			$0.11
Entergy Texas			N/A


System Energy			$21.4

NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors.

In the event that one or more acts of terrorism causes property damage under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceeding $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses.

Non-Nuclear Property Insurance

Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge.

Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027.

Employment and Labor-related Proceedings

The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that

loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Utility operating companies.

Asbestos Litigation

Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 200 lawsuits involving approximately 325 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies.

Grand Gulf - Related Agreements

Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas-36%, Entergy Louisiana-14%, Entergy Mississippi-33%, and Entergy New Orleans-17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. The agreement will remain in effect until terminated by the parties and the termination is approved by the FERC, most likely upon Grand Gulf’s retirement from service. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2021 under the agreement were approximately $16.4 million for Entergy Arkansas, $6.5 million for Entergy Louisiana, $14.6 million for Entergy Mississippi, and $7.9 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement.

Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas-17.1%, Entergy Louisiana-26.9%, Entergy Mississippi-31.3%, and Entergy New Orleans-24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including an amount sufficient to amortize the cost of Grand Gulf 2 over 27 years (See Reallocation Agreement terms below) and expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement have exceeded the amounts payable under the Availability Agreement. Accordingly, no payments under the Availability Agreement have ever been required. If Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other

sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments.

Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. The FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. Responsibility for any Grand Gulf 2 amortization amounts has been individually allocated (Entergy Louisiana-26.23%, Entergy Mississippi-43.97%, and Entergy New Orleans-29.80%) under the terms of the Reallocation Agreement. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future.

NOTE 9. ASSET RETIREMENT OBLIGATIONS

Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets.

These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries.

The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by the Registrant Subsidiaries were as follows:

Liabilities as of December 31, 2020

Accretion

Spending

Dispositions

Liabilities as of December 31, 2021

(In Millions)

Utility

Entergy Arkansas

1,314.2

77.7

—

(1.5)

1,390.4


Entergy Louisiana	1,573.3	79.9	—	—	1,653.2
Entergy Mississippi	9.8	0.5	—	—	10.3
Entergy New Orleans	3.8	0.2	—	—	4.0
Entergy Texas	8.1	0.4	—	—	8.5
System Energy	968.9	38.7	—	—	1,007.6


	Liabilities as of December 31, 2019	Accretion	Spending	Liabilities as of December 31, 2020
	(In Millions)
Utility
Entergy Arkansas	1,242.6	73.3	(1.7)	1,314.2
Entergy Louisiana	1,497.3	76.0	—	1,573.3
Entergy Mississippi	9.7	0.6	(0.5)	9.8
Entergy New Orleans	3.5	0.3	—	3.8
Entergy Texas	7.6	0.5	—	8.1
System Energy	931.7	37.2	—	968.9

Nuclear Plant Decommissioning

Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. Entergy did not update decommissioning cost estimates in 2021 or 2020.

NRC Filings Regarding Trust Funding Levels

Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met.

As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund.

Coal Combustion Residuals

In June 2010 the EPA issued a proposed rule on coal combustion residuals (CCRs) that contained two primary regulatory options: (1) regulating CCRs destined for disposal in landfills or received (including stored) in surface impoundments as so-called “special wastes” under the hazardous waste program of Resource Conservation and Recovery Act (RCRA) Subtitle C; or (2) regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes under Subtitle D of RCRA. Under both options, CCRs that are beneficially reused in certain processes would remain excluded from hazardous waste regulation. In April 2015 the EPA published the final CCR rule with the material being regulated under the

second scenario presented above - as non-hazardous wastes regulated under RCRA Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed for CCR that cannot be transferred for beneficial reuse. In December 2016 the Water Infrastructure Improvements for the Nation Act (WIIN Act) was signed into law, which authorizes states to regulate coal ash rather than leaving primary enforcement to citizen suit actions. States may submit to the EPA proposals for permit programs.

NOTE 10. LEASES

As of December 31, 2021 and 2020, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards.

Leases have remaining terms of one year to 59 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly.

The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Operating lease cost	$15,087	$14,368	$7,018	$1,745	$5,370
Finance lease cost:
Amortization of right-of-use assets	$2,860	$3,938	$1,766	$731	$1,493
Interest on lease liabilities	$432	$607	$270	$124	$214

Of the lease costs disclosed above, Entergy Louisiana had $934 thousand in short-term lease costs for the year ended December 31, 2021.

The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities.

The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Operating lease cost	$14,344	$13,944	$6,584	$1,443	$4,870
Finance lease cost:
Amortization of right-of-use assets	$2,693	$4,097	$1,627	$712	$1,340
Interest on lease liabilities	$408	$597	$254	$120	$196

Of the lease costs disclosed above, Entergy Louisiana had $719 thousand in short-term lease costs for the year ended December 31, 2020.

The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities.

Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below.

Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021
Operating leases	$56,099	$46,443	$16,831	$5,480	$14,986
Finance leases	$15,043	$19,007	$9,114	$4,023	$7,583

2020
Operating leases	$55,840	$43,189	$16,538	$5,222	$14,738
Finance leases	$12,447	$16,425	$7,452	$3,428	$5,719

The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Current liabilities:
Operating leases	$12,695	$12,520	$5,866	$1,491	$4,489
Finance leases	$2,964	$4,001	$1,843	$812	$1,476
Non-current liabilities:
Operating leases	$43,420	$33,931	$10,976	$3,994	$10,505
Finance leases	$12,079	$15,006	$7,271	$3,211	$6,107

The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Current liabilities:
Operating leases	$11,942	$11,934	$5,738	$1,406	$4,277
Finance leases	$2,660	$3,821	$1,644	$686	$1,327
Non-current liabilities:
Operating leases	$43,914	$31,260	$10,867	$3,819	$10,469
Finance leases	$9,788	$12,603	$5,808	$2,741	$4,392

The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas

Weighted average remaining lease terms:
Operating leases	5.13	4.65	5.36	5.35	3.94
Finance leases	5.89	5.57	5.63	5.94	5.97
Weighted average discount rate:
Operating leases	3.10	2.93	3.00	2.99	3.04
Finance leases	2.80	3.08	2.87	3.03	2.79

The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas

Weighted average remaining lease terms:
Operating leases	5.74	4.72	5.30	5.78	4.30
Finance leases	5.60	5.20	5.44	5.69	5.39
Weighted average discount rate:
Operating leases	3.34	3.11	3.43	3.09	3.07
Finance leases	3.18	3.33	3.22	3.35	3.22

Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows:

Operating Leases


Year	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)

2022	$14,180	$13,706	$6,280	$1,682	$4,888
2023	12,713	11,791	4,181	1,441	4,449
2024	11,150	9,618	3,174	1,182	3,427
2025	9,292	6,694	2,168	773	1,933
2026	7,314	4,081	827	398	771
Years thereafter	5,892	3,574	1,924	601	423
Minimum lease payments	60,541	49,464	18,554	6,077	15,891
Less: amount representing interest	4,425	3,013	1,711	592	898
Present value of net minimum lease payments	$56,116	$46,451	$16,843	$5,485	$14,993

Finance Leases


Year	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)

2022	$3,319	$4,481	$2,054	$854	$1,637
2023	3,100	4,231	1,971	814	1,532
2024	2,791	3,671	1,783	712	1,382
2025	2,449	3,122	1,529	621	1,256
2026	2,018	2,367	1,202	545	1,016
Years thereafter	2,477	2,613	1,220	673	1,296
Minimum lease payments	16,154	20,485	9,759	4,219	8,119
Less: amount representing interest	1,111	1,478	645	196	536
Present value of net minimum lease payments	$15,043	$19,007	$9,114	$4,023	$7,583

In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases.

NOTE 11. RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS

Qualified Pension Plans

Entergy has eight defined benefit qualified pension plans. The Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees, the Entergy Corporation Retirement Plan III, and the Entergy Corporation Retirement Plan IV for Bargaining Employees are non-contributory final average pay plans that provide pension benefits based on employees’ credited service and compensation during employment. Non-bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 do not participate in a final average pay plan, but instead participate in the Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan). Effective January 1, 2021, the Non-Bargaining Cash Balance Plan was closed to non-bargaining employees whose most recent date of hire is after December 31, 2020, who instead may be eligible to participate in, and receive a discretionary employer contribution under, the Savings Plan of Entergy Corporation and Subsidiaries VIII, an Entergy-sponsored tax-qualified defined contribution plan that includes a 401(k) feature. Certain bargaining employees whose most recent date of hire is after June 30, 2014, or such later date provided for in their applicable collective bargaining agreements, participate in the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). Effective January 1, 2021, the Bargaining Cash Balance Plan was amended to close participation in the plan to those bargaining employees whose most recent hire date is after December 31, 2020 or such later date provided for in their applicable collective bargaining agreements. The Registrant Subsidiaries participate in these four plans: Non-Bargaining Plan I, Bargaining Plan I, Non-Bargaining Cash Balance Plan, and Bargaining Cash Balance Plan. Effective January 1, 2022, the Non-Bargaining Cash Balance Plan was merged with and into Non-Bargaining Plan I.

The assets of the six final average pay defined benefit qualified pension plans are held in a master trust established by Entergy, and the assets of the two cash balance pension plans are held in a second master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in its respective master trust that is maintained by a trustee. Use of the master trusts permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trusts are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in each trust to the various participating pension plans in that particular trust. The fair value of the trusts’ assets is determined by the trustee and certain investment managers. For each trust, the trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trusts on a pro rata basis. Effective January 1, 2022, the assets of the remaining cash balance pension plan held in a second master trust were merged with and into a master trust that holds the assets of the six final average pay defined benefit qualified pension plans.

Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions, and are decreased for benefit payments. A plan’s investment net income/loss (i.e. interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter.

Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions.

Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI)

The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components:


2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period	$28,632	$38,271	$9,070	$3,038	$6,921	$8,851
Interest cost on projected benefit obligation	35,683	39,740	10,446	4,392	8,381	9,087
Expected return on assets	(78,368)	(89,821)	(22,407)	(10,598)	(21,158)	(19,254)
Recognized net loss	69,290	67,015	20,007	7,596	12,676	18,404
Settlement charges	37,682	61,945	16,710	5,431	11,797	12,260
Net pension cost	$92,919	$117,150	$33,826	$9,859	$18,617	$29,348
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net gain	($96,066)	($89,534)	($29,675)	($16,159)	($18,217)	($27,617)
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss	(69,290)	(67,015)	(20,007)	(7,596)	(12,676)	(18,404)
Settlement charge	(37,682)	(61,945)	(16,710)	(5,431)	(11,797)	(12,260)
Total	($203,038)	($218,494)	($66,392)	($29,186)	($42,690)	($58,281)
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)	($110,119)	($101,344)	($32,566)	($19,327)	($24,073)	($28,933)

2020

Entergy Arkansas

Entergy Louisiana

Entergy Mississippi

Entergy New Orleans

Entergy Texas

System Energy

(In Thousands)

Net periodic pension cost:


Service cost - benefits earned during the period	$26,329	$35,158	$8,060	$2,654	$6,116	$7,883
Interest cost on projected benefit obligation	44,165	50,432	12,922	5,825	10,731	11,006
Expected return on assets	(78,187)	(89,691)	(23,147)	(10,509)	(21,951)	(18,757)
Recognized net loss	68,338	66,640	18,983	8,018	13,173	17,104
Settlement charges	21,078	8,109	3,366	—	4,289	105
Net pension cost	$81,723	$70,648	$20,184	$5,988	$12,358	$17,341
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net loss	$106,178	$90,064	$36,899	$8,148	$13,379	$35,403
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss	(69,713)	(68,248)	(19,393)	(8,213)	(13,564)	(17,434)
Settlement charge	(21,078)	(8,109)	(3,366)	—	(4,289)	(105)
Total	$15,387	$13,707	$14,140	($65)	($4,474)	$17,864
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)	$97,110	$84,355	$34,324	$5,923	$7,884	$35,205


2019	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period	$21,043	$29,137	$6,516	$2,274	$5,401	$6,199
Interest cost on projected benefit obligation	56,701	63,529	16,272	7,495	14,451	13,456
Expected return on assets	(80,705)	(90,607)	(23,873)	(10,785)	(23,447)	(18,710)
Recognized net loss	47,361	46,571	12,416	6,117	9,335	11,400
Net pension cost	$44,400	$48,630	$11,331	$5,101	$5,740	$12,345
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net loss	$118,898	$99,346	$41,088	$6,531	$10,869	$36,711
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss	(47,361)	(46,571)	(12,416)	(6,117)	(9,335)	(11,400)


Total	$71,537	$52,775	$28,672	$414	$1,534	$25,311
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)	$115,937	$101,405	$40,003	$5,515	$7,274	$37,656

Qualified Pension Obligations, Plan Assets, Funded Status, Amounts Recognized in the Balance Sheet

Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows:


2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Change in Projected Benefit Obligation (PBO)
Balance at January 1	$1,739,382	$1,927,271	$510,109	$220,287	$410,664	$441,148
Service cost	28,632	38,271	9,070	3,038	6,921	8,851
Interest cost	35,683	39,740	10,446	4,392	8,381	9,087
Actuarial gain	(41,227)	(28,439)	(14,831)	(9,118)	(3,971)	(14,746)
Benefits paid (a)	(183,124)	(240,447)	(65,936)	(23,219)	(50,193)	(49,546)
Balance at December 31	$1,579,346	$1,736,396	$448,858	$195,380	$371,802	$394,794
Change in Plan Assets
Fair value of assets at January 1	$1,285,856	$1,476,306	$371,394	$172,551	$349,748	$310,818
Actual return on plan assets	133,207	150,917	37,251	17,639	35,405	32,125
Employer contributions	66,649	59,882	13,715	5,395	6,955	18,663
Benefits paid (a)	(183,124)	(240,447)	(65,936)	(23,219)	(50,193)	(49,546)
Fair value of assets at December 31	$1,302,588	$1,446,658	$356,424	$172,366	$341,915	$312,060
Funded status	($276,758)	($289,738)	($92,434)	($23,014)	($29,887)	($82,734)
Amounts recognized in the balance sheet (funded status)
Non-current liabilities	($276,758)	($289,738)	($92,434)	($23,014)	($29,887)	($82,734)
Amounts recognized as regulatory asset
Net loss	$612,963	$556,345	$173,511	$62,805	$113,790	$153,782
Amounts recognized as AOCI (before tax)
Net loss	$—	$23,181	$—	$—	$—	$—

(a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy.

2020

Entergy Arkansas

Entergy Louisiana

Entergy Mississippi

Entergy New Orleans

Entergy Texas

System Energy


	(In Thousands)
Change in Projected Benefit Obligation (PBO)
Balance at January 1	$1,615,084	$1,784,474	$471,510	$206,962	$396,764	$393,607
Service cost	26,329	35,158	8,060	2,654	6,116	7,883
Interest cost	44,165	50,432	12,922	5,825	10,731	11,006
Actuarial loss	196,755	196,032	62,564	20,535	37,579	57,574
Benefits paid (a)	(142,951)	(138,825)	(44,947)	(15,689)	(40,526)	(28,922)
Balance at December 31	$1,739,382	$1,927,271	$510,109	$220,287	$410,664	$441,148
Change in Plan Assets
Fair value of assets at January 1	$1,200,035	$1,364,030	$354,928	$160,777	$339,126	$282,668
Actual return on plan assets	168,764	195,658	48,812	22,896	46,151	40,927
Employer contributions	60,008	55,443	12,601	4,567	4,997	16,145
Benefits paid (a)	(142,951)	(138,825)	(44,947)	(15,689)	(40,526)	(28,922)
Fair value of assets at December 31	$1,285,856	$1,476,306	$371,394	$172,551	$349,748	$310,818
Funded status	($453,526)	($450,965)	($138,715)	($47,736)	($60,916)	($130,330)
Amounts recognized in the balance sheet (funded status)
Non-current liabilities	($453,526)	($450,965)	($138,715)	($47,736)	($60,916)	($130,330)
Amounts recognized as regulatory asset
Net loss	$816,002	$766,099	$239,904	$91,991	$156,480	$212,062
Amounts recognized as AOCI (before tax)
Net loss	$—	$31,921	$—	$—	$—	$—

(a) Including settlement lump sum benefit payments of ($48.4) million at Entergy Arkansas, ($18.6) million at Entergy Louisiana, ($7.7) million at Entergy Mississippi, ($9.8) million at Entergy Texas, and ($236) thousand at System Energy.

The qualified pension plans incurred actuarial gains during 2021 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations and an actual return on assets exceeding the expected return on assets for 2021. The qualified pension plans incurred actuarial losses during 2020 primarily due to a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020.

Accumulated Pension Benefit Obligation

The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows:


			December 31,
			2021						2020
			(In Thousands)


Entergy Arkansas	$1,463,966	$1,617,858
Entergy Louisiana	$1,574,273	$1,753,980
Entergy Mississippi	$407,851	$466,497
Entergy New Orleans	$178,010	$201,159
Entergy Texas	$342,441	$379,050
System Energy	$366,920	$410,296

Other Postretirement Trusts


2021	Level 1		Level 2		Level 3	Total
	(In Thousands)
Equity securities:
Common collective trust (c)						$312,594
Fixed income securities:
U.S. Government securities	62,240	(b)	89,951	(a)	—	152,191
Corporate debt instruments	—		152,562	(a)	—	152,562
Registered investment companies	28,450	(d)	—		—	28,450
Other	—		72,059	(f)	—	72,059
Total investments	$90,690		$314,572		$—	$717,856
Other pending transactions						(25,897)
Plus: Other postretirement assets included in the investments of the qualified pension trust						79,360
Total fair value of other postretirement assets						$771,319


2020	Level 1		Level 2		Level 3	Total
	(In Thousands)
Equity securities:
Common collective trust (c)						$315,191
Fixed income securities:
U.S. Government securities	46,498	(b)	97,604	(a)	—	144,102
Corporate debt instruments	—		147,287	(a)	—	147,287
Registered investment companies	16,965	(d)	—		—	16,965
Other	—		60,219	(f)	—	60,219
Total investments	$63,463		$305,110		$—	$683,764
Other pending transactions						(21,931)
Plus: Other postretirement assets included in the investments of the qualified pension trust						76,033
Total fair value of other postretirement assets						$737,866

a.Certain fixed income debt securities (corporate, government, and securitized) are stated at fair value as determined by broker quotes.

b.Common stocks, certain preferred stocks, and certain fixed income debt securities (government) are stated at fair value determined by quoted market prices.

c.The common collective trusts hold investments in accordance with stated objectives. The investment strategy of the trusts is to capture the growth potential of equity markets by replicating the performance of a specified index. Net asset value per share of common collective trusts estimate fair value. Common collective trusts are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total.

d.Registered investment companies are money market mutual funds with a stable net asset value of one dollar per share. Registered investment companies may hold investments in domestic and international bond markets or domestic equities and estimate fair value using net asset value per share.

e.Certain of these registered investment companies are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total.

f.The other remaining assets are U.S. municipal and foreign government bonds stated at fair value as determined by broker quotes and quoted market values.

g.The unallocated insurance contract investments are recorded at contract value, which approximates fair value. The contract value represents contributions made under the contract, plus interest, less funds used to pay benefits and contract expenses, and less distributions to the master trust.

Estimated Future Benefit Payments

Based upon the same assumptions, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received over the next ten years for the Registrant Subsidiaries for their employees will be as follows:


Estimated Future Qualified Pension Benefits Payments	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Year(s)
2022	$107,542	$120,365	$33,459	$13,992	$31,134	$26,953
2023	$104,328	$118,289	$33,055	$13,677	$30,381	$25,985
2024	$104,606	$117,416	$32,711	$13,333	$28,661	$26,155
2025	$102,411	$116,610	$31,838	$13,146	$26,807	$25,203
2026	$101,144	$114,232	$31,708	$12,875	$26,983	$24,939
2027 - 2031	$487,637	$534,665	$143,052	$58,299	$114,747	$123,220


Estimated Future Non-Qualified Pension Benefits Payments	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Year(s)
2022	$248	$186	$190	$31	$3,080
2023	$383	$172	$422	$82	$441
2024	$324	$159	$504	$104	$420
2025	$689	$146	$486	$135	$398
2026	$143	$133	$412	$128	$428
2027 - 2031	$878	$503	$1,927	$782	$1,677

Estimated Future Other Postretirement Benefits Payments (before Medicare Part D Subsidy)

Entergy Arkansas

Entergy Louisiana

Entergy Mississippi

Entergy New Orleans

Entergy Texas

System Energy


	(In Thousands)
Year(s)
2022	$14,228	$15,845	$3,488	$2,449	$5,061	$2,828
2023	$13,652	$15,766	$3,550	$2,378	$4,998	$2,774
2024	$13,392	$15,404	$3,597	$2,288	$4,824	$2,668
2025	$13,021	$15,182	$3,657	$2,200	$4,686	$2,617
2026	$12,717	$14,868	$3,645	$2,096	$4,458	$2,511
2027 - 2031	$61,153	$70,094	$18,095	$9,058	$20,932	$12,474


Estimated Future Medicare Part D Subsidy	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Year(s)
2022	$35	$6	$14	$—	$—	$1
2023	$3	$5	$15	$—	$—	$1
2024	$4	$7	$16	$—	$—	$1
2025	$4	$8	$17	$—	$—	$—
2026	$5	$7	$18	$1	$—	$1
2027 - 2031	$27	$51	$104	$—	$—	$4

Contributions

The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their employees in 2022:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Pension Contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Other Postretirement Contributions	$517	$15,845	$130	$175	$66	$22

Actuarial Assumptions

The significant actuarial assumptions used in determining the pension PBO and the other postretirement benefit APBO as of December 31, 2021 and 2020 were as follows:


	2021	2020
Weighted-average discount rate:
Qualified pension	2.99% - 3.08% Blended 3.05%	2.60% - 2.83% Blended 2.77%
Other postretirement	2.94%	2.62%
Non-qualified pension	2.11%	1.61%
Weighted-average rate of increase in future compensation levels	3.98% - 4.40%	3.98% - 4.40%
Interest crediting rate	2.60%	2.60%
Assumed health care trend rate:


Pre-65	5.65%	5.87%
Post-65	5.90%	6.31%
Ultimate rate	4.75%	4.75%
Year ultimate rate is reached and beyond:
Pre-65	2032	2030
Post-65	2032	2028

The significant actuarial assumptions used in determining the net periodic pension and other postretirement benefit costs for 2021, 2020, and 2019 were as follows:


	2021	2020	2019
Weighted-average discount rate:
Qualified pension:
Service cost	2.81%	3.42%	4.57%
Interest cost	2.08%	2.99%	4.15%
Other postretirement:
Service cost	2.98%	3.27%	4.62%
Interest cost	1.86%	2.41%	4.01%
Non-qualified pension:
Service cost	1.48%	2.71%	3.94%
Interest cost	2.14%	2.25%	3.46%
Weighted-average rate of increase in future compensation levels	3.98% - 4.40%	3.98% - 4.40%	3.98%
Expected long-term rate of return on plan assets:
Pension assets	6.75%	7.00%	7.25%
Other postretirement non-taxable assets	6.00% - 6.75%	6.25% - 7.25%	6.50% - 7.50%
Other postretirement taxable assets	5.00%	5.25%	5.50%
Assumed health care trend rate:
Pre-65	5.87%	6.13%	6.59%
Post-65	6.31%	6.25%	7.15%
Ultimate rate	4.75%	4.75%	4.75%
Year ultimate rate is reached and beyond:
Pre-65	2030	2027	2027
Post-65	2028	2027	2026

With respect to the mortality assumptions, Entergy used the Pri-2012 Employee and Healthy Annuitant Tables with a fully generational MP-2020 projection scale, in determining its December 31, 2021 and 2020 pension plans’ PBOs and the Pri.H 2012 (headcount weighted) Employee and Healthy Annuitant Tables with a fully generational MP-2020 projection scale, in determining its December 31, 2021 and 2020 other postretirement benefit APBO.

Defined Contribution Plans

Entergy sponsors the Savings Plan of Entergy Corporation and Subsidiaries (System Savings Plan). The System Savings Plan is a defined contribution plan covering eligible employees of Entergy and certain of its subsidiaries. The participating Entergy subsidiary makes matching contributions to the System Savings Plan for all eligible participating employees in an amount equal to either 70% or 100% of the participants’

basic contributions, up to 6% of their eligible earnings per pay period. The matching contribution is allocated to investments as directed by the employee.

Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries VI (established in April 2007) and the Savings Plan of Entergy Corporation and Subsidiaries VII (established in April 2007) to which matching contributions are also made. The plans are defined contribution plans that cover eligible employees, as defined by each plan, of Entergy and certain of its subsidiaries.

Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries VIII (established January 2021) and the Savings Plan of Entergy Corporation and Subsidiaries IX (established January 2021) to which company contributions are made. The participating Entergy subsidiary makes matching contributions to these defined contribution plans for all eligible participating employees in an amount equal to 100% of the participants’ basic contributions, up to 5% of their eligible earnings per pay period. Eligible participants may also receive a discretionary annual company contribution up to 4% of the participant’s eligible earnings (subject to vesting).

The Registrant Subsidiaries’ 2021, 2020, and 2019 contributions to defined contribution plans for their employees were as follows:


Year	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$4,820	$6,678	$3,045	$1,140	$2,699
2020	$4,515	$6,518	$2,863	$1,115	$2,596
2019	$4,111	$5,641	$2,424	$882	$2,136

NOTE 12. STOCK-BASED COMPENSATION

Note 12 to the financial statements is not applicable to the Registrant Subsidiaries.

NOTE 13. BUSINESS SEGMENT INFORMATION

Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

NOTE 14. ACQUISITIONS

Acquisitions

Washington Parish Energy Center

In April 2017, Entergy Louisiana entered into an agreement with a subsidiary of Calpine Corporation for the construction and purchase of Washington Parish Energy Center, which consists of two natural gas-fired combustion turbine units with a total nominal capacity of approximately 361 MW. In November 2020,

Entergy Louisiana completed the purchase, as approved by the LPSC, of the Washington Parish Energy Center. The total investment including transmission and other related costs, is approximately $261 million, including a payment of $222 million to purchase the plant.

NOTE 15. RISK MANAGEMENT AND FAIR VALUES

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an

established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2021 is 2.25 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of December 31, 2021 is 10 months for Entergy Mississippi and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2021 is 33,083,500 MMBtu for Entergy, including 16,420,000 MMBtu for Entergy Louisiana, 16,017,800 MMBtu for Entergy Mississippi, and 645,700 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2021 is 57,836 GWh for Entergy, including 12,561 GWh for Entergy Arkansas, 25,973 GWh for Entergy Louisiana, 6,429 GWh for Entergy Mississippi, 2,643 GWh for Entergy New Orleans, and 10,003 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2021 and 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi and Entergy Texas as of December 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.


Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
2021
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana

Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas

Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans


Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant

2020
Assets:
Natural gas swaps and options	Prepayments and other	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana

Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas



Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	Entergy New Orleans

a.Represents the gross amounts of recognized assets/liabilities

b.Represents the netting of fair value balances with the same counterparty

c.Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

d.As of December 31, 2021 letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 million for Entergy Texas.

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows:

Instrument

Income Statement Location

Amount of gain (loss) recorded in the income statement

Registrant

(In Millions)

2021

Natural gas swaps and options

Fuel, fuel-related expenses, and gas purchased for resale

$12.6

(a)

Entergy Louisiana

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

$19.8

(a)

Entergy Mississippi

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

($0.1)

(a)

Entergy New Orleans

Financial transmission rights

Purchased power

$42.6

(b)

Entergy Arkansas

Financial transmission rights

Purchased power

$31.6

(b)

Entergy Louisiana

Financial transmission rights

Purchased power

$11.3

(b)

Entergy Mississippi

Financial transmission rights

Purchased power

$4.3

(b)

Entergy New Orleans

Financial transmission rights

Purchased power

$85.9

(b)

Entergy Texas

2020

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

($11.1)

(a)

Entergy Mississippi

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

($0.8)

(a)

Entergy New Orleans

Financial transmission rights

Purchased power

$26.7

(b)

Entergy Arkansas

Financial transmission rights

Purchased power

$19.6

(b)

Entergy Louisiana

Financial transmission rights

Purchased power

$3.0

(b)

Entergy Mississippi

Financial transmission rights

Purchased power

$1.4

(b)

Entergy New Orleans

Financial transmission rights

Purchased power

$40.4

(b)

Entergy Texas

2019

Natural gas swaps and options

Fuel, fuel-related expenses, and gas purchased for resale

($5.3)

(a)

Entergy Louisiana

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

($7.7)

(a)

Entergy Mississippi

Financial transmission rights

Purchased power

$22.3

(b)

Entergy Arkansas

Financial transmission rights

Purchased power

$46.7

(b)

Entergy Louisiana

Financial transmission rights

Purchased power

$6.8

(b)

Entergy Mississippi

Financial transmission rights

Purchased power

$2.7

(b)

Entergy New Orleans

Financial transmission rights

Purchased power

$15.7

(b)

Entergy Texas

a.Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

b. Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs

can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;

–quoted prices for identical assets or liabilities in inactive markets;

–inputs other than quoted prices that are observable for the asset or liability; or

–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume

specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value.

On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight. The values are calculated internally and verified against the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer. The Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2021 and December 31, 2020. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

Entergy Louisiana


2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$18.4	$—	$—	$18.4
Decommissioning trust funds (a):
Equity securities	20.2	—	—	20.2
Debt securities	262.6	531.6	—	794.2


Common trusts (b)				1,300.1
Gas hedge contracts	5.7	5.3	—	11.0
Financial transmission rights	—	—	0.6	0.6
	$306.9	$536.9	$0.6	$2,144.5


2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$726.7	$—	$—	$726.7
Decommissioning trust funds (a):
Equity securities	8.7	—	—	8.7
Debt securities	172.4	459.8	—	632.2
Common trusts (b)				1,153.1
Securitization recovery trust account	2.7	—	—	2.7
Gas hedge contracts	0.8	0.5	—	1.3
Financial transmission rights	—	—	4.2	4.2
	$911.3	$460.3	$4.2	$2,528.9

Liabilities:
Gas hedge contracts	$0.3	$1.3	$—	$1.6

a.The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements for additional information on the investment portfolios.

b. Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2021.


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)

Balance as of January 1, 2021	$2.7	$4.2	$0.6	$0.1	$1.6
Issuances of financial transmission rights	2.8	4.1	1.7	0.4	2.7
Gains (losses) included as a regulatory liability/asset	39.4	23.9	9.3	3.9	82.4
Settlements	(42.6)	(31.6)	(11.3)	(4.3)	(85.9)
Balance as of December 31, 2021	$2.3	$0.6	$0.3	$0.1	$0.8

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2020.


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)

Balance as of January 1, 2020	$3.3	$4.5	$0.8	$0.3	$0.9
Issuances of financial transmission rights	6.5	13.2	1.4	(0.1)	2.4
Gains (losses) included as a regulatory liability/asset	19.6	6.1	1.4	1.3	38.7
Settlements	(26.7)	(19.6)	(3.0)	(1.4)	(40.4)
Balance as of December 31, 2020	$2.7	$4.2	$0.6	$0.1	$1.6

NOTE 16. DECOMMISSIONING TRUST FUNDS

The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, and Grand Gulf. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents.

Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

Entergy Louisiana

Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2021 and 2020 are summarized as follows:


	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2021
Debt Securities	$794.2	$31.3	$3.3

2020
Debt Securities	$632.2	$51.3	$0.5

The amortized cost of available-for-sale debt securities was $766.3 million as of December 31, 2021 and $581.4 million as of December 31, 2020. As of December 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.30%, an average duration of approximately 6.83 years, and an average maturity of approximately 12.29 years.

The unrealized gains/(losses) recognized during the year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $249.4 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020:


	December 31, 2021		December 31, 2020
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)
Less than 12 months	$206.9	$1.4	$36.4	$0.5
More than 12 months	42.9	1.9	0.8	—
Total	$249.8	$3.3	$37.2	$0.5

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows:


	2021	2020
	(In Millions)
Less than 1 year	$—	$—
1 year - 5 years	157.8	117.0
5 years - 10 years	173.0	159.4
10 years - 15 years	123.0	101.2
15 years - 20 years	80.2	66.9
20 years+	260.2	187.7
Total	$794.2	$632.2

During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $303.4 million, $159.7 million, and $186 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $6.8 million, $8.1 million, and $4.8 million, respectively, and gross losses of $4.1 million, $0.7 million, and $0.3 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

NOTE 17. VARIABLE INTEREST ENTITIES

Note 17 to the financial statements is not applicable to the presentation of the FERC Form 1.

NOTE 18. TRANSACTIONS WITH AFFILIATES

Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive

management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis.

As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in Entergy’s money pool and earn interest income from the money pool. As described in Note 2 to the financial statements, Entergy Louisiana receives preferred membership interest distributions from Entergy Holdings Company.

The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates.

Intercompany Revenues


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Millions)
2021	$109.8	$289.9	$1.4	$—	$64.3	$545.6
2020	$105.2	$280.5	$1.2	$—	$40.4	$520.7
2019	$117.5	$277.8	$1.4	$—	$51.6	$584.1

Intercompany Operating Expenses


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Millions)
2021	$559.7	$755.2	$299.8	$287.8	$275.0	$190.8
2020	$515.5	$661.5	$283.3	$266.0	$260.3	$177.4
2019	$534.0	$665.4	$306.7	$292.1	$255.0	$156.2

Intercompany Interest and Investment Income


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
		(In Millions)

2021	$—	$127.6	$—	$—	$—	$—
2020	$—	$127.7	$0.1	$—	$—	$0.2
2019	$0.4	$128.5	$0.4	$—	$0.4	$1.0

NOTE 19. SUBSEQUENT EVENT

Management has evaluated the impact of events occurring after December 31, 2021 up to April 15, 2022, the date that Entergy Louisiana's FERC financial statements and disclosures were filed. These financial statements include all necessary adjustments and disclosures resulting from these evaluations.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote. Report data on a year-to-date basis.
Line No.	Item (a)	Unrealized Gains and Losses on Available-For-Sale Securities (b)	Minimum Pension Liability Adjustment (net amount) (c)	Foreign Currency Hedges (d)	Other Adjustments (e)	Other Cash Flow Hedges Interest Rate Swaps (f)	Other Cash Flow Hedges [Specify] (g)	Totals for each category of items recorded in Account 219 (h)	Net Income (Carried Forward from Page 116, Line 78) (i)	Total Comprehensive Income (j)
1	Balance of Account 219 at Beginning of Preceding Year		4,562,761					4,562,761
2	Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income		235,413					235,413
3	Preceding Quarter/Year to Date Changes in Fair Value
4	Total (lines 2 and 3)		235,413					235,413	1,082,351,807	1,082,116,394
5	Balance of Account 219 at End of Preceding Quarter/Year		4,327,348					4,327,348
6	Balance of Account 219 at Beginning of Current Year		4,327,348					4,327,348
7	Current Quarter/Year to Date Reclassifications from Account 219 to Net Income		3,950,868					3,950,868
8	Current Quarter/Year to Date Changes in Fair Value
9	Total (lines 7 and 8)		3,950,868					3,950,868	653,984,207	657,935,075
10	Balance of Account 219 at End of Current Quarter/Year		8,278,216					8,278,216

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION
Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.
Line No.	Classification (a)	Total Company For the Current Year/Quarter Ended (b)	Electric (c)	Gas (d)	Other (Specify) (e)	Other (Specify) (f)	Other (Specify) (g)	Common (h)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlantInServiceAbstract In Service
3	UtilityPlantInServiceClassified Plant in Service (Classified)	24,619,398,401	24,360,098,575	259,299,826
4	UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases	(a) 65,448,200	63,017,725	2,430,475
5	UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold
6	UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified	3,706,710,697	3,683,393,599	23,317,098
7	UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified
8	UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7)	28,391,557,298	28,106,509,899	285,047,399
9	UtilityPlantLeasedToOthers Leased to Others
10	UtilityPlantHeldForFutureUse Held for Future Use	1,082,682	1,082,682
11	ConstructionWorkInProgress Construction Work in Progress	851,178,196	850,717,421	460,775
12	UtilityPlantAcquisitionAdjustment Acquisition Adjustments	141,561,725	141,561,725
13	UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12)	29,385,379,901	29,099,871,727	285,508,174
14	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion	(b) 9,190,174,494	(d) 9,064,787,159	125,387,335
15	UtilityPlantNet Net Utility Plant (13 less 14)	20,195,205,407	20,035,084,568	160,120,839
16	DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17	AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service:
18	DepreciationUtilityPlantInService Depreciation	8,476,383,094	(e) 8,365,964,382	110,418,712
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	674,837,783	(f) 659,869,160	(h) 14,968,623
22	DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21)	9,151,220,877	9,025,833,542	125,387,335
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	207	207
29	AmortizationUtilityPlantHeldForFutureUse Amortization
30	DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29)	207	207
31	AbandonmentOfLeases Abandonment of Leases (Natural Gas)
32	AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment	38,953,410	38,953,410
33	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32)	(c) 9,190,174,494	(g) 9,064,787,159	125,387,335

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: UtilityPlantInServicePropertyUnderCapitalLeases

Includes Operating Leases recorded in accordance with FASB ASU No. 2016-02, Leases, as provided for in FERC Docket No. AI19-1-000.

(b) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility

Includes a debit balance for removal costs of $848,242,785.

(c) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility

Includes a debit balance for removal costs of $848,242,785.

(d) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility

Includes a credit balance of $153,184,648 accumulated depreciation for ARO assets.

(e) Concept: DepreciationUtilityPlantInService

Includes a credit balance of $153,184,648 accumulated depreciation for ARO assets.

(f) Concept: AmortizationOfOtherUtilityPlantUtilityPlantInService

Includes a credit balance of $665,353,585 of accumulated provision for amortization pertaining to intangible assets.

(g) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility

Includes a credit balance of $153,184,648 accumulated depreciation for ARO assets.

(h) Concept: AmortizationOfOtherUtilityPlantUtilityPlantInService

Includes a credit balance of $14,967,062 of accumulated provision for amortization pertaining to intangible assets.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No.	Description of item (a)	Balance Beginning of Year (b)	Changes during Year Additions (c)	Changes during Year Amortization (d)	Changes during Year Other Reductions (Explain in a footnote) (e)	Balance End of Year (f)
1	Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1)
2	Fabrication
3	Nuclear Materials	27,191,854	57,354,085		(b) 30,957,844	53,588,095
4	Allowance for Funds Used during Construction	50,668	1,333,482		(c) 1,293,856	90,294
5	(Other Overhead Construction Costs, provide details in footnote)
6	SUBTOTAL (Total 2 thru 5)	27,242,522				53,678,389
7	Nuclear Fuel Materials and Assemblies
8	In Stock (120.2)
9	In Reactor (120.3)
10	SUBTOTAL (Total 8 & 9)
11	Spent Nuclear Fuel (120.4)
12	Nuclear Fuel Under Capital Leases (120.6)	(a) 168,249,152	69,953,167	93,681,759		(d) 144,520,560
13	(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)	14,636,665	3,985,440	7,403,504		11,218,601
14	TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)	210,128,339				209,417,550
15	Estimated Net Salvage Value of Nuclear Materials in Line 9
16	Estimated Net Salvage Value of Nuclear Materials in Line 11
17	Est Net Salvage Value of Nuclear Materials in Chemical Processing
18	Nuclear Materials held for Sale (157)
19	Uranium
20	Plutonium
21	Other (Provide details in footnote)
22	TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21)

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: NuclearFuelUnderCapitalLeases

As of December 31, 2021, arrangements to lease nuclear fuel existed in an aggregate amount up to $300 million for Entergy Louisiana, LLC. The lessors finance the acquisition and ownership of nuclear fuel through loans made under revolving credit agreements, the issuance of commercial paper, and the issuance of intermediate-term notes. The credit agreement for Entergy Louisiana has a termination date of June 10, 2024. The termination dates may be extended from time to time with the consent of the lenders. The intermediate-term notes issued pursuant to these fuel lease arrangements have varying maturities through June 15, 2027. It is expected that additional financing under the leases will be arranged as needed to acquire additional fuel, to pay interest, and to pay maturing debt. However, if such additional financing cannot be arranged, the lessee in each case must repurchase sufficient nuclear fuel to allow the lessor to meet its obligations in accordance with the fuel lease.

(b) Concept: NuclearMaterialsNuclearFuelInProcessOfRefinementConversionEnrichmentAndFabricationOtherReductions

Withdrawals and allocation adjustments related to the regulated nuclear pool.

(c) Concept: AllowanceForFundsConstructionNuclearFuelInProcessOfRefinementConversionEnrichmentAndFabricationOtherReductions

Withdrawals and allocation adjustments related to the regulated nuclear pool.

(d) Concept: NuclearFuelUnderCapitalLeases

FUEL LEASE FOR WATERFORD AND RIVER BEND

LESSOR: RIVER BEND FUEL SERVICES INC. AND RIVER FUEL COMPANY #2

Investment of River Bend Fuel Services, Inc. & River Fuel Company #2 Lease at December 31, 2021


Investment at December 31,2020			$168,249,152

Additional investment in fuel			69,647,496

Daily lease charges allocated to and included in capitalized costs			305,671

Less: Burn-up charges paid to lessor			93,681,759

Total Investment at December 31, 2021			$144,520,560


Costs Incurred under River Bend Fuel Services Inc. and River Fuel Company #2 Lease for the Year Ended December 31, 2021
Daily Lease Charges			$5,549,768

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
Report below the original cost of electric plant in service according to the prescribed accounts. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of the prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No.	Account (a)	Balance Beginning of Year (b)	Additions (c)	Retirements (d)	Adjustments (e)	Transfers (f)	Balance at End of Year (g)
1	1. INTANGIBLE PLANT
2	(301) Organization	7,357,399					7,357,399
3	(302) Franchise and Consents	19,712					19,712
4	(303) Miscellaneous Intangible Plant	987,815,834	68,286,320	142,956			1,055,959,198
5	TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)	995,192,945	68,286,320	142,956			1,063,336,309
6	2. PRODUCTION PLANT
7	A. Steam Production Plant
8	(310) Land and Land Rights	6,479,958		892			6,479,066
9	(311) Structures and Improvements	152,104,796	4,316,958	798,353			155,623,401
10	(312) Boiler Plant Equipment	623,003,529	15,074,682	4,734,776			633,343,435
11	(313) Engines and Engine-Driven Generators		14,003,798	6,050,299			7,953,499
12	(314) Turbogenerator Units	368,205,665	5,502,141	1,217,420			372,490,386
13	(315) Accessory Electric Equipment	149,900,716	941,024	80,847			150,760,893
14	(316) Misc. Power Plant Equipment	24,396,221					24,396,221
15	(317) Asset Retirement Costs for Steam Production	2,510,653					2,510,653
16	TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)	1,326,601,538	39,838,603	12,882,587			1,353,557,554
17	B. Nuclear Production Plant
18	(320) Land and Land Rights	9,404,991					9,404,991
19	(321) Structures and Improvements	2,481,469,400	6,143,822	2,435,331			2,485,177,891
20	(322) Reactor Plant Equipment	2,615,157,095	28,240,971	6,201,475			2,637,196,591
21	(323) Turbogenerator Units	864,071,912	11,315,607	3,446,962			871,940,557
22	(324) Accessory Electric Equipment	1,363,441,415	32,096,787	2,588,063			1,392,950,139
23	(325) Misc. Power Plant Equipment	483,962,209	18,040,706	1,309,249			500,693,666
24	(326) Asset Retirement Costs for Nuclear Production	469,801,266					469,801,266
25	TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)	8,287,308,288	95,837,893	15,981,080			8,367,165,101
26	C. Hydraulic Production Plant
27	(330) Land and Land Rights
28	(331) Structures and Improvements
29	(332) Reservoirs, Dams, and Waterways
30	(333) Water Wheels, Turbines, and Generators
31	(334) Accessory Electric Equipment
32	(335) Misc. Power Plant Equipment
33	(336) Roads, Railroads, and Bridges
34	(337) Asset Retirement Costs for Hydraulic Production
35	TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)
36	D. Other Production Plant
37	(340) Land and Land Rights	12,683,666					12,683,666
38	(341) Structures and Improvements	730,022,342	2,053,792	672,628		4	731,403,510
39	(342) Fuel Holders, Products, and Accessories	266,745,630	181,822,417	171,959		7	84,751,261
40	(343) Prime Movers	1,541,893,155	575,832,062	6,313,472		18,469,583	2,129,881,328
41	(344) Generators	979,805,521	296,685,286	4,867,268		22,969,892	655,283,075
42	(345) Accessory Electric Equipment	356,606,590	1,978,602	954,013		3,673,203	350,000,772
43	(346) Misc. Power Plant Equipment	34,911,190	15,306,654	99,906		2	19,504,632
44	(347) Asset Retirement Costs for Other Production
44.1	(348) Energy Storage Equipment - Production
45	TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)	3,922,668,094	82,092,895	13,079,246		8,173,499	3,983,508,244
46	TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)	13,536,577,920	217,769,391	41,942,913		8,173,499	13,704,230,899
47	3. Transmission Plant
48	(350) Land and Land Rights	286,855,655	18,071,174				304,926,829
48.1	(351) Energy Storage Equipment - Transmission
49	(352) Structures and Improvements	207,935,699	14,558,539	365,955			193,011,205
50	(353) Station Equipment	2,106,297,944	109,612,570	9,537,803		12,339,097	2,218,711,808
51	(354) Towers and Fixtures	189,241,027	377,522	2,271,810			187,346,739
52	(355) Poles and Fixtures	1,321,339,847	333,154,182	15,499,302			1,638,994,727
53	(356) Overhead Conductors and Devices	892,112,904	122,266,945	9,562,339		1,013,491	1,005,831,001
54	(357) Underground Conduit	1,798,563					1,798,563
55	(358) Underground Conductors and Devices	4,981,330				572,807	5,554,137
56	(359) Roads and Trails	6,248,115					6,248,115
57	(359.1) Asset Retirement Costs for Transmission Plant
58	TOTAL Transmission Plant (Enter Total of lines 48 thru 57)	5,016,811,084	568,923,854	37,237,209		13,925,395	5,562,423,124
59	4. Distribution Plant
60	(360) Land and Land Rights	39,091,229	4,959,195				44,050,424
61	(361) Structures and Improvements	70,480,681	3,111,257	246,630			73,345,308
62	(362) Station Equipment	863,339,970	73,681,220	8,961,483		5,833,332	922,226,375
63	(363) Energy Storage Equipment – Distribution
64	(364) Poles, Towers, and Fixtures	706,506,259	425,424,984	11,981,226			1,119,950,017
65	(365) Overhead Conductors and Devices	1,010,118,108	450,925,728	15,825,397			1,445,218,439
66	(366) Underground Conduit	225,883,388	19,369,067	110,476			245,141,979
67	(367) Underground Conductors and Devices	304,677,804	60,950,776	1,568,178		81,436	364,141,838
68	(368) Line Transformers	1,242,585,500	416,961,317	9,896,878			1,649,649,939
69	(369) Services	606,648,905	56,733,869	1,057,517			662,325,257
70	(370) Meters	288,555,258	120,441,441	2,272,388		1,070,959	407,795,270
71	(371) Installations on Customer Premises	191,001,293	15,597,627	2,073,717			204,525,203
72	(372) Leased Property on Customer Premises		20,171,249	2,639,390			17,531,859
73	(373) Street Lighting and Signal Systems	154,816,239					154,816,239
74	(374) Asset Retirement Costs for Distribution Plant
75	TOTAL Distribution Plant (Enter Total of lines 60 thru 74)	5,703,704,634	1,668,327,730	56,633,280		4,680,937	7,310,718,147
76	5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77	(380) Land and Land Rights
78	(381) Structures and Improvements
79	(382) Computer Hardware
80	(383) Computer Software
81	(384) Communication Equipment
82	(385) Miscellaneous Regional Transmission and Market Operation Plant
83	(386) Asset Retirement Costs for Regional Transmission and Market Oper
84	TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85	6. General Plant
86	(389) Land and Land Rights	11,876,589		7,699			11,868,890
87	(390) Structures and Improvements	170,655,680	14,529,133	1,405,894			183,778,919
88	(391) Office Furniture and Equipment	55,670,862	19,742,188	65,470		1,070,959	74,276,621
89	(392) Transportation Equipment	214,700	639,946				854,646
90	(393) Stores Equipment	265,560	127,419				392,979
91	(394) Tools, Shop and Garage Equipment	25,503,259	2,722,160				28,225,419
92	(395) Laboratory Equipment	4,128,913					4,128,913
93	(396) Power Operated Equipment	1,307,490	182,174				1,489,664
94	(397) Communication Equipment	81,686,719	10,661,403				92,348,122
95	(398) Miscellaneous Equipment	4,988,920	192,218	17,276			5,163,862
96	SUBTOTAL (Enter Total of lines 86 thru 95)	356,298,692	48,796,641	1,496,339		1,070,959	402,528,035
97	(399) Other Tangible Property	255,660					255,660
98	(399.1) Asset Retirement Costs for General Plant
99	TOTAL General Plant (Enter Total of lines 96, 97, and 98)	356,554,352	48,796,641	1,496,339		1,070,959	402,783,695
100	TOTAL (Accounts 101 and 106)	25,608,840,935	2,572,103,936	137,452,697			28,043,492,174
101	(102) Electric Plant Purchased (See Instr. 8)
102	(Less) (102) Electric Plant Sold (See Instr. 8)
103	(103) Experimental Plant Unclassified
104	TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)	25,608,840,935	(a) 2,572,103,936	137,452,697			28,043,492,174

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: ElectricPlantInServiceAdditions

The negative project additions include reversal credits from prior year additions for unclassified project costs closed to plant in service.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No.	LesseeName Name of Lessee (a)	IndicationOfAssociatedCompany * (Designation of Associated Company) (b)	LeaseDescription Description of Property Leased (c)	CommissionAuthorization Commission Authorization (d)	ExpirationDateOfLease Expiration Date of Lease (e)	ElectricPlantLeasedToOthers Balance at End of Year (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47	TOTAL

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No.	ElectricPlantHeldForFutureUseDescription Description and Location of Property (a)	ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate Date Originally Included in This Account (b)	ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate Date Expected to be used in Utility Service (c)	ElectricPlantHeldForFutureUse Balance at End of Year (d)
1	Land and Rights:
2	Nelson To Richard 500Kv Ln	12/31/1996		882,727
3	Land and land rights under $250k			199,955
21	Other Property:
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47	TOTAL			1,082,682

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
Report below descriptions and balances at end of year of projects in process of construction (107). Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts). Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No.	ConstructionWorkInProgressProjectDescription Description of Project (a)	ConstructionWorkInProgress Construction work in progress - Electric (Account 107) (b)
1	2021_IMPROVE_F0936_INSPECTION FORM-	1,203,744
2	Briarwood Sub-2020-Feeder2	953,603
3	KANSAS LN, CITY PART, MONROE, N4164	852,464
4	DIST CUSTOMER REQUEST BLKT ELA-EGSL	843,462
5	GS20-004V Grayson- Columbia Sub-REP 1	712,200
6	Briarwood-Feeder 3-Project 5 TIGER	654,127
7	N0155, ATHENS,PHASE 5 RECON & NEW B	642,401
8	Printed JMCBETH 5-17-21	624,095
9	IMPROVE-2021-F0936-CBKR F0936-FEEDE 1	595,112
10	IMPROVE, WM19-001S, N5208,WEST MONR	578,957
11	Improve-2021-Chackbay Sub-New FDR 3	510,780
12	FO21 FOCUS 201AD L16522	510,306
13	Highway Kansas Lane : State Part Mo	501,696
14	MIDDLEBROOK SUBD.	500,478
15	IMPROVE-2021-F0936-CBKR F0936-FEEDE 2	479,872
16	LA FEEDER INVESTMENT 2021 GN 833GN 1	460,441
17	N0306 PROJECT, SAREPTA, PHASE 1	454,479
18	FOCUS, N0303, SAREPTA, SBKR	452,574
19	Recable : West Monroe N1819, N1820	452,154
20	RELIAB - Target Device Reliability	451,635
21	ADDIS REPLACE T5 INST MAIN FEEDER	406,882
22	FLI , SAREPTA N0306, PHASE 4_Part 1	385,542
23	RELIAB: INDEPENDENCE, G0623, L4154,	383,851
24	IMPROVE, WM17-010S, N3756, FAIRBANK	375,354
25	FC21 FOCUS H0915 L0532	361,195
26	IMPROV WEST MONROE N5103 (Part 5 OF	333,489
27	RELIABILITY BASTROP N3554 DEVICE ID	330,057
28	CUSTOMR - Customer Requested Projec	328,923
29	IMPROVE, WM19-001S, WEST MONROE, C	313,440
30	FOCUS FC21L130 N4903 DEVICE 46346	304,902
31	GS20-004V Grayson- Columbia Sub-Reb	300,815
32	FO21 FOCUS 305LV L77232	297,062
33	Briarwood Sub-2020-Feeder2-Project4 1	280,516
34	FAILCBL RE B0625 BORE IN B PHASE LO	279,382
35	FLI SAREPTA N0306, PHASE 4_Part 5 o	268,663
36	Ouachtia River Crossing Rebuild in	263,318
37	SUGARMILL 15TH PH. 1	260,444
38	FOCUS_FC21L125_Y3713_Y3713	256,869
39	SUGAR MILL SPLIT LOOP	253,215
40	FC21L143, FOCUS, N4073, HOMER, SBKR	250,171
41	Improve, 753CE,HND, Build new feede	246,545
42	CHEVAL TRAILS SUBD.	246,458
43	2021 Q2 Focus Project, Number FC21L	243,756
44	GS20-003V Grayson- Standard Sub-Bui	240,723
45	LA FEEDER INVESTMENT 2021 BR 325HR 1	239,367
46	REV-WK-W0512-BELLE CHASSE-INSTALL U	236,382
47	BELLACOSA 3RD FILING	229,037
48	DA STRATEGIC-ELL-COTEAU-SCHREV-SLAN 1	227,439
49	WM17-005A- Drew N3103 Build 1.2 mil	227,377
50	2021 - IMPROVE - AM20-006A - H0915	224,937
51	REVENUE:N4302: SCRAP/INSTALL NEW PR	211,317
52	BRIAR COVE PHASE 2 REV,LAF,760AV	209,387
53	Rev: Weyerhaeuser Holden LA - Build 1	205,942
54	Improve: Fairbanks Substation Railr	203,687
55	TV 28 VAULT	201,617
56	Improve-2021-Chackbay Feeder 1 Exit	199,361
57	BA20-002V- Bastrop- Rebuild .47 mil	191,841
58	Reliab: Reconduct from recloser L96	187,207
59	LA FEEDER INVESTMENT 2021 BR 325HR 2	180,867
60	360 hrs. TV VAULT 07 XFMR CHANGE-OU	180,043
61	FC21 FOCUS K0531 BREAKER	178,989
62	Briarwood-Feeder 2-Project 4	178,505
63	T & D PROJECT VACHERIE SUBSTATION	178,467
64	URD REV Isle of Capri (UG) - 100 We	178,172
65	tv- 12 XFMR REPLACEMENT	176,645
66	Pierre Part Y3112 Highway 70 Plann	175,123
67	Briarwood Sub-2020-Feeder1234-Proje 1	173,813
68	REVENUE HOUMA Y3517 UPGRADE FACILIT	171,453
69	IMPROVE - 2021 - 718ZO - BR17-012B	171,199
70	Briarwood Sub-2020-Feeder1234-Proje 2	168,923
71	FC21 FOCUS 304TI L27014 preventive	168,049
72	IMPROVE_2020_ZA20-003A_826ZA	165,831
73	1201.07 HRS - REV 2020 BEDICO CREEK	160,923
74	FC21 FOCUS 726GR RL0733	159,548
75	ARC ELAS_1713 L6045 HWY 1064 TO MOR	158,625
76	BA20-002V- Bastrop- Remove .79 mile	157,697
77	RECABLE MONROE N5006 3PH PRI BORE A	157,282
78	Recable: N1806 Replace Underground	154,958
79	FC21 FOCUS G0623 L5327	154,248
80	DA STRATEGIC-ELL-COTEAU-SCHREV-SLAN 2	150,923
81	FC21 FOCUS K0613 RECLOSER L6232	149,822
82	Briarwood Sub-2020-Feeder2-Project4 2	145,249
83	Rel N5355 Dunn 3 PH PRI Substation	142,674
84	DA STRATEGIC-ELL-COTEAU-SCHREV-SLAN 3	138,096
85	URD REV Isle of Capri (Bore) - 100	136,837
86	N0306 PROJECT, SAREPTA, PHASE 2 PAR	136,513
87	LAKE VILLA CROSSING	135,746
88	IMPROV PLANNING PROJECT 3PH PRI REC	133,668
89	Briarwood Sub-2020-Feeder3-Project5	133,627
90	SECTION - N3353 - GRAMBLING/RUSTON	133,134
91	FOCUS - Focus 706LV BEHIND L23035	131,588
92	INSTALL RECLOSERS, ANTENNAS, AND CO	130,165
93	STORM DMG LA EGSL 10/27/21-10/29/21	128,645
94	FLI SAREPTA N0306, PHASE 4_Part 3 o	127,311
95	SECTION MONROE N4206/N5059 3PH PRI	125,193
96	FC21L139 FOCUS JULIA 235-BREAKER	123,931
97	FO21 FOCUS 312SR RL0223	123,863
98	760AV: IN 3-333 KVA REGS ON HWY 192	122,855
99	FLI SAREPTA N0306 PHASE 7- Remainin	122,411
100	FO21 FOCUS 291DR	122,214
101	Improve-2021-Chackbay Sub-FDR 2 Par	121,303
102	LA FEEDER INVESTMENT 2021 TERREBONN	120,890
103	DA Strategic-ELL-RUSAGE-SELMAN-RL09	120,485
104	THE GROVE TOWN HOMES	120,051
105	DA Strategic-ELL-REI-61REI-62REI-R0	119,031
106	61.50 hrs. IBM BLDG- TRIDENT SWITCH	118,038
107	61.50 hrs. KRESS BLDG- TRIDENT SWIT	118,038
108	FC20G002 FOCUS F0938 SBKR	117,612
109	210 hrs. FC21 FOCUS 694BL	116,508
110	GS20-004V Grayson- Columbia Sub-REP 2	116,040
111	FO21 FOCUS 710CH L29026	115,631
112	260.5 Hrs N. O. AIRPORT FLYOVER UG	115,255
113	207.3 hrs. TV11 XFMR CHANGEOUT	114,167
114	207.3 hrs. TV-08 XFMR CHANGE- OUT	114,167
115	TV10 XFMR CHANGE-OUT	114,167
116	IMPROVE 2020 X3612 BORE NEW SUBMARI	113,541
117	FC21L153-FOCUS-X9743-D01658 [Duplic	112,812
118	DA Strategic-ELL-JENA_STNARD Device	112,159
119	RELIAB RECONDUCTOR 846DH/847DH [Dup	112,114
120	RELIABILITY FIRETOWER RD	112,008
121	TV03 XFMR CHANGE-OUT	109,662
122	DA Strategic-ELL-SLC-190SL-191SL-RL	108,893
123	IMPROVE MAURICE 851MA - RECON ALONG	108,393
124	181.21 hrs. INSTALL 3 PHASE POWER L	106,603
125	FOCUS_FC21L015_W0512_SBKR W0512	105,414
126	LA FEEDER INVESTMENT 2021 GN 833GN 2	104,170
127	Rev: Weyerhaeuser Holden LA - Build 2	103,726
128	MIRAVAL PH. B	103,245
129	SECTION IPO INSTALLATION RED GUM SU	102,813
130	N0155, ATHENS,PHASE 1 RECON & NEW B	102,381
131	Regulators, Oakville w3112, r1275	102,115
132	Other Distribution lines	11,360,202
133	Hurricane Ida LA Storm Accrual	214,473,607
134	Asset Suite/AIMM Repl - Supply Chai	12,645,404
135	Asset Suite/AIMM Repl - Nuclear	9,847,976
136	Asset Suite/AIMM Repl - Nuclear RBS	4,512,223
137	Jeff Hwy Consolidation	3,888,190
138	AMI - DMS/OMS - Software - Rel 4-5	2,853,900
139	Endevor ER Software	1,780,692
140	BRO - Technology Center Design	1,129,495
141	INF21: Lacassine Laydown Yard	969,799
142	Power Generation Fleet Training Pla	883,377
143	PRA REV7 MODEL & APPLICATION UPDATE	783,020
144	Renovate Lafayette Service Ctr	768,919
145	Utility Data Warehouse Plus	660,207
146	SAISO Replacement	631,368
147	AMI Sales and Rev BIE	627,759
148	CSD Workforce Management System	592,539
149	Digital LIHEAP	473,319
150	SW2 - EDE-Bill Syst Contr Repo Inte	458,372
151	ServiceNow Enhancements	454,897
152	Broussard Roof Upgrades	427,533
153	Advanced DMS	322,380
154	Hammond Distribution Center Storm	279,233
155	Environmental Safety MgmtContract	238,214
156	SW-Network Access Control Authentic	186,613
157	WF3-Nuc. WL Refresh 2020	182,284
158	Choctaw Lineman&Storm Room Renovate	164,878
159	SW-Facilities Ratings WS-NERC Rep	159,148
160	Salesforce Bill Projection	157,622
161	SOFTWARE AND SERVICES FOR PRC002	153,269
162	Airsweb Replacement AVA Cloud	147,931
163	Deposit before Service - E and G	145,794
164	MT1 repairs for Hurricane Ida	145,639
165	IDM Hub Phase II Expansion-ALERT	119,576
166	Weblogic Portal Applications Upgrad	117,506
167	BDEx Expansion BDX - 21/22	113,135
168	SCO LA Warehouse 2019	111,550
169	STLF Work Order for AA Use Case	107,993
170	Meter Data Classification	105,686
171	St Rosalie Building Storm Repairs	102,124
172	Workforce Planning Tool	101,009
173	Other general and intangible plant	937,972
174	Waterford 3 CPC/CEAC Safety Repl.	58,910,182
175	Waterford 3 Feedring Modification	26,800,109
176	Replace MCC-315A & MCC-315B outdoor	15,282,385
177	MAIN CONDENSER TUBE BUNDLE REPL	14,785,581
178	CEA Replacements	9,734,967
179	MSB Hurricane Ida Restoration	7,954,430
180	Implement Risk Informed Tech Spec	7,783,993
181	License Renewal Implementation	7,507,658
182	FEEDWATER LEVEL CONTRL DIGITAL UPGD	6,316,005
183	UtilityNEXT ELA Power Barge	5,513,136
184	Weir Wall Replacement	5,326,943
185	DEH Control System Repl	4,837,151
186	MN GEN ALTERREX EXCTR VLT REG UPGRD	4,798,962
187	ELA WPEC Capital Additions	4,124,545
188	ESFAS Actuation Relay Redundancy	3,588,151
189	LQ1 - Administration Building Const	3,547,022
190	Main Generator Blower Shroud Upgrde	3,356,637
191	Pressurizer Heater Replacement	2,852,100
192	Electrical Distribution Improvement	2,639,253
193	REPL RWCU NON-REGNERTVE HEAT EXCHGR	2,255,493
194	LICENSE RENEWAL PROJECT PHASE 2	2,096,701
195	SPV Elimination: Generator and Tran	1,913,133
196	5TH PT HEATER A (CNM-E5A) REPL	1,843,423
197	Indoor Firing Range	1,799,850
198	Permanent Backup Fire Pump Rplc	1,726,175
199	WF3 Enhance EDG Performance Monitor	1,568,241
200	Dolphin #8 Replacement	1,355,656
201	LOWER FUEL STORAGE PLATFORM UPGRADE	1,332,205
202	Voltage Regulator (Main Generator)	1,320,713
203	Replace Roofing on GSB	1,249,502
204	Polar Crane Upgrade	1,238,651
205	Transfer Tube Quick Closure Device	1,178,967
206	UP3 3B 3C Generator Breaker Install	1,146,434
207	West Side Access Storm Damage Repai	1,102,588
208	CONTNMNT/EXHST AIR ISOLATION VALVES	1,080,172
209	HI-STORM FW Transition Equipment	1,077,771
210	Purchase 2nd Spare Main Transformer	1,069,660
211	RP Instrumentation Rplc. - Ida	979,550
212	ELGAR POWER LINE CONDITIONERS REPL	933,833
213	SI-512A Replacement	929,076
214	St. Charles Power Station Developmt	888,871
215	SPO ELL St.Jacques Transact/Trnstn	857,254
216	Refurbish PM Steam Gen and Snubbers	846,335
217	RF24 Turbine Valve Refurbishment	842,429
218	PWR Incores RF24	807,131
219	Replace Roofing on Polisher Buildin	732,245
220	Modify/Replace Essential Chiller	658,320
221	Pump Vibration Monitoring Equipment	637,350
222	PV1 Bailey DCS Hardware Replacement	601,508
223	Replace ACC-126 A and B	594,356
224	Allen Bradley Relay Replacement	548,524
225	SIMULATOR SOFTWARE UPGRD PHASE 1&2	540,802
226	7B Warehouse Roof Replacement	518,159
227	Turbine Lift Oil Line Break	505,010
228	CNTNMNT UNIT COOLR SPARE REPL PARTS	423,793
229	NP4 Air Pre-Heater Hot and Cold End	418,069
230	SPENT FUEL POOL FLTR BYPSS VLV REPL	410,249
231	TGB Lighting Upgrade	386,166
232	Intake Gantry Crane Controls Upgrad	381,504
233	LLRW Bldg Hurricane Ida Restoration	312,203
234	Repl Diesel and Add Manual Switch	312,172
235	NL6 Purchase Spare BWCP-Motor Assem	310,435
236	BC2U3 - Rpl SAH Hot & Interm Basket	307,103
237	Replace current Supplementary chill	295,209
238	Replace EOF EDG	281,686
239	RBS HOTLINE PHONE SYSTEM REPLACEMNT	257,497
240	SECURITY THERMAL OPTIC PURCH	256,325
241	Replace RCP Speed Sensor	253,859
242	SP1 - Circulating Water Pump Capit	243,800
243	MFIV #1 Nitrogen Leak	238,909
244	CFFF FLOW CNTRL VLV/FILL VLV IMPRV	223,671
245	MWS CABLE REPL	214,498
246	LQ1 WTR21 Wind breaks for winteriza	211,179
247	HVN CHILERS PRMNT CLN-UP KIT INSTAL	203,450
248	LUBE OIL STORAGE BUILDING UPGRADE	186,878
249	RF23 FAC Piping Replacement	181,889
250	Fire Brigade Safety Equipment	181,341
251	FEEDWATER SPARE MOTOR FWS-P1X REFB	179,662
252	UP4 - 4B & 4C Generator Sync Breake	177,717
253	EXTENDED DRY FUEL STORAGE SLAB	172,460
254	Svc. Bldg Hurricane Ida Restoration	169,349
255	LICENSE RENEWAL PROJECT PHASE 3	167,723
256	RF22 RECIRC MTR B33-PC001A RFRB/RPL	161,389
257	5B Warehouse Roof Replacement	149,448
258	JWL 1B BFWP A refurbishment	149,026
259	Seismic Monitoring Equipment	148,445
260	NL6 Purchase Spare Circ Water Pump	146,498
261	LAS 8 Stage Element Purchase	141,787
262	Hydrolasing Equipment & Training	141,623
263	2B Warehouse Roof Replacement	126,443
264	REACTOR CORE MONITORING SYS REPL	124,700
265	CEDMCS System Upgrade	116,929
266	CONDENSATE DEMIN LINING CHANGE	113,682
267	TORQUE CALIBRATION EQUIP PURCH	109,042
268	SERVICE BLDG FLOORING/STAIRWELL UPG	106,495
269	APPENDIX R LED LIGHT FIXTURE UPGRD	106,029
270	NP5 Condenser Monitoring System (CM	105,893
271	NPB Aux Boiler Heat Tracing Install	105,062
272	LICENSE AMNDMNT-ADOPT TSTF-505	105,001
273	NP5 CWP Motor 5W Power Cable Replac	102,506
274	ALPHA/BETA CONTINUOUS AIR MNTR PRCH	101,774
275	GENERATOR ROTOR REWIND	101,485
276	Other Production Plant	2,738,021
277	Goos Ferry: Build New 230kV D Sub	15,157,815
278	Munster 230kV: Bld New Sub	13,754,441
279	Selman Field 115/230kV Sub	8,039,240
280	Air Liquide: Sugar House 230kV Sub	6,914,432
281	Chackbay 230/13.8kV Build New Sub	5,818,037
282	Michigan Sub 203kV Cut In	4,626,173
283	Belle Point 115kV Reliability Upgra	4,546,766
284	Big Lake 230kV Sub	3,310,583
285	Nelson Substation	2,691,189
286	Conrad - Install New 138kV Ln Brkr	2,070,070
287	Lake Charles Bulk Replace T2	1,956,636
288	Culicchia Sub: Scoping	1,719,757
289	St. James to Welcome 230kV Line	1,643,012
290	Install E-5238 at Louisiana Sub	1,549,141
291	Pecue Add (2) 230kV breakers	942,247
292	Thompson Rd Build New Sub	900,762
293	Mud Lake: Add 230kV Line Bay Brkr	682,572
294	Lone Star Cement: Replace T1	657,177
295	Fancy Point: Rplc N. Bus Diff Panel	618,323
296	Leeville Sub - Generator Interconne	585,995
297	Waterford: Expand 230kV Switchyard	562,602
298	Pecue add (2) line relay panels	543,263
299	ELA: 69x34.5-13.8kV \| 25MVA Reigel	531,462
300	ELA: 230 x 115 - 34.5kV \| 67MVA LTC	503,432
301	ELL: 69-13.8\|33MVA (Highland)	481,749
302	Patton 230kV XMFR and Feeder Add	473,434
303	Graywood 230kV Sub	465,013
304	Nelson 230/138kV Relay Imprv SPOF	459,882
305	Citcon West: T-2 XMFR Replacement	459,019
306	Fancy Point: Rplc 230kV OCB 20740	417,461
307	Capitol T2 Life Extension	415,279
308	Fancy Point: Rplc 230kV OCB 20735	412,091
309	Benoit Substation 230kV	383,245
310	Lockmoor Substation Upgrade Relay	381,980
311	Conway: Replace AT1 Diff Panel	355,861
312	Calcasieu 230kV Sub	348,452
313	Ninemile SES: Rplc 230kV OCB S2034	339,816
314	Pecue Add 230kV Bus Diff panel	338,723
315	Ponchatoula Add 230kV Breakers	336,139
316	Ninemile SES: Rplc 230kV OCB S2037	323,266
317	Chlomal-Lacassine ROW Calcasieu2024	317,482
318	Cosmar: Replace OCB 14695	317,176
319	Sterlington 500: Rpl Ouachita Panel	311,183
320	Frisco: Replace Cap Bank, GCB S1529	310,641
321	Baton Rouge: Specialty SF6 Trailer	310,549
322	Esso: Replace OCB 21555	305,942
323	Poydras Generator Interconnect	299,818
324	Oaks 230kV: Sub Upgrades	296,241
325	Barataria: Rplce 115kV Switch S7805	290,794
326	Meraux 230kV: Sub Upgrades	287,444
327	Destrehan: Replace 20 T2 Radiators	280,763
328	Behrman 230kV -Rmt-End Relay Replmt	277,443
329	ELL: 115-13.8kV\|33MVA LTC (Alto)	270,373
330	Humphreys: Replace OCB S6085	269,501
331	Webre: GIS Life Extension Bay 1	261,586
332	LOOP Leonard-Bld 115kV Sub	259,595
333	Lake Charles Bulk: Replace OCB 8500	255,839
334	Lake Charles Bulk Sub Upgrades	255,645
335	Destrehan: Replace Failed Fence	252,971
336	Gloria: T2 Life Extension	238,878
337	McKnight Substation Relay Work	233,532
338	Bayou Galion115Kv Inst D-components	222,830
339	Mossville Substation Upgrades	216,770
340	Fancy Pt: L-354, 20690, 20695 Pnls	213,771
341	Abbeville to LeBlanc 138kV Structur	213,339
342	Olin TDI: Replace OCB 18045	212,117
343	Coly-DEMCO 69kV Upgd	211,326
344	Geigy: Replace L-326 Line Panel	207,043
345	Pontchartrain: Replace T4 CS S3405	206,523
346	Port Hudson T6 LTC Repair	204,491
347	Hammond: Add CoverUp, Laser Defense	198,974
348	Conway: Replace 138kV OCB 20320	196,922
349	Youngsville: Inst 2nd Xfmr	192,525
350	Kaiser 230kVSub Rmt End Relay Rplmt	192,481
351	Oak Villa: LS Bus Tie Switch & CTs	189,566
352	Sarepta: Replace 34.5kV OCB N0304	183,955
353	Convent-replace Romeville LinePanel	178,730
354	Fancy Point: L-353 & 20650 Panels	177,731
355	Snakefarm: Repair T5 LTC	176,573
356	Thibodaux: Vacherie Ln Panel & CCVT	176,090
357	Bayou Warehouse 34.5KV 959F	171,452
358	Oak GroveT1 Add 34.5kV Feeder Ba	169,617
359	Coly GCB 21310 Major Rebuild	165,418
360	Coly 21300 Major Rebuild	159,609
361	Grace: Replace T1 & T2 LTC controls	156,790
362	Geigy: Replace 138kV OCB 14945	156,317
363	Norco: Replace LV bus diff panels	155,469
364	Evergreen: Replace 34.5kV OCB X1151	150,434
365	Geigy: Rplc 138kV OCB 14935	148,184
366	U-City: Rep 7 T2 Radiators & 8 Fans	147,342
367	D’ville: Replace 230kV MOAB S1917	143,980
368	CFI: Replace 34.5kV OCB X2992	143,540
369	Geigy: Replace L-313 Line Panel	142,497
370	Alfol: Replace Bus Diff 2 Panel	142,233
371	Oak Villa: Replace L-791 Line Panel	141,674
372	CFI: Replace 34.5kV OCB X2991	139,475
373	Olin TDI: Replace OCB 18050	134,484
374	Alchem: Replace Cap Bank #1	133,466
375	Ninemile SVC: Replace Computer	133,392
376	ELL: New 34-24kV \| 22.4MVA Auto	132,091
377	Alchem Cap Bank Failure	130,710
378	ELL: Camlin Pilot at Bayou Verret	128,475
379	Romeville-replaceConvent line panel	128,379
380	Waterford Swyd: 2 Gen 1 line CCVT's	127,573
381	Humphreys: Repl Terrebonne Panel	124,874
382	East: Replace 4.16kV OCB 531F	122,896
383	Vacherie:Replace Thib. Line Panel	120,530
384	Harelson: Replace L-791 Line Panels	119,101
385	Denham Springs: Replace GCB 21090	117,536
386	Paincourtville: Wanda Y0512 Panel	112,587
387	Thibodaux: Minor Add Replace T3	111,773
388	Air Liquide-Zephyr Bld New138kV Sub	110,980
389	Olin TDI: Replace Bus #3 Diff Panel	109,297
390	Bogalusa: Replace AT1 Diff Panel	106,467
391	Sarepta - Repl Cap Bank Panel	106,077
392	Olin TDI: Replace T2 Diff Panel	105,087
393	Dow Brine: Replace Wanda Line Panel	103,812
394	Mall of LA Blvd Extn at Wrd Crk Sub	100,208
395	Other Transmission & Distribution Substation Plant	10,172,342
396	GldnMdw to Clovly-Engzd 115kVLnRbld	33,878,768
397	Mud Lake-Big Lake 230kV	21,587,812
398	Conrad-Sellers Rd 138k T-Line	21,210,010
399	Bld 230kV FncyPnt-PrtHudson (L-354)	14,619,561
400	Waterford-Sidney 230kV T-Line	14,210,772
401	Waterford-Winchester T-Line ROW	8,374,155
402	Houma-Ashland 115 kV-L206_IDA Storm	8,125,297
403	Champagne-Plaisance L-636 Rebuild	6,898,267
404	Behrman to Port Nickel UG Line	4,554,881
405	Avondale-Harahan River Crossing_Ida	3,349,222
406	Arabi-Munster-Michoud L-150 L&Cut-i	2,590,052
407	Rebuild Jennings-Lawtag	2,563,844
408	EBroad - Ford Reconductor L-624	2,470,175
409	IDA 21: L172 Golden Meadow-Baratari	2,035,458
410	Mud Lake-Big Lake 230kV TL ROW	1,797,036
411	Placid-Sugar House 230kV TL Cut-In	1,684,211
412	Darnell-Lake Providence 230kV Line	1,496,970
413	Riverview-Wilbert: Reroute 138kV TL	1,355,310
414	Champagne Substation Upgrade	1,329,327
415	Meraux-Munster-Michoud L-292 L&Cut-	1,162,825
416	Moss Bluff-Goos Ferry 230kV Cut-In	1,086,371
417	Formosa-Sugar House 230kV TL Cut-In	1,070,846
418	Goos Ferry to Chalkley 230kV Cut-In	1,069,949
419	GM-Barataria 115kV Line Rebuild	1,020,844
420	Five Points to 281 to Line 247 Up	859,282
421	Nelson-Michigan 230kV Cut In	776,067
422	INCR21: St. Gabriel-Wintz	464,634
423	Thibodaux-Vacherie 230 kV Cut in	459,425
424	SnkFrm-Airline L-187 Upgrd Gyp-Clay	446,678
425	INF21_22: Addis-Tiger	429,489
426	Esso - Delmont: Upgrade 230kV Line	422,796
427	INF21_22: Addis-Copol	418,777
428	INCR21: Coly-Willow Glen	357,432
429	Chlomal-Lawtag ROW Jeff Davis 2024	350,243
430	Oaks-Munster-Meraux L-203 Cut-in	348,762
431	Slidell Airport Clearance Study	333,829
432	INF18: Rhodes-Hartburg	327,725
433	WP21: L13 Henning-Lacassine	325,022
434	L660 MOSSVILLE - LOCKMOOR 69kV	308,993
435	INF21_22: Addis-Willow Glen	226,111
436	Orange-Mossville ROW Calcasieu 2025	224,117
437	Glbl SplTap-Ellender-Intracstl 69kV	222,751
438	Big Lake-Vincent: 230kV Cut-In	216,531
439	INF22: CARLYSS-CERTAINTEED	214,797
440	GOAB Nesser from Tiger Sub	209,155
441	Big Lake-Graywood 230kV Cut-In	208,633
442	FAIL21: LITTLE GYPSY-FAIRVIEW	207,121
443	WP21_22: Addis-Willow Glen	196,329
444	Avondale Tower Demo/Rebuild	189,664
445	INF21-22: DAWSON CREEK-DOWNTOWN	171,716
446	WP21: ADDIS-TIGER	171,451
447	L-698 to Lake Charles Bulk Relocate	168,990
448	INCR21: Adams Creek-Angie	168,321
449	L-654 to Lake Charles Bulk Relocate	168,129
450	Orange-Mossville ROW 2025 Calcasieu	160,099
451	Chlomal-Lawtag ROW Calcasieu 2025	159,001
452	Southport-Joliet 230kV Cut-in & Upg	141,241
453	INF22: COKHAN TAP-MOSSVILLE	137,422
454	Hollywood-Nelson ROW Calcasieu 2025	136,570
455	Meaux to Sellers Rd 230kV Double Ci	136,239
456	Manena-Michigan 230kV Cut In	127,124
457	LA Grid; place holder – Trans Fail	125,638
458	Mid-Barataria Dvrsn Canal 115 T-Ln	125,283
459	Cadeville-Rilla 115/230kV	124,103
460	Pecue-I-10 Relo- Brrwd-Pecue L-395	123,195
461	FAIL22: Meaux Tap-Gueydan Tap	110,340
462	WP21: Metropolis-Winser	103,741
463	Other Transmission Lines Plant	3,448,017
464	ELA Capital Suspense, Distr Wires	163,131,225
465	ELA Metro Suspense, Distr Wires	101,943,193
466	CA Suspense TRN PM&C	94,522,684
467	Office of the CIO Capital Suspense	29,403,432
468	CA Suspense AM ESI	19,642,783
469	OVERHEADS-WF3 SITE ENG & SUPERVISIO	7,795,380
470	RIVERBEND SITE OVERHEAD ENG & SUPRV	6,776,480
471	CA Susp TRN Captl Projcts	5,384,777
472	Capital Suspense T&D Grid ESI LA	2,346,613
473	Facilities Capital Suspense ELA	286,755
474	Other Undistributed Overheads	420,210,738
43	Total	850,717,421

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
Explain in a footnote any important adjustments during year. Explain in a footnote any difference between the amount for book cost of plant retired, Line 12, column (c), and that reported for electric plant in service, page 204, column (d), excluding retirements of non-depreciable property. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No.	Item (a)	Total (c + d + e) (b)	Electric Plant in Service (c)	Electric Plant Held for Future Use (d)	Electric Plant Leased To Others (e)
Section A. Balances and Changes During Year
1	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance Beginning of Year	8,495,421,450	8,495,421,243	207
2	Depreciation Provisions for Year, Charged to
3	DepreciationExpenseExcludingAdjustments (403) Depreciation Expense	588,614,678	(a) 588,614,678
4	DepreciationExpenseForAssetRetirementCosts (403.1) Depreciation Expense for Asset Retirement Costs	13,286,493	13,286,493
5	ExpensesOfElectricPlantLeasedToOthers (413) Exp. of Elec. Plt. Leas. to Others
6	TransportationExpensesClearing Transportation Expenses-Clearing
7	OtherClearingAccounts Other Clearing Accounts
8	OtherAccounts Other Accounts (Specify, details in footnote):
9.1	Other Accounts (Specify, details in footnote):	35,188	(b) 35,188
10	DepreciationProvision TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)	601,936,359	601,936,359
11	Net Charges for Plant Retired:
12	BookCostOfRetiredPlant Book Cost of Plant Retired	137,309,742	(c) 137,309,742
13	CostOfRemovalOfPlant Cost of Removal	593,144,486	593,144,486
14	SalvageValueOfRetiredPlant Salvage (Credit)	908,887	908,887
15	NetChargesForRetiredPlant TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)	731,363,115	731,363,115
16	OtherAdjustmentsToAccumulatedDepreciation Other Debit or Cr. Items (Describe, details in footnote):
17.1	Other Debit or Cr. Items (Describe, details in footnote):	30,105	(d) 30,105
18	BookCostOfAssetRetirementCosts Book Cost or Asset Retirement Costs Retired
19	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)	8,365,964,589	8,365,964,382	207
Section B. Balances at End of Year According to Functional Classification
20	AccumulatedDepreciationSteamProduction Steam Production	912,583,015	(e) 912,583,015
21	AccumulatedDepreciationNuclearProduction Nuclear Production	4,317,853,852	(f) 4,317,853,852
22	AccumulatedDepreciationHydraulicProductionConventional Hydraulic Production-Conventional
23	AccumulatedDepreciationHydraulicProductionPumpedStorage Hydraulic Production-Pumped Storage
24	AccumulatedDepreciationOtherProduction Other Production	958,252,271	958,252,271
25	AccumulatedDepreciationTransmission Transmission	1,328,638,918	1,328,638,906	12
26	AccumulatedDepreciationDistribution Distribution	989,991,537	989,991,342	195
27	AccumulatedDepreciationRegionalTransmissionAndMarketOperation Regional Transmission and Market Operation
28	AccumulatedDepreciationGeneral General	141,355,004	141,355,004
29	AccumulatedProvisionForDepreciationOfElectricUtilityPlant TOTAL (Enter Total of lines 20 thru 28)	8,365,964,589	8,365,964,382	207

FOOTNOTE DATA

(a) Concept: DepreciationExpenseExcludingAdjustments

Excludes service company depreciation allocations of $12,616,767 (included in the depreciation expense shown on page 336), since these allocations do not offset to accumulated depreciation reserves. Also, ($34,896,898) is excluded due to depreciation expense reversed into a regulatory asset due to assets related to Hurricane Laura and Hurrican Ida that will be securitized.

(b) Concept: OtherAccounts

Depreciation on Nelson Coal Unit 6 Railcars, which is accounted for as fuel expense.

(c) Concept: BookCostOfRetiredPlant

Excludes retirements of $142,955 (included in Amortization of Other Utility Plant shown on pages 204 - 207), since these retirements do not offset to accumulated depreciation reserves.

(d) Concept: OtherAdjustmentsToAccumulatedDepreciation


Net losses on sale of land and buildings			($65,061)
Gains on disposition of hardware and alarm			34,956
Total			($30,105)

(e) Concept: AccumulatedDepreciationSteamProduction

Includes a debit balance of $4,958,165 for asset retirement obligations.

(f) Concept: AccumulatedDepreciationNuclearProduction

Includes a credit balance of $153,184,648 for asset retirement obligations.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
Report below investments in Account 123.1, Investments in Subsidiary Companies. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f). Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No.	DescriptionOfInvestmentsInSubsidiaryCompanies Description of Investment (a)	DateOfAcquisitionInvestmentsInSubsidiaryCompanies Date Acquired (b)	DateOfMaturityInvestmentsInSubsidiaryCompanies Date of Maturity (c)	InvestmentInSubsidiaryCompanies Amount of Investment at Beginning of Year (d)	EquityInEarningsOfSubsidiaryCompanies Equity in Subsidiary Earnings of Year (e)	InterestAndDividendRevenueFromInvestments Revenues for Year (f)	InvestmentInSubsidiaryCompanies Amount of Investment at End of Year (g)	InvestmentGainLossOnDisplosal Gain or Loss from Investment Disposed of (h)
1	VARIBUS L.L.C. - Subsidiary Company Subheading	04/01/1970
2	VARIBUS L.L.C. - Capital Stock 100,000 shares issued, $1 par value			100,000			100,000
3	VARIBUS L.L.C. - Paid-In-Capital			7,116,149		15,000,000	7,883,851
4	VARIBUS L.L.C. - Unappropriated Undistributed Subsidiary Earnings			15,835,459	10,649,802		5,185,657
5	VARIBUS L.L.C. - Cum. effect of the change in acct. for inc. taxes			8,237,050			8,237,050
6	VARIBUS L.L.C. - Subtotal			382,260	10,649,802	15,000,000	4,732,458
7	PRUDENTIAL OIL & GAS, L.L.C. - Subsidiary Company Subheading	07/28/1981
8	PRUDENTIAL OIL & GAS, L.L.C. - Capital Stock 11,537 shares issued, $1 par value			6,634			6,634
9	PRUDENTIAL OIL & GAS, L.L.C. - Paid-In-Capital			24,132,153			24,132,153
10	PRUDENTIAL OIL & GAS, L.L.C. - Unappropriated Undistributed Subsidiary Earnings			24,197,380			24,197,380
11	PRUDENTIAL OIL & GAS, L.L.C. - Cum. effect of change in acct. for post. benefits other than pens			490,664			490,664
12	PRUDENTIAL OIL & GAS, L.L.C. - Subtotal			432,071			432,071
13	GRAND GULF 3 NUCLEAR DEVELOPMENT, LLC - Subsidiary Company Subheading	09/19/2008
14	GRAND GULF 3 NUCLEAR DEVELOPMENT, LLC - Capital Contribution			88,000		8,000	80,000
15	GRAND GULF 3 NUCLEAR DEVELOPMENT, LLC - Unappropriated Undistributed Subsidiary Earnings			1,905		1,905
16	GRAND GULF 3 NUCLEAR DEVELOPMENT, LLC - Return of capital			80,000			80,000
17	GRAND GULF 3 NUCLEAR DEVELOPMENT, LLC - Subtotal			6,095		6,095
18	ENTERGY LOUISIANA INVESTMENT RECOVERY FUNDING I, L.L.C. - Subsidiary Company Subheading	06/07/2011
19	ENTERGY LOUISIANA INVESTMENT RECOVERY FUNDING I, L.L.C. - Capital Contribution			1,035,880		1,035,880
20	ENTERGY LOUISIANA INVESTMENT RECOVERY FUNDING I, L.L.C. - Unappropriated Undistributed Subsidiary Earnings			149,255	446,548	312	596,115
21	ENTERGY LOUISIANA INVESTMENT RECOVERY FUNDING I, L.L.C. - Subtotal			886,625	446,548	1,036,192	596,115
22	RIVER BEND 3 NUCLEAR DEVELOPMENT, LLC - Subsidiary Company Subheading	09/19/2008
23	RIVER BEND 3 NUCLEAR DEVELOPMENT, LLC - Capital Contribution			88,000		8,000	80,000
24	RIVER BEND 3 NUCLEAR DEVELOPMENT, LLC - Unappropriated Undistributed Subsidiary Earnings			1,905		1,905
25	RIVER BEND 3 NUCLEAR DEVELOPMENT, LLC - Return of Capital			80,000			80,000
26	RIVER BEND 3 NUCLEAR DEVELOPMENT, LLC - Subtotal			6,095		6,095
27	SOUTHERN GULF RAILWAY LLC - Subsidiary Company Subheading
28	SOUTHERN GULF RAILWAY LLC - Capital stock 1,000 shares issued, $1 par value	02/24/1993		575			575
29	SOUTHERN GULF RAILWAY LLC - Unappropriated Undistributed Subsidiary Earnings			1,134,848	66,646		1,201,494
30	SOUTHERN GULF RAILWAY LLC - Advances, Open Account			867,064			867,064
31	SOUTHERN GULF RAILWAY LLC - Interest Payable to Parent			232,355			232,355
32	SOUTHERN GULF RAILWAY LLC - Capital Contribution			74,750			74,750
33	SOUTHERN GULF RAILWAY LLC - Subtotal			39,896	66,646		26,750
34	GULF STATES UTILITIES COMPANY - Subsidiary Company Subheading
35	GULF STATES UTILITIES COMPANY - Capital Contribution			823			823
36	GULF STATES UTILITIES COMPANY - Subtotal			823			823
42	Total Cost of Account 123.1 $		Total	989,345	10,136,608	16,048,382	4,922,429

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

MATERIALS AND SUPPLIES
For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No.	Account (a)	Balance Beginning of Year (b)	Balance End of Year (c)	Department or Departments which Use Material (d)
1	Fuel Stock (Account 151)	50,409,320	42,930,214
2	Fuel Stock Expenses Undistributed (Account 152)	181,734	19
3	Residuals and Extracted Products (Account 153)
4	Plant Materials and Operating Supplies (Account 154)
5	Assigned to - Construction (Estimated)	(a) 236,645,418	(b) 267,405,204	Electric, Gas
6	Assigned to - Operations and Maintenance
7	Production Plant (Estimated)	156,760,608	159,803,013	Electric
8	Transmission Plant (Estimated)	488,370	572,754	Electric
9	Distribution Plant (Estimated)	4,961,291	11,113,832	Electric, Gas
10	Regional Transmission and Market Operation Plant (Estimated)
11	Assigned to - Other (provide details in footnote)
12	TOTAL Account 154 (Enter Total of lines 5 thru 11)	398,855,687	438,894,803
13	Merchandise (Account 155)
14	Other Materials and Supplies (Account 156)
15	Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)
16	Stores Expense Undistributed (Account 163)	39,077,556	46,430,420
17
18
19
20	TOTAL Materials and Supplies	488,524,297	528,255,456

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesConstruction


			BALANCE AT
			BEG OF YEAR
Production (estimated)			$157,055,602
Transmission (estimated)			26,650,254
Distribution (estimated)			52,939,562
Total Assigned to Construction (estimated)			$236,645,418

(b) Concept: PlantMaterialsAndOperatingSuppliesConstruction


			BALANCE AT
			END OF YEAR
Production (estimated)			$165,349,301
Transmission (estimated)			31,953,137
Distribution (estimated)			70,102,765
Total Assigned to Construction (estimated)			$267,405,203

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	SO2 Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year	249,876										249,876
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)	22,692		22,643		22,643		22,643		(a) 633,997		724,618
5	Returned by EPA
6
7
8	Purchases/Transfers:	50										50
9
10
11
12
13
14
15	Total	50										50
16
17	Relinquished During Year:
18	Charges to Account 509
19	Other:
20	Allowances Used
20.1	Allowances Used
21	Cost of Sales/Transfers:
22	Compliance Deduction	3,639										3,639
23
24
25
26
27
28	Total	3,639										3,639
29	Balance-End of Year	268,979		22,643		22,643		22,643		633,997		970,905
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)
33	Net Sales Proceeds (Other)
34	Gains
35	Losses
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year
37	Add: Withheld by EPA
38	Deduct: Returned by EPA
39	Cost of Sales
40	Balance-End of Year
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)
44	Net Sales Proceeds (Other)
45	Gains
46	Losses

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: AllowancesIssuedLessWithheldAllowancesNumber

Future years include allowances issued from 2025 through 2052.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	NOx Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year	757	89,304									757	89,304
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)	6,293		6,104		6,104		6,104		(a) 12,208		36,813
5	Returned by EPA
6
7
8	Purchases/Transfers:
9	Initial Allowance Recall	5,990										5,990
10	Current Year Adjustment	2,418										2,418
11	Conversion Allowances/Consumption	2,367										2,367
12
13
14
15	Total	1,205										1,205
16
17	Relinquished During Year:
18	Charges to Account 509	4,252	61,877									4,252	61,877
19	Other:
20	Allowances Used
20.1	Allowances Used
21	Cost of Sales/Transfers:
22
23
24
25
26
27
28	Total
29	Balance-End of Year	1,593	27,427	6,104		6,104		6,104		12,208		32,113	27,427
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)
33	Net Sales Proceeds (Other)
34	Gains
35	Losses
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year
37	Add: Withheld by EPA
38	Deduct: Returned by EPA
39	Cost of Sales
40	Balance-End of Year
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)
44	Net Sales Proceeds (Other)
45	Gains
46	Losses

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: AllowancesIssuedLessWithheldAllowancesNumber

Future years include allowances issued from 2025 through 2026.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfExtraordinaryPropertyLoss Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).] (a)	ExtraordinaryPropertyLossesNotYetRecognized Total Amount of Loss (b)	ExtraordinaryPropertyLossesRecognized Losses Recognized During Year (c)	ExtraordinaryPropertyLossesWrittenOffAccountCharged Account Charged (d)	ExtraordinaryPropertyLossesWrittenOff Amount (e)	ExtraordinaryPropertyLosses Balance at End of Year (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
20	TOTAL

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)] (a)	UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized Total Amount of Charges (b)	UnrecoveredPlantAndRegulatoryStudyCostsRecognized Costs Recognized During Year (c)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged Account Charged (d)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff Amount (e)	UnrecoveredPlantAndRegulatoryStudyCosts Balance at End of Year (f)
21	Waterford 3 Design Basis Documentation Cost - Amort pd Jan 1990 - Sept 2025 - Commission auth Feb 26, 1990	1,498,886		407	315,556	1,183,330
22	Retired plant - electric meters - LPSC Docket No. U-34320-A - Amort period 4/2019 - 7/2041 - Commission auth AC19-167-000 Sept 6, 2019	96,378,059		407	4,694,648	91,683,411
23	Retired plant - gas meters - LPSC Docket No. U-34320-A - Amort period 6/2019 - 8/2045 - Commission auth AC19-167-000 Sept 6, 2019	1,079,421		407	43,751	1,035,670
49	TOTAL	98,956,366			5,053,955	93,902,411

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

Transmission Service and Generation Interconnection Study Costs
Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies. List each study separately. In column (a) provide the name of the study. In column (b) report the cost incurred to perform the study at the end of period. In column (c) report the account charged with the cost of the study. In column (d) report the amounts received for reimbursement of the study costs at end of period. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.	DescriptionOfStudyPerformed Description (a)	StudyCostsIncurred Costs Incurred During Period (b)	StudyCostsAccountCharged Account Charged (c)	StudyCostsReimbursements Reimbursements Received During the Period (d)	StudyCostsAccountReimbursed Account Credited With Reimbursement (e)
1	Transmission Studies
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20	Total
21	Generation Studies
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39	Total
40	Grand Total

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

OTHER REGULATORY ASSETS (Account 182.3)
Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Assets being amortized, show period of amortization.
				CREDITS
Line No.	DescriptionAndPurposeOfOtherRegulatoryAssets Description and Purpose of Other Regulatory Assets (a)	OtherRegulatoryAssets Balance at Beginning of Current Quarter/Year (b)	IncreaseDecreaseInOtherRegulatoryAssets Debits (c)	OtherRegulatoryAssetsWrittenOffAccountCharged Written off During Quarter/Year Account Charged (d)	OtherRegulatoryAssetsWrittenOffRecovered Written off During the Period Amount (e)	OtherRegulatoryAssets Balance at end of Current Quarter/Year (f)
1	Electric Deferred Fuel Under-Recovery	2,987,834	32,895,597			35,883,431
2	Gas for Resale Deferred Under-Recovery	2,576,409	5,557,755			8,134,164
3	Capacity Rider Under-Recovery	8,534,653	993,385	555	6,657,770	2,870,268
4	Environmental Adjustment Clause Rider	26,487	169,370			195,857
5	Hurricane Ida Storm Damage Costs		2,952,794			2,952,794
6	Fuel Tracking Mechanism Under-Recovery (Legacy Entergy Louisiana) LPSC Docket No. U-33244	1,974,816	1,741,859			3,716,675
7	Income Taxes	1,001,812	994,213,350	182.3, 190, 282, 283	4,125,425	991,089,737
8	Deferred Fuel Unbilled	168,121,960				168,121,960
9	Derivative Instruments & Hedging Activities	1,617,463		244	1,617,463
10	Asset Retirement Obligation - Nuclear	255,645,357		407.3	9,305,917	246,339,440
11	Asset Retirement Obligation - River Bend 70%	23,843,636		407.3	4,319,927	19,523,709
12	Asset Retirement Obligation - Fossil	19,244,496	1,181,322			20,425,818
13	Asset Retirement Obligation - Coal	264,792	60,727			325,519
14	Defined Benefit Pension & Other Postretirement Plan	786,002,791		107, 190, 283, 410.1, 411.1, 926, 253	211,182,714	574,820,077
15	Qualified Pension Settlement Cost Deferral LPSC Docket No. 20-028-U Amort 130 months effective October 2020	5,366,893		926	507,108	4,859,785
16	Qualified Pension Settlement Cost Deferral LPSC Docket No. 20-028-U Amort 120 months effective July 2021		51,840,944	926	1,702,799	50,138,145
17	MISO Financial Transmission Rights Mark-to-Market	924,600	226,453			1,151,053
18	Deferred Electric Storm Restoration Costs	92,917,943	628,414,334			721,332,277
19	Acadia PB2 Transmission Upgrades LPSC Docket No. U-32708, 18.5 yr amort eff Dec 2014	4,652,621		568	374,708	4,277,913
20	New Nuclear Generation Development Costs LPSC Docket No. U-32707 and U-32708 8 yr recovery effect December 2014	13,962,758		407.3	7,284,917	6,677,841
21	Business Combination External Costs Deferral LPSC Docket No. U-33244, recovery thru FRP over 10 yrs eff December 2015	9,191,063		407.3, 923, 928, 930.2	1,621,952	7,569,111
22	Storm Cost Offset Rider - Isaac Securitization LPSC Docket No. U-32764	133,158				133,158
23	Fuel Stabilization Pilot Program Admin Costs Amortization through March 2024	42,515		407.3	12,783	29,732
24	River Bend AFUDC Gross-Up and Acc Amort. LPSC Order No. U-17282-J	7,209,978		407.3	1,894,800	5,315,178
25	Deferred COVID-19 costs Special Order 22-2020 and Special Order 44	48,812,238	7,468,093			56,280,331
26	Hurricane Laura/Delta - deferred depreciation expense, deferred carrying costs, and deferred securitization costs	1,008,813	48,349,662			49,358,475
27	MSS-4 ROE Settlement - Amort pd Sept 2021 thru Aug 2022		12,223,720	407.3	4,148,499	8,075,221
28	Danger Tree Vegetation Deferral LPSC Docket No. U-35565, recovery thru FRP over 10 yrs eff Sept 2022		7,157,357			7,157,357
44	TOTAL	1,456,065,086	1,795,446,722		254,756,782	2,996,755,026

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

MISCELLANEOUS DEFFERED DEBITS (Account 186)
Report below the particulars (details) called for concerning miscellaneous deferred debits. For any deferred debit being amortized, show period of amortization in column (a) Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
				CREDITS
Line No.	Description of Miscellaneous Deferred Debits (a)	Balance at Beginning of Year (b)	Debits (c)	Credits Account Charged (d)	Credits Amount (e)	Balance at End of Year (f)
1	Section 263A	542,227		930.2	109,612	432,615
2	Pooled equipment PEICo	1,309,055		517	53,898	1,255,157
3	Little Gypsy - Algiers - New Orleans City Council Docket No. UD-13-01	1,380,636		131	79,586	1,301,050
4	Non-Expense Accrued Labor	1,769,381	288,190			2,057,571
5	Vidalia - Mark to Market - Amortization through Dec 2031	1,379,441		930.2	125,404	1,254,037
6	Nuclear fuel in-process costs	105,651		120.6	105,049	602
7	Other	64		131	64
47	Miscellaneous Work in Progress
48	Deferred Regulatroy Comm. Expenses (See pages 350 - 351)
49	TOTAL	6,486,455				6,301,032

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

ACCUMULATED DEFERRED INCOME TAXES (Account 190)
Report the information called for below concerning the respondent’s accounting for deferred income taxes. At Other (Specify), include deferrals relating to other income and deductions.
Line No.	DescriptionOfAccumulatedDeferredIncomeTax Description and Location (a)	AccumulatedDeferredIncomeTaxes Balance at Beginning of Year (b)	AccumulatedDeferredIncomeTaxes Balance at End of Year (c)
1	Electric
2	(a) See Footnote Detail	1,776,761,012	2,489,748,550
7	Other
8	TOTAL Electric (Enter Total of lines 2 thru 7)	1,776,761,012	2,489,748,550
9	Gas
10	(b) See Footnote Detail	2,621,770	5,726,063
15	Other
16	TOTAL Gas (Enter Total of lines 10 thru 15)	2,621,770	5,726,063
17.1	Other (Specify)
17	Other (Specify)
18	TOTAL (Acct 190) (Total of lines 8, 16 and 17)	1,779,382,782	2,495,474,613

Notes

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: DescriptionOfAccumulatedDeferredIncomeTax


	BALANCE AT BEG OF YEAR	BALANCE AT END OF YEAR

Intrst/Tax Tax Deficiencies	$5,580,716	$6,219,675
Def Inc Taxes Regulatory	91,161	—
New Nuclear Development Costs	9,807,082	11,795,930
Securitization	30,073,932	—
Taxable Unbilled Revenue	(23,593,309)	8,975,871
Property Insurance Reserve	(18,076,414)	(193,865,222)
Capitalized Repairs	1,043,045	371,129
Injuries & Damages Reserve	5,421,379	5,210,274
Contribution in Aid of Construction	19,292,612	17,599,673
Pension Plan	(93,205,186)	(90,488,428)
Defined Benefit Pension	198,368,681	146,809,077
Supplemental Pension Plan	412,358	346,199
Other Post Employment Benefits	69,018,621	70,528,359
Deferred Fuel	(2,225,676)	(772,820)
Removal Cost	(82,540,498)	(282,298,937)
Acquisition	(995,631)	(971,389)
Accrual of Reserves	—	121,412
WF3 Buy Back	14,029,973	11,235,872
Sale/Leaseback	(1)	(1)
Decommissioning	74,277	8,093,998
Asset Retirement Obligation	3,287,863	(4,804,371)
Accrued Medical Claims	3,569,120	3,809,960
Uncollectible Accounts	11,495,932	7,407,704
Def Gain/Basis Step-Up	945,065	784,499
Restructuring Basis Step-up	56,034,911	39,078,525
Basis Step-Up	284,137,126	182,759,607
Regulatory Liability	42,909,998	77,027,850
Contract Deferred Revenue	393,562	473,751
Def. Misc. Services	148,124	105,878
Lease - Rental Expense	81,703	93,889
Environmental Reserve	850,549	947,638
Waste Site Clean-Up	261,564	262,788
Waste Disposal Reserve	1,265,341	1,335,170
Incentive Compensation	2,663,687	4,653,483
Restricted Stock Awards	153,964	145,990
Deferred Compensation	87,082	77,539
Rate Refund	19,484,788	3,540,015
Transition Costs	1,116,724	576,495
Payroll Tax Accruals	1,097,543	—
Retroactive Rate Reduction	48,464,219	46,499,448
W/O Plant	21,396,968	20,931,302
Income Tax adjustment	(1,058,718)	382,482,593
ADIT Wholesale	715,176	681,445
Tax Attribute - NOL/CR Carryforward	117,845,577	128,524,221


NOL Protected Excess	150,572,551	144,995,790
ADIT NOL Carryforward	913,866,877	1,821,411,610
LA ADIT on Deferred FITD	4,000,000	4,000,000
ADIT-Contrib Carryforward	2,387,434	3,030,998
ADIT-Tax CR Carryforward	9,309,331	12,320,027
Fed Offset-St Carryover	(54,400,171)	(113,415,966)
ADIT-Ben-Potnt Disall UTPs Res	1,100,000	1,100,000
TOTAL ELECTRIC	$1,776,761,012	$2,489,748,550

(b) Concept: DescriptionOfAccumulatedDeferredIncomeTax


GAS:	BALANCE AT BEG OF YEAR	BALANCE AT END OF YEAR
Taxable Unbilled Revenue	$211,038	$943,442
Property Insurance Reserve	(86,562)	(102,238)
Capitalized Repairs	518	144
Injuries & Damages Reserve	(59,729)	(76,262)
Contribution in Aid of Construction	640,004	610,172
Pension Plan	(3,045,689)	(3,522,498)
Supplemental Pension Plan	(15,021)	(16,192)
Other Post Employment Benefits	1,580,868	1,632,207
Removal Cost	(376,241)	(631,325)
Accrued Medical Claims	81,862	85,782
Uncollectible Accounts	419,890	462,617
Basis Step-Up	1,782,039	1,641,926
Environmental Reserve	(1,707)	(1,762)
Incentive Compensation	309,891	385,168
Deferred Compensation	25,375	26,074
Rate Refund	100,351	—
Income Tax adjustment	(1,037,330)	2,274,084
Tax Attribute - NOL/CR Carryforward	2,092,213	2,014,724
TOTAL GAS	$2,621,770	$5,726,063

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

CAPITAL STOCKS (Account 201 and 204)
Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No.	Class and Series of Stock and Name of Stock Series (a)	Number of Shares Authorized by Charter (b)	Par or Stated Value per Share (c)	Call Price at End of Year (d)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares (e)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount (f)	Held by Respondent As Reacquired Stock (Acct 217) Shares (g)	Held by Respondent As Reacquired Stock (Acct 217) Cost (h)	Held by Respondent In Sinking and Other Funds Shares (i)	Held by Respondent In Sinking and Other Funds Amount (j)
1	Common Stock (Account 201)
2
3
4
5	Total
6	Preferred Stock (Account 204)
7
8
9
10	Total
1	Capital Stock (Accounts 201 and 204) - Data Conversion
2
3
4
5	Total

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

2022-04-19

Year/Period of Report

End of:

2021

/

Q4

Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No.	Item (a)	Amount (b)
1	DonationsReceivedFromStockholdersAbstract Donations Received from Stockholders (Account 208)
2	DonationsReceivedFromStockholders Beginning Balance Amount
3.1	IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders Increases (Decreases) from Sales of Donations Received from Stockholders
4	DonationsReceivedFromStockholders Ending Balance Amount
5	ReductionInParOrStatedValueOfCapitalStockAbstract Reduction in Par or Stated Value of Capital Stock (Account 209)
6	ReductionInParOrStatedValueOfCapitalStock Beginning Balance Amount
7.1	IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8	ReductionInParOrStatedValueOfCapitalStock Ending Balance Amount
9	GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10	GainOnResaleOrCancellationOfReacquiredCapitalStock Beginning Balance Amount
11.1	IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock
12	GainOnResaleOrCancellationOfReacquiredCapitalStock Ending Balance Amount
13	MiscellaneousPaidInCapitalAbstract Miscellaneous Paid-In Capital (Account 211)
14	MiscellaneousPaidInCapital Beginning Balance Amount	2,938,204,555
15.1	IncreasesDecreasesDueToMiscellaneousPaidInCapital Increases (Decreases) Due to Miscellaneous Paid-In Capital	125,000,000
16	MiscellaneousPaidInCapital Ending Balance Amount	3,063,204,555
17	OtherPaidInCapitalAbstract Historical Data - Other Paid in Capital
18	OtherPaidInCapitalDetail Beginning Balance Amount
19.1	IncreasesDecreasesInOtherPaidInCapital Increases (Decreases) in Other Paid-In Capital
20	OtherPaidInCapitalDetail Ending Balance Amount
40	OtherPaidInCapital Total	3,063,204,555

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

CAPITAL STOCK EXPENSE (Account 214)
Report the balance at end of the year of discount on capital stock for each class and series of capital stock. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No.	NameOfClassAndSeriesOfStock Class and Series of Stock (a)	CapitalStockExpense Balance at End of Year (b)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22	TOTAL

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

LONG-TERM DEBT (Account 221, 222, 223 and 224)
Report by Balance Sheet Account the details concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds, and in column (b) include the related account number. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received, and in column (b) include the related account number. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued, and in column (b) include the related account number. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (m). Explain in a footnote any difference between the total of column (m) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No.	ClassAndSeriesOfObligationCouponRateDescription Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates) (a)	RelatedAccountNumber Related Account Number (b)	Principal Amount of Debt Issued (c)	LongTermDebtIssuanceExpensePremiumOrDiscount Total Expense, Premium or Discount (d)	LongTermDebtIssuanceExpenses Total Expense (e)	LongTermDebtPremium Total Premium (f)	LongTermDebtDiscount Total Discount (g)	NominalDateOfIssue Nominal Date of Issue (h)	DateOfMaturity Date of Maturity (i)	AmortizationPeriodStartDate AMORTIZATION PERIOD Date From (j)	AmortizationPeriodEndDate AMORTIZATION PERIOD Date To (k)	Outstanding (Total amount outstanding without reduction for amounts held by respondent) (l)	Interest for Year Amount (m)
1	Bonds (Account 221)
2	5.59% Series	221	300,000,000		(a) 2,582,721		240,000	10/02/2009	10/01/2024	10/02/2009	10/01/2024	300,000,000	16,770,000
3	3.78% Series 1	221	110,000,000		1,089,022		91,300	07/01/2014	04/01/2025	07/01/2014	04/01/2025	110,000,000	4,158,000
4	5.4% Series	221	400,000,000		3,329,864		1,368,000	11/16/2009	11/01/2024	11/16/2009	11/01/2024	400,000,000	21,600,000
5	4.44% Series	221	250,000,000		2,114,635		260,000	09/24/2010	01/15/2026	09/24/2010	01/15/2026	250,000,000	11,100,000
6	4.8% Series	221	200,000,000		1,611,259		346,000	03/24/2011	05/01/2021	03/24/2011	05/01/2021	(b) 0	3,200,000
7	3.3% Series	221	200,000,000		1,448,634		422,000	12/04/2012	12/01/2022	12/04/2012	12/01/2022	200,000,000	6,600,000
8	4.05% Series	221	325,000,000		2,480,017		1,010,750	08/23/2013	09/01/2023	08/23/2013	09/01/2023	325,000,000	13,162,500
9	5.0% Series	221	170,000,000		1,823,724			06/24/2014	07/15/2044	06/24/2014	07/15/2044	170,000,000	8,500,000
10	3.78% Series 2	221	190,000,000		1,570,993		157,700	07/01/2014	04/01/2025	07/01/2014	04/01/2025	190,000,000	7,182,000
11	4.95% Series 1	221	250,000,000		2,555,883		960,000	11/21/2014	01/15/2045	11/21/2014	01/15/2045	250,000,000	12,375,000
12	4.95% Series 2	221	200,000,000		2,173,842		5,988,000	03/10/2016	01/15/2045	03/10/2016	01/15/2045	200,000,000	9,900,000
13	3.25% Series	221	425,000,000		3,693,636		42,500	03/24/2016	04/01/2028	03/24/2016	04/01/2028	425,000,000	13,812,500
14	3.05% Series	221	325,000,000		2,771,944		1,943,500	05/19/2016	06/01/2031	05/19/2016	06/01/2031	325,000,000	9,912,500
15	4.875% Series	221	270,000,000		8,899,534			08/17/2016	09/01/2066	08/17/2016	09/01/2066	270,000,000	13,162,500
16	2.4% Series	221	400,000,000		2,997,547		1,692,000	10/04/2016	10/01/2026	10/04/2016	10/01/2026	400,000,000	9,600,000
17	3.12% Series	221	450,000,000		3,723,822		220,500	05/23/2017	09/01/2027	05/23/2017	09/01/2027	450,000,000	14,040,000
18	4.0% Series	221	750,000,000		6,833,458		1,170,000	03/23/2018	03/15/2033	03/23/2018	03/15/2033	750,000,000	30,000,000
19	4.2% Series 1	221	600,000,000		6,057,051		1,134,000	08/14/2018	09/01/2048	08/14/2018	09/01/2048	600,000,000	25,200,000
20	4.2% Series 2	221	525,000,000		5,506,732		3,711,750	03/12/2019	04/01/2050	03/12/2019	04/01/2050	525,000,000	22,050,000
21	2.9% Series 1	221	350,000,000		3,880,307		857,500	03/06/2020	03/15/2051	03/06/2020	03/15/2051	350,000,000	10,150,000
22	4.2% Series	221	300,000,000		1,783,246	2,259,000		03/31/2020	09/01/2048	03/31/2020	09/01/2048	300,000,000	12,600,000
23	2.9% Series 2	221	300,000,000		2,987,813	13,239,000		11/13/2020	03/15/2051	11/13/2020	03/15/2051	300,000,000	8,700,000
24	1.6% Series	221	300,000,000		2,326,491		1,170,000	11/13/2020	12/15/2030	11/13/2020	12/15/2030	300,000,000	4,800,000
25	0.62% Series	221	1,100,000,000		4,793,748		198,000	11/24/2020	11/17/2023	11/24/2020	11/17/2023	1,100,000,000	6,820,000
26	2.35% Series	221	500,000,000		3,941,756		2,580,000	03/10/2021	06/15/2032	03/10/2021	06/15/2032	500,000,000	9,497,917
27	3.1% Series	221	500,000,000		4,304,530		3,180,000	03/10/2021	06/15/2041	03/10/2021	06/15/2041	500,000,000	12,529,167
28	0.95% Series	221	1,000,000,000		4,652,682		1,500,000	10/01/2021	10/01/2024	10/01/2021	10/01/2024	1,000,000,000	2,375,000
29	Subtotal		10,690,000,000		91,934,891	15,498,000	30,243,500					10,490,000,000	319,797,084
30	Reacquired Bonds (Account 222)
31
32
33
34	Subtotal
35	Advances from Associated Companies (Account 223)
36	Long-term accts payable to assoc company
37	Subtotal
38	Other Long Term Debt (Account 224)
39	Pollution Control bonds - West Feliciana Parish 3.375% Series	224	83,680,000		936,436		836,800	03/18/2016	09/01/2028	03/18/2016	09/01/2028	(c) 0	706,050
40	Pollution Control bonds - St. Charles Parish 3.5% Series	224	115,000,000		1,103,474		1,275,350	03/18/2016	06/01/2030	03/18/2016	06/01/2030	(d) 0	1,677,083
41	Pollution Control bonds - LCDA 2.0% Series	224	16,200,000		577,989			04/01/2021	06/01/2030	04/01/2021	06/01/2030	16,200,000	243,000
42	Pollution Control bonds - LCDA 2.5% Series	224	182,480,000		1,498,645			04/01/2021	04/01/2036	04/01/2021	04/01/2036	182,480,000	3,421,500
43	Long-term obligations - Fort Polk distribution facilities 4.5%	224										3,554,006	160,692
44	Revolving credit facility	224										125,000,000	9,189
45	Subtotal		397,360,000		4,116,544		2,112,150					327,234,006	6,217,514
33	TOTAL		11,087,360,000									10,817,234,006	(e) 326,014,598

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: BondIssuanceExpense

Due to the presence of deregulated/nonregulated operations in Louisiana, a portion of Entergy Louisiana's operations are not under the provisions of ASC 980, Regulated Operations. Therefore, Entergy Louisiana must expense the portion of any loss/gain incurred in the reacquisition of debt that does not fall under the provisions of ASC 980. That portion is based on the ratio of net plant investment for the deregulated options to the total Louisiana net plant investment. The remaining loss will be moved to Account 189 to be amortized over the remaining life.

(b) Concept: Bonds

Mortgage Bond 4.8% series matured May 1, 2021.

(c) Concept: OtherLongTermDebt

West Feliciana Parish 3.375% series was redeemed April 1, 2021. The unamortized debt expense at the time of the redemption was $559,515 and unamortized discount was $498,384 for a combined total of $1,057,899. Of this, $8,463 was recorded to 426.5, Other Deductions, and the $1,049,436 has been moved to account 189, Unamortized Loss on Reacquired Debt, to be amortized over the life of the new debt issuance ending April 1, 2036.

(d) Concept: OtherLongTermDebt

St. Charles Parish 3.5% series was redeemed June 1, 2021. The unamortized debt expense at the time of the redemption was $700,528 and unamortized discount was $808,162 for a combined total of $1,508,690. Of this, $12,070 was recorded to 426.5, Other Deductions, and the $1,496,620 has been moved to account 189, Unamortized Loss on Reacquired Debt, to be amortized over the life of the new debt issuance ending April 1, 2036.

(e) Concept: InterestExpenseOnLongTermDebtIssued

Total interest for Accounts 221 and 224 is recorded in Account 427, as shown on page 117, line 62.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No.	Particulars (Details) (a)	Amount (b)
1	Net Income for the Year (Page 117)	653,984,207
2	Reconciling Items for the Year
3
4	Taxable Income Not Reported on Books
5	(a) See Footnote Detail	141,064,346
9	Deductions Recorded on Books Not Deducted for Return
10	(b) See Footnote Detail	507,390,075
14	Income Recorded on Books Not Included in Return
15	(c) See Footnote Detail	328,467,520
19	Deductions on Return Not Charged Against Book Income
20	(d) See Footnote Detail	3,029,320,952
21	(e) Other Reconciling Items - See Footnote Detail	3,070,129,994
27	Federal Tax Net Income
28	Show Computation of Tax:
29	Normal and Surtax @ 21%
30	Estimated Consolidated Income Tax Allocated
31	(f) See Footnote Detail - applicable for 1/1/21 - 12/31/21

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: TaxableIncomeNotReportedOnBooksDescription


Taxable Income Not Recorded on Books:
Amortization of Regulatory Liabilities			($319,865)
Avoided Cost - Tax Interest			6,736,366
Contributions in Aid of Construction			13,296,015
Deferred Contract Revenue			348,862
Obligation for Customer Credits			(5,500,000)
Unbilled Revenue			126,502,968
Total			$141,064,346

(b) Concept: DeductionsRecordedOnBooksNotDeductedForReturnDescription


Deductions Recorded on Books Not Deducted for Return:
Accrual of Reserves			($657,430,038)
Book Writeoff of Investment			6,203,761
Deferred Compensation and Benefits			7,216,469
Dry Cask Amortization			7,403,504
Asset Retirement Obligation			168,868,402
Contingencies			1,700,000
Meals and Entertainment			135,482
Nuclear Fuel Burn			93,681,759
Other Deferred Costs			(174,770)
Penalties			46,840
Political Expenses			111,622
Rate Refund			(33,407,900)
Reorganizational Costs			1,621,952
Reserve for Uncollectible Accounts			(14,668,151)
Securitization			(37,396,552)
Storm Costs			(51,302,455)
Total			($507,390,075)

(c) Concept: IncomeRecordedOnBooksNotIncludedInReturnDescription


Income Recorded on Books Not Included in Return:
Allowance for Funds Used During Construction			$20,296,772
Dividend Income			127,593,909
Equity Earnings in Subs			10,649,802
Officers' Life Insurance			383,802
Unrealized Gain/Loss			169,543,235
Total			$328,467,520

(d) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription


Deductions on Return Not Charged Against Book Income:
Amortization of Other Assets			$27,482,559
Amortization of Regulatory Assets			(6,262,208)
Bond Reacquisition Loss			297,398
Business Development Costs			20,746
Daily Lease Charges			222,011
Decommissioning Costs			3,120,100
Deferred Compensation & Benefits			17,104
Deferred Fuel			34,687,413
Depletion			21,508
Depreciation of Nuclear Fuel			86,687,396
Depreciation of Plant Assets			3,077,563,028
Dividends Received Deduction			5,841,294
Service Company Billings			7,034,947
IRC Sec 475 Mark to Market Adjustments			(144,565,737)
License Renewal Costs			2,191,004
Other Misc Deductible Items			27,000
Outage Costs			(8,824,584)
Pension and OPEB			(62,757,758)
Prepaid Expenses			2,676,280
Research and Development Costs			(21,297,402)
Software Costs			31,621,170
UOP Repairs			(6,482,317)
Total			$3,029,320,952

(e) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription


Reconciling Items for the Year:
Net Operating Loss			$2,953,710,876
Federal Income Tax Accrual - Prior year			($26,730,144)
Investment Tax Credit			($4,782,588)
FIN 48 taxes			$14,177,448
Provision for Deferred Income Tax			$132,402,969
State Income Tax Accrual - Prior Year			$1,351,433
Total			$3,070,129,994

(f) Concept: ComputationOfTaxDescription

The Respondent intends to join in the filing of a consolidated Federal Income Tax Return by Entergy Corporation and Subsidiary Companies for the year ended 2021. The estimated consolidated tax allocable under Entergy and Subsidiary Companies Intercompany Income Tax Allocation Agreement based on the provisions of Securities and Exchange Commission Rule 45(c) follows:


Entergy Utility Property, Inc.			$162,000
Entergy Utility Affiliates, LLC			(15,000)
Entergy Utility Assets Holdings, Inc.			904,000
Entergy Utility Group, Inc.			(21,000)
System Energy Resources, Inc.			30,734,000
Entergy Operations, Inc.			(97,000)
Entergy Corporation			(36,765,000)
Entergy Solutions LLC			(1,000)
Entergy Nuclear New York Investment Company, LLC			1,317,000
Entergy Nuclear Holding Company #3, LLC			(3,543,000)
Entergy Assets Management Company, LLC			(3,834,000)
Entergy Northeast Holdings, LLC			(18,320,000)
Entergy Power Marketing Holding II, Inc.			(108,000)
Entergy Nuclear Power Marketing, LLC			7,248,000
Entergy Nuclear, Inc.			(442,000)
Entergy Nuclear Holding Company #1			(5,454,000)
Entergy Nuclear Operations, Inc.			(13,904,000)
Entergy Power Holdings, Inc.			2,991,000
Entergy TransCo HoldCo, LLC			(7,000)
EAM Nelson Holding, LLC			332,000
Entergy Nighthawk GP, LLC			876,000
Entergy Power Investment Holding, Inc.			1,962,000
Entergy Mississippi Turbine Company			(16,000)
Entergy Nuclear Holding Company #2			221,000
Entergy Power, LLC			(149,000)
Entergy Enterprises, Inc.			(31,000)
Entergy Power Gas Operations, LLC			9,627,000
Entergy Power Marketing Holding I, Inc.			(3,887,000)
Entergy Power Operations U.S., Inc.			166,000
Entergy Nuclear Palisades, LLC			(9,752,000)
EK Holding III, LLC			(2,000)
EWO Marketing, LLC			(40,000)
Entergy Global, LLC			(77,000)
Entergy Ventures, Inc.			(80,000)
EUP Holdings, LLC			259,000
Entergy Technology Company			(3,000)
Warren Power, LLC			(1,000)
Entergy TransCo Texas, LLC			(11,000)
Entergy Services Holding, Inc. (Supplemental Information below)			75,187,000
Entergy Asset Management, Inc.			4,156,000


Entergy Investments Holding Company, Inc.			(3,000)
EWO Wind II, LLC			(19,000)
Entergy Nuclear Indian Point 2, LLC			(11,037,000)
Entergy Nuclear Indian Point 3, LLC			(12,579,000)
Entergy Finance Company, LLC			51,137,000
Entergy New Orleans, LLC			(6,566,000)
Entergy Utility Holding Company, LLC (Supplemental Information below)			(60,440,000)
Morpheus One Holdings, LLC			(75,000)
Total			$—


Supplemental Information -Entergy Utility Holding Company, LLC
Entergy Louisiana, LLC			($28,329,000)
Entergy Arkansas, LLC			(21,083,000.00)
Entergy Mississippi, LLC			(9,614,000.00)
Entergy Utility Holding Company, LLC			(1,414,000.00)
Total			($60,440,000)

Supplemental Information -Entergy Services Holdings, Inc
Entergy Services Holdings, Inc.			$41,991,000
Entergy Services, LLC			29,168,000.00
Entergy Account Services, LLC			4,028,000.00
Total			$75,187,000

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (d). Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (l) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
					BALANCE AT BEGINNING OF YEAR					BALANCE AT END OF YEAR		DISTRIBUTION OF TAXES CHARGED
Line No.	DescriptionOfTaxesAccruedPrepaidAndCharged Kind of Tax (See Instruction 5) (a)	TypeOfTax Type of Tax (b)	TaxJurisdiction State (c)	TaxYear Tax Year (d)	TaxesAccrued Taxes Accrued (Account 236) (e)	PrepaidTaxes Prepaid Taxes (Include in Account 165) (f)	TaxesCharged Taxes Charged During Year (g)	TaxesPaid Taxes Paid During Year (h)	TaxAdjustments Adjustments (i)	TaxesAccrued Taxes Accrued (Account 236) (j)	PrepaidTaxes Prepaid Taxes (Included in Account 165) (k)	TaxesAccruedPrepaidAndCharged Electric (Account 408.1, 409.1) (l)	IncomeTaxesExtraordinaryItems Extraordinary Items (Account 409.3) (m)	AdjustmentsToRetainedEarnings Adjustment to Ret. Earnings (Account 439) (n)	TaxesIncurredOther Other (o)
1	FICA	Federal Tax			5,905,826	0	18,344,904	19,292,546		4,958,184		5,383,621			12,961,283
2	Federal Unemployment Tax	Federal Tax			12,769	0	159,867	163,381		9,255		28,998			130,869
3	Federal Income Tax	Federal Tax			222,654,731	0	17,929,646	18,440,000		223,165,085		20,548,460			2,618,814
4	Federal Excise Tax	Federal Tax			0	0	39,746	39,746		0		63,197			23,451
5	Subtotal Federal Tax				228,573,326	0	614,871	1,055,673	0	228,132,524	0	15,072,644	0	0	15,687,515
6	State Income Tax	State Tax			9,194,824	0	832,044	12,502		8,350,278		933,941			1,765,985
7					0	0				0					0
8	Subtotal State Tax				9,194,824	0	832,044	12,502	0	8,350,278	0	933,941	0	0	1,765,985
9	Occupational License	Local Tax			0	0	623,963	623,963		0		623,139			824
10	Subtotal Local Tax				0	0	623,963	623,963	0	0	0	623,139	0	0	824
11	Inspection & Supervision Fee	Other Taxes			738,000	0	3,345,248	3,333,248		750,000		3,284,269			60,979
12	Pipeline Safety Inspection Fee	Other Taxes			0	0	104,213	104,213		0					104,213
13	Subtotal Other Tax				738,000	0	3,449,461	3,437,461	0	750,000	0	3,284,269	0	0	165,192
14	State Unemployment	Unemployment Tax			3,085	0	38,109	38,902		2,292		4,788			33,321
15	Subtotal Unemployment Tax				3,085	0	38,109	38,902	0	2,292	0	4,788	0	0	33,321
16	State Sales & Use	Sales And Use Tax			5,334,889	0	42,640,464	42,283,419		5,691,934					42,640,464
17	Local Sales and Use	Sales And Use Tax			2,862,377	0	27,662,876	27,830,635		2,694,618					27,662,876
18	Subtotal Sales And Use Tax				8,197,266	0	70,303,340	70,114,054	0	8,386,552	0	0	0	0	70,303,340
19	Entergy Services, LLC	Income Tax			0	0				0		5,624,812			5,624,812
20	Subtotal Income Tax				0	0	0	0	0	0	0	5,624,812	0	0	5,624,812
21	State Excise Tax	Excise Tax			0	0	215,178	215,178		0		215,178			0
22	Subtotal Excise Tax				0	0	215,178	215,178	0	0	0	215,178	0	0	0
23	Corporate Franchise Tax	Franchise Tax			4,244,552	0				4,244,552		150			150
24	Franchise Requirement	Franchise Tax			7,556,729	0	38,942,702	37,370,967		9,128,464		37,411,484			1,531,218
25	Subtotal Franchise Tax				3,312,177	0	38,942,702	37,370,967	0	4,883,912	0	37,411,634	0	0	1,531,068
26	Non Income Tax	Miscellaneous Other Tax			21,400,000	0	1,700,000			23,100,000		1,700,000			0
27	Subtotal Miscellaneous Other Tax				21,400,000	0	1,700,000	0	0	23,100,000	0	1,700,000	0	0	0
28	Receipts & Sales	Other Use Tax			0	0				0		36,081			36,081
29	Subtotal Other Use Tax				0	0	0	0	0	0	0	36,081	0	0	36,081
30	Ad Valorem Tax	Ad Valorem Tax			17,316,189	0	159,675,222	133,002,116		43,989,295		147,258,419			12,416,803
31	Subtotal Advalorem Tax				17,316,189	0	159,675,222	133,002,116	0	43,989,295	0	147,258,419	0	0	12,416,803
32	Entergy Services, LLC	Other Allocated Tax			0	0				0		22,234,996			22,234,996
33	Subtotal Other Allocated Tax				0	0	0	0	0	0	0	22,234,996	0	0	22,234,996
40	TOTAL				270,345,219	0	276,394,890	245,845,812	0	300,894,297	0	202,386,731	0	0	(a) 74,008,159

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: TaxesIncurredOther


	ACCOUNTS 408.1, 409.1 GAS	OTHER Various Accounts	TOTAL
FEDERAL TAXES:
FICA	$226,720	$12,734,563	$12,961,283
Federal Unemployment Tax	1,221	129,648	130,869
Federal Income Tax	(1,139,837)	3,758,651	2,618,814
Federal Excise Tax	—	(23,451)	(23,451)
SUBTOTAL	($911,896)	$16,599,411	$15,687,515
STATE AND LOCAL TAXES:
State Unemployment Tax	$202	$33,119	$33,321
Corporate Franchise Tax	—	(150)	(150)
Inspection & Supervision Fee	60,979	—	60,979
Pipeline Safety Inspect Fee	104,213	—	104,213
State Sales & Use	—	42,640,464	42,640,464
Local Sales & Use	—	27,662,876	27,662,876
State Income Tax	(456,666)	2,222,651	1,765,985
Act Valorem Tax	3,673,364	8,743,439	12,416,803
Franchise Fee - LA	1,531,218	—	1,531,218
Occupational License	824	—	824
Receipts & Sales	—	(36,081)	(36,081)
SUBTOTAL	$4,914,134	$81,266,318	$86,180,452
Taxes Other Than Income Taxes
Entergy Services, LLC	235,932	(22,470,928)	(22,234,996)
INCOME TAXES
Entergy Services, LLC	(28,473)	(5,596,339)	(5,624,812)
GRAND TOTAL	$4,209,697	$69,798,462	$74,008,159

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)
Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.
			Deferred for Year		Allocations to Current Year's Income
Line No.	Account Subdivisions (a)	Balance at Beginning of Year (b)	Account No. (c)	Amount (d)	Account No. (e)	Amount (f)	Adjustments (g)	Balance at End of Year (h)	Average Period of Allocation to Income (i)	ADJUSTMENT EXPLANATION (j)
1	Electric Utility
2	3%
3	4%
4	7%
5	10%	100,963,330			411.4/411.5	4,338,183		96,625,147	(a) 49.14 YRS
8	TOTAL Electric (Enter Total of lines 2 thru 7)	100,963,330				4,338,183		96,625,147
9	Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10										`
11	Non utility	6,354,009			411.5	391,123		5,962,886	(b) 52.91 YRS
47	OTHER TOTAL	6,354,009				391,123		5,962,886
48	GRAND TOTAL	107,317,339				4,729,306		102,588,033

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: AccumulatedDeferredInvestmentTaxCreditsAveragePeriodOfAllocationToIncome

Average lives are based on estimated composite useful lives of the properties and are subject to reconsideration each year.

(b) Concept: AccumulatedDeferredInvestmentTaxCreditsAveragePeriodOfAllocationToIncome

Average lives are based on estimated composite useful lives of the properties and are subject to reconsideration each year.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

OTHER DEFERRED CREDITS (Account 253)
Report below the particulars (details) called for concerning other deferred credits. For any deferred credit being amortized, show the period of amortization. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
			DEBITS
Line No.	Description and Other Deferred Credits (a)	Balance at Beginning of Year (b)	Contra Account (c)	Amount (d)	Credits (e)	Balance at End of Year (f)
1	Vinton/Jasper Clearing Account	3,248,248	131	2,060,089		5,308,337
2	Qualified Pension funded status	450,964,529	107, 182.3,219,131,926	161,226,446		289,738,083
3	Non-Qualified Pension funded status	1,771,519	131	605,241	116,244	1,282,522
4	Net ARO Plant Valuation	62,246,903	421	2,523,523		59,723,380
5	Change in Refueling Accounting	12,434,593				12,434,593
6	Split Dollar Life Insurance	774,898			22,701	797,599
7	Acct for Certain Invest. in Debt & Equity Securities - 30% River Bend	252,434,349	128	2,032,633	76,807,263	327,208,979
8	Waste Disposal Closure Costs	4,852,119			106,728	4,958,847
9	Cleco Power Non-IPP Tax gross up	400,100	242	400,100
10	Storm costs over collection	6,198,992				6,198,992
11	Willow Glen emission reduction credit	289,500				289,500
12	Deferred Payroll Employer Tax	4,208,676	131	4,208,676
13	Driftwood Electric Line Extension	232,286				232,286
14	Formosa				1,500,000	1,500,000
15	Siemens		456	54,360	978,086	923,726
16	Deferred rebate	23,668	131	31,692		8,024
17	Other	429			48	477
47	TOTAL	793,584,313		173,142,760	79,531,070	699,972,623

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)
Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property. For other (Specify),include deferrals relating to other income and deductions. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Accelerated Amortization (Account 281)
2	Electric
3	Defense Facilities
4	Pollution Control Facilities
5	Other
5.1	Nelson #6 Start Up Costs	7,149	1,268	473							7,944
5.2	River Bend #1 Start Up Costs	1,186,076	6,858	21,581							1,171,353
5.3	Other (provide details in footnote):
8	TOTAL Electric (Enter Total of lines 3 thru 7)	1,193,225	8,126	22,054							1,179,297
9	Gas
10	Defense Facilities
11	Pollution Control Facilities
12	Other
12.1	Other (provide details in footnote):
15	TOTAL Gas (Enter Total of lines 10 thru 14)
16	Other
16.1	Other
16.2	Other
17	TOTAL (Acct 281) (Total of 8, 15 and 16)	1,193,225	8,126	22,054							1,179,297
18	Classification of TOTAL
19	Federal Income Tax	899,108	5,318	15,813							888,613
20	State Income Tax	294,117	2,808	6,241							290,684
21	Local Income Tax

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization. For other (Specify),include deferrals relating to other income and deductions. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 282
2	Electric	3,043,644,693	1,780,147,080	1,352,598,818	496,428	667,128	182.3/254	26,364,370	182.3/254	182,968,027	3,627,625,912
3	Gas	18,647,447	2,518,915	1,601,606					182.3/254	1,779,440	21,344,196
4	Other (Specify)
5	Total (Total of lines 2 thru 4)	3,062,292,140	1,782,665,995	1,354,200,424	496,428	667,128		26,364,370		184,747,467	3,648,970,108
6
7
8
9	TOTAL Account 282 (Total of Lines 5 thru 8)	3,062,292,140	1,782,665,995	1,354,200,424	496,428	667,128		26,364,370		184,747,467	3,648,970,108
10	Classification of TOTAL
11	Federal Income Tax	2,304,175,500	1,103,398,868	759,632,098	496,428		182.3/254	26,364,370			2,622,074,328
12	State Income Tax	758,116,640	679,267,127	594,568,326		667,128			182.3/254	184,747,467	1,026,895,780
13	Local Income Tax

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283. For other (Specify),include deferrals relating to other income and deductions. Provide in the space below explanations for Page 276. Include amounts relating to insignificant items listed under Other. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 283
2	Electric
3	(a) See Footnote Detail	625,252,066	226,571,848	186,818,907			190	50,036,036	190/182.3/254	413,821,267	1,028,790,238
9	TOTAL Electric (Total of lines 3 thru 8)	625,252,066	226,571,848	186,818,907				50,036,036		413,821,267	1,028,790,238
10	Gas
11	(b) See Footnote Detail	952,381	3,304,450	1,562,239					182.3/254	3,731,237	6,425,829
17	TOTAL Gas (Total of lines 11 thru 16)	952,381	3,304,450	1,562,239						3,731,237	6,425,829
18	TOTAL Other
19	TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)	626,204,447	229,876,298	188,381,146				50,036,036		417,552,504	1,035,216,067
20	Classification of TOTAL
21	Federal Income Tax	475,247,921	137,064,837	120,808,112			190	42,507,400	190/182.3/254	287,481,587	736,478,833
22	State Income Tax	150,956,526	92,811,461	67,573,034			190	7,528,636	190/182.3/254	130,070,917	298,737,234
23	Local Income Tax
NOTES

FOOTNOTE DATA

(a) Concept: DescriptionOfAccumulatedDeferredIncomeTaxOther


	CHANGES DURING YEAR
	BALANCE AT BEGINNING OF YEAR	AMOUNTS DEBITED TO ACCT. 410.1	AMOUNTS CREDITED TO ACCT. 411.1	AMOUNTS DEBITED TO ACCT. 410.2	AMOUNTS CREDITED TO ACCT. 411.2
Deferred Fuel	$1,306,866	$73,503,534	$64,092,797	$—	$—
Reg Asset Covid 19	12,340,482	6,216,411	3,942,778	—	—
Reg Asset-Securitization	3,156,600	17,138,897	12,186,860	—	—
Reg Asset-LG3	2,068,199	—	2,068,199	—	—
Reg Asset-LG3 O/U	(1,020,191)	187,368	983,826	—	—
Maint/Refueling Reserve	9,380,904	9,954,374	12,025,748	—	—
Minimum Pension Liability	199,895,280	—	—	—	—
Bond Reacquisition Loss	6,944,412	1,107,038	801,443	—	—
Section 475 adj	258,606,889	65,574,272	57,986,508	—	—
Capitalized Costs	2,142,323	74,903	627,897	—	—
Deferred Storm Costs	(231,676)	257,634	25,958	—	—
Amort W3 Design	390,881	35,071	107,341	—	—
Rider SCO	34,725	2,093	966	—	—
Reg Asset-HCM	(17,190)	478	1,036	—	—
Misc Cap Costs	254,321	1,205,925	149,101	—	—
Reg Asset-Storm Costs	263,080	15,700,050	1,878,321	—	—
Prepaid Expenses	2,228,390	6,998,910	5,604,971	—	—
Constr. Trusts-Turgen	953,043	11,566	19,033	—	—
Nuc. Fuel Int Exp	101,444	—	20,295	—	—
RB Litigation	68,893,488	19,338,349	20,005,443	—	—
Income Tax Adjustment	(3,168,778)	2,704,119	541,777	—	—
Nuclear Decom Liability	60,728,574	6,560,856	3,748,609	—	—
TOTAL ELECTRIC	$625,252,066	$226,571,848	$186,818,907	$—	$—


	ADJUSTMENTS
	DEBITS		CREDITS
	ACCOUNT CREDITED	AMOUNT	ACCOUNT DEBITED	AMOUNT	BALANCE AT END OF YEAR
Deferred Fuel		$—		$—	$10,717,603
Reg Asset Covid 19		—		—	14,614,115
Reg Asset-Securitization		—	190	2,259,967	10,368,604
Reg Asset -LG3		—		—	—
Reg Asset-LG3 O/U		—		—	(1,816,649)
Maint/Refueling Reserve		—		—	7,309,530
Minimum Pension Liability	190	50,036,036		—	149,859,244
Bond Reacquisition Loss		—		—	7,250,007
Section 475 adj		—		—	266,194,653
Capitalized Costs		—		—	1,589,329
Deferred Storm Costs		—		—	—
Amort W3 Design		—		—	318,611
Rider SCO		—		—	35,852
Reg Asset-HCM		—		—	(17,748)
Misc Cap Costs		—		—	1,311,145
Reg Asset-Storm Costs		—		—	14,084,809
Prepaid Expenses		—		—	3,622,329
Constr. Trusts-Turgen		—		—	945,576
Nuc. Fuel Int Exp		—		—	81,149
RB Litigation		—		—	68,226,394
Income Tax Adjustment		—	182.3/254	411,561,300	410,554,864
Nuclear Decom Liability		—		—	63,540,821
TOTAL ELECTRIC		$50,036,036		$413,821,267	$1,028,790,238

(b) Concept: DescriptionOfAccumulatedDeferredIncomeTaxOther


		CHANGES DURING YEAR
	BALANCE AT BEGINNING OF YEAR	AMOUNTS DEBITED TO ACCT. 410.1	AMOUNTS CREDITED TO ACCT. 411.1	AMOUNTS DEBITED TO ACCT. 410.2	AMOUNTS CREDITED TO ACCT. 411.2
Deferred Fuel	$677,173	$2,388,045	$869,638	$—	$—
Reg Asset Covid 19	388,829	781,497	630,960	—	—
Reg Asset-Securitization	1	83,298	11,360	—	—
Reg Asset-HCM	17,190	1,036	478	—	—
Prepaid Expenses	(130,812)	50,573	49,803	—	—
Income Tax Adjustment	—	1	—	—	—
TOTAL GAS	$952,381	$3,304,450	$1,562,239	$—	$—


	ADJUSTMENTS
	DEBITS		CREDITS
	ACCOUNT CREDITED	AMOUNT	ACCOUNT DEBITED	AMOUNT	BALANCE AT END OF YEAR
Deferred Fuel		$—		$—	$2,195,580
Reg Asset Covid 19		—		—	539,366
Reg Asset-Securitization		—		—	71,939
Reg Asset-HCM		—		—	17,748
Prepaid Expenses		—		—	(130,042)
Income Tax Adjustment		—	182.3/254	3,731,237	3,731,238
TOTAL GAS		$—		$3,731,237	$6,425,829

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

OTHER REGULATORY LIABILITIES (Account 254)
Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Liabilities being amortized, show period of amortization.
			DEBITS
Line No.	Description and Purpose of Other Regulatory Liabilities (a)	Balance at Beginning of Current Quarter/Year (b)	Account Credited (c)	Amount (d)	Credits (e)	Balance at End of Current Quarter/Year (f)
1	Certain Investments in Debt & Equity Securities	567,682,199			124,545,051	692,227,250
2	Income Taxes	444,679,868	190, 282, 283	37,096,182	894,375,844	1,301,959,530
3	Unprotected Excess Accumulated Deferred Income Taxes - LPSC Docket No. U-34631 - Amort pd 5/18 thru 12/22	35,087,921	411.1	17,132,022		17,955,899
4	Gas Hedging Rider Over-Recovery	299,113			886,696	1,185,809
5	Energy Efficiency Rider Over-Recovery	24,821,337			1,034,186	25,855,523
6	Gas Infrastructure Investment Recovery Rider Over-Recovery	44,045			20,878	64,923
7	SSTS Deferred Over-Recovery	30,795			353,753	384,548
8	ARO River Bend - FERC Jurisdiction	1,755,051	407.4	1,755,051
9	ARO River Bend - LA Jurisdiction	27,968,366			17,496,084	45,464,450
10	Vidalia Power Purchase Contract Mark-to-Market	115,698,685	407.4	9,477,842		106,220,843
11	Fuel Stabilization Pilot Program Mark-to-Market	197,690			3,580,027	3,777,717
12	Guaranteed Customer Credits LPSC Docket No. U-33244 Amort period 9 yrs effective December 2015	21,541,667	407.4	5,500,000		16,041,667
13	Hurricanes Katrina/Rita tax settlement (Louisiana Act 55 Financing Savings Obligation)	104,156,299	407.4	14,095,898		90,060,401
14	Hurricanes Gustav/Ike tax settlement (Louisiana Act 55 Financing Savings Obligation) Legacy Entergy Gulf States Louisiana customers LPSC Docket No. U-30981-C	10,822,655	407.4	1,201,613		9,621,042
15	Hurricanes Gustav/Ike tax settlement (Louisiana Act 55 Financing Savings Obligation) Legacy Entergy Louisiana customers LPSC Docket No. U-30981-C	343,551	407.4	38,144		305,407
16	Hurricane Isaac tax settlement (Louisiana Act 55 Financing Savings Obligation) Legacy Entergy Gulf States Louisiana customers LPSC Docket No. U-32764-C	7,007,617	407.4	379,192		6,628,425
17	Hurricane Isaac tax settlement (Louisiana Act 55 Financing Savings Obligation) Legacy Entergy Louisiana customers LPSC Docket No. U-32764-C	21,930,155	407.4	1,186,671		20,743,484
18	Storm Cost Offset Rider - Katrina/Rita Securitization	136,118				136,118
19	MISO Rider Over-Recovery	11,208,591	407.4,457	6,391,868		4,816,723
20	Fuel Tracking Mechanism Over-Recovery (Legacy Entergy Guf States) LPSC Docket No. U-33244	2,084,023	557	276,280		1,807,743
21	Rough Production Cost Equalization	3,174,311	557	3,005,935		168,376
22	River Bend DOE Award - giveback period 9/1/2020 - 8/31/2021	317,119	407.4	317,119
23	River Bend DOE Award - giveback period 9/1/2022 - 8/31/2023				779,310	779,310
24	Waterford 3 DOE Award - giveback period 9/1/2021 thru 8/31/2022	1,586,024	407.4	547,009	55,004	1,094,019
25	Grand Gulf DOE Award Entergy Louisiana customers giveback period 9/1/2021 thru 8/31/2022	391,533	407.4	130,518	4,224,223	4,485,238
26	LIttle Gypsy Storm Securitization Over-Recovery				6,134,814	6,134,814
27	Derivative Instruments & Hedging Activities				6,405,855	6,405,855
28	Tax Reform Adjustment Mechanism - LPSC Docket No. U-36092 Amort pd 9/21 thru 8/22				9,705,827	9,705,827
29	Gas Rate Stabilization Plan ADIT - LPSC Docket No. U-34744	384,810	407.4	384,810
41	TOTAL	1,403,349,543		98,916,154	1,069,597,552	2,374,030,941

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

Electric Operating Revenues
The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages. Report below operating revenues for each prescribed account, and manufactured gas revenues in total. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.) See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.	Title of Account (a)	Operating Revenues Year to Date Quarterly/Annual (b)	Operating Revenues Previous year (no Quarterly) (c)	MEGAWATT HOURS SOLD Year to Date Quarterly/Annual (d)	MEGAWATT HOURS SOLD Amount Previous year (no Quarterly) (e)	AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly) (f)	AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly) (g)
1	SalesOfElectricityHeadingAbstract Sales of Electricity
2	ResidentialSalesAbstract (440) Residential Sales	1,480,134,692	1,260,496,317	13,587,668	13,771,171	953,368	946,440
3	CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales
4	CommercialSalesAbstract Small (or Comm.) (See Instr. 4)	(a) 1,052,556,152	(d) 880,049,424	10,384,500	10,465,054	133,495	132,910
5	IndustrialSalesAbstract Large (or Ind.) (See Instr. 4)	1,767,520,730	1,306,968,577	29,869,186	28,880,742	11,610	10,882
6	PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting	27,687,915	24,377,553	170,050	171,076	1,945	1,958
7	OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities	54,515,142	43,968,422	621,519	608,307	6,092	6,059
8	SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways
9	InterdepartmentalSalesAbstract (448) Interdepartmental Sales
10	SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers	4,382,414,631	3,515,860,293	54,632,923	53,896,350	1,106,510	1,098,249
11	SalesForResaleAbstract (447) Sales for Resale	391,423,731	333,594,102	7,713,967	7,949,638	9	4
12	SalesOfElectricityAbstract TOTAL Sales of Electricity	4,773,838,362	3,849,454,395	62,346,890	61,845,988	1,106,519	1,098,253
13	ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds	42,175,702	17,873,251
14	RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds	4,816,014,064	3,831,581,144	62,346,890	61,845,988	1,106,519	1,098,253
15	OtherOperatingRevenuesAbstract Other Operating Revenues
16	ForfeitedDiscounts (450) Forfeited Discounts	12,245,416	17,042,965
17	MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues	(b) 4,311,690	(e) 3,414,160
18	SalesOfWaterAndWaterPower (453) Sales of Water and Water Power
19	RentFromElectricProperty (454) Rent from Electric Property	23,745,343	21,375,134
20	InterdepartmentalRents (455) Interdepartmental Rents
21	OtherElectricRevenue (456) Other Electric Revenues	(c) 2,401,710	(f) 23,771,369
22	RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others	98,970,932	77,054,214
23	RegionalTransmissionServiceRevenues (457.1) Regional Control Service Revenues	25,055,266	21,059,550
24	MiscellaneousRevenue (457.2) Miscellaneous Revenues
25	OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues
26	OtherOperatingRevenues TOTAL Other Operating Revenues	166,730,357	163,717,392
27	ElectricOperatingRevenues TOTAL Electric Operating Revenues	4,982,744,421	3,995,298,536
Line12, column (b) includes $ of unbilled revenues.
Line12, column (d) includes MWH relating to unbilled revenues

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: SmallOrCommercialSalesElectricOperatingRevenue

Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.

(b) Concept: MiscellaneousServiceRevenues

Revenues from turn on/install new meters and return charges.

(c) Concept: OtherElectricRevenue


Other Electric Revenues:
Unbilled Revenue - Includes (38,034) MWH			($5,804,263)
Misc Rev - Ouachita Upgrades			2,199,264
MISO Mkt Sch 11 Wholesale Dist			1,972,500
Net Metering			1,618,157
Westinghouse Credits			1,304,007
Facilities Charge			643,989
Coordination Service Charge			633,333
Fees - LURC Securitization			587,130
Defense Logistics Agency Energy Defense Revenue			457,011
Interest - Other Electric			(1,932,563)
Third Party Sales of Inventory			138,545
Side Lights			7,475
Other Rev-Serv To Non-Associate			100
NISCO Incentive			400,000
Affiliate Service Fee Revenue			122,500
Siemans Energy Efficency Project			54,360
Trans-Union Contract Revenue			165
			$2,401,710

(d) Concept: SmallOrCommercialSalesElectricOperatingRevenue

Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.

(e) Concept: MiscellaneousServiceRevenues

Revenues from turn on/install new meters and return charges.

(f) Concept: OtherElectricRevenue


Other Electric Revenues:
Unbilled Revenue - Includes (102,786) MWH			$12,068,648
Misc Rev - Ouachita Upgrades			2,199,264
MISO Mkt Sch 11 Wholesale Dist			1,858,358
Net Metering			1,438,793
Westinghouse Credits			1,198,607
Facilities Charge			644,001
Coordination Service Charge			600,000
Fees - LURC Securitization			587,130
Defense Logistics Agency Energy Defense Revenue			457,011
Interest - Other Electric			1,587,583
Third Party Sales of Inventory			(10,793)
Side Lights			14,850
Other Rev-Serv To Non-Associate			33
NISCO Incentive			800,000
Affiliate Service Fee Revenue			245,000
Miscellaneous			82,434
Trans-Union Contract Revenue			450
			$23,771,369

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.	Description of Service (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1	MISO Sch 1 Sched/Sys Ctrl/Disp	388,630	723,997	1,159,992	1,550,531
2	MISO Sch 2 Reactive	5,745,941	11,560,363	18,129,314	23,504,735
46	TOTAL	6,134,571	12,284,360	19,289,306	25,055,266

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	RS-G Residential Service	5,242,073	557,716,790	362,775	14,450	0.1064
2	RS-L Residential Service	8,247,653	899,975,979	588,126	14,024	0.1091
3	MMRA-L Master Metered Res Apts	12,675	1,272,449	29	437,069	0.1004
4	ALGS-G Area Lighting Service	14,437	3,372,586	628	22,989	0.2336
5	ALS-LED Area Lighting Serv-LED	3,016	2,084,531	233	12,944	0.6912
6	LS-E-G Light Serv to Existing Inst	7,257	1,275,883	171	42,439	0.1758
7	RLU-G Street Lighting Serv	5,061	2,207,229	54	93,722	0.4361
8	SLPL-G Street Light Pole Serv		58,563	2
9	DSL-L Directional Security Ltg	19,226	3,928,573	467	41,169	0.2043
10	NW-L Night Watchman Ltg	19,877	3,641,672	447	44,468	0.1832
11	HPSV-NW-L Hi Press. Sod. Lgt	13,890	3,957,061	393	35,344	0.2849
12	RLU-L Street Lighting Serv	1,033	508,983	15	68,867	0.4927
13	MV-L Mercury Vapor Street Lgt	1	183			0.1830
14	SLPS-L Street Light Pole Serv		9,772
15	SGS-G Small General Service	358	48,167	26	13,769	0.1345
16	GS-G General Service	1,112	77,385	2	556,000	0.0696
17	GS-L Small General Service	1	1,957			1.9570
18	AFC-L Additional Facilities Charges		1,138
19	Miscellaneous		295
41	TOTAL Billed Residential Sales	13,587,668	(a) 1,480,134,692	953,368	14,252	0.1089
42	TOTAL Unbilled Rev. (See Instr. 6)
43	TOTAL	13,587,668	1,480,134,692	953,368	14,252	0.1089

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: ResidentialSalesBilled


Residential
Includes fuel adjustment revenues of:
RS – G Residential Service			$161,879,576
ALS-G Area Lighting Service			445,541
ALS-LED Area Lighting-LED			97,281
LS-E-G Light Serv to Existing Inst			223,576
RLU-G Street Lighting Service			156,596
SGS-G Small General Service			10,835
GS-G General Service			34,574
RS-L Residential Service			266,111,768
MMRA-L Master Meter Residential Apts			422,695
DSL-L Directional Security Lighting			623,390
NW-L Night Watchman Lighting			646,326
HPSV-NW-L High Pressure Sodium Vapor Lighting			451,639
RLU-L Street Lighting Service			33,564
MV-L Mercury Vapor Street Lighting			49
GS-L General Service			(25)
Total Residential Fuel Adjustment Revenues			$431,137,385

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	SGS-G Small General Service	637,125	87,435,414	35,710	17,842	0.1372
2	GS-G General Service	3,435,918	307,128,565	17,899	191,961	0.0894
3	GS-TOD-G Gen Sev Time-Of-Day Serv	640	55,778	1	640,000	0.0872
4	LPS-G Large Power Serv	656,724	44,575,484	27	24,323,111	0.0679
5	HLFS-G High Load Factor Serv	115,545	7,222,119	4	28,886,250	0.0625
6	GS-L Small General Service	4,020,124	445,939,036	74,841	53,716	0.1109
7	LGS-L Large General Service	1,061,822	106,466,197	2,412	440,225	0.1003
8	LIS-L Large Industrial Service	283,937	21,327,219	10	28,393,700	0.0751
9	MMGS-L Master Metered Gen Service	1,574	239,062	24	65,583	0.1519
10	WHSH-L Water Heat & Space Heat	3,989	380,925	46	86,717	0.0955
11	SMQ-G Standby & Maint Service	7,557	600,066			0.0794
12	ALS-G Area Lighting Service	57,079	8,471,949	882	64,715	0.1484
13	ALS-LED Area Lighting Serv-LED	19,023	7,252,515	278	68,428	0.3812
14	LS-E-G Light Serv to Existing Inst	6,119	782,753	209	29,278	0.1279
15	RLU-G Street Lighting Serv	1	336			0.3360
16	SHL-G Street & Hwy Lighting	329	43,937	14	23,500	0.1335
17	TSS-G Municipal Traffic Serv	90	10,867	36	2,500	0.1207
18	DSL-L Directional Security Lgt	71,107	11,888,384	788	90,237	0.1672
19	NW-L Night Watchman Lgt	3,936	753,735	179	21,989	0.1915
20	HPSV-NW-L Hi Press Sod Lgt	1,769	489,955	94	18,819	0.2770
21	RLU-L Street Lighting Serv	12	3,538	1	12,000	0.2948
22	MV-L Mercury Vapor Street Lgt	38	4,590	2	19,000	0.1208
23	TSL-L Traffic & Signal Lgt	42	8,280	25	1,680	0.1971
24	SPLS-L Street Light Pole Serv		1,860	1
25	MS - Miscellaneous Services		120
26	AFC Additional Facilities Charges		560,782
27	AFC-G Additional Facilities Charges		627,320	10
28	AFC-L Additional Facilities Charges		217,473	2
29	Facilities Charges - L		67,658
30	REP Renewable Energy Pilot Pur		360
31	RS-L Residential Service		125
41	TOTAL Billed Small or Commercial	10,384,500	(a) 1,052,556,152	133,495	77,789	0.1014
42	TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)
43	TOTAL Small or Commercial	10,384,500	(b) 1,052,556,152	133,495	77,789	0.1014

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: SmallOrCommercialSalesElectricOperatingRevenueBilled


Commercial
Includes fuel adjustment revenues of:
SGS-G Small General Service			$19,722,964
GS-G General Service			106,359,254
GS-TOD-G Gen Serv Time-Of-Day			20,115
LPS-G Large Power Serv			19,900,268
HLFS-G High Load Factor Serv			3,446,073
SMQ-G Qualifying Facilities			251,418
ALS-G Area Lighting Service			1,752,009
ALS-LED Area Lighting-LED			608,608
LS-E-G Light Serv to Existing Inst			188,307
SHL-G Street & Highway Lighting			10,166
RLU-G Street Lighting Service			28
TSS-G Municipal Traffic Signal			2,793
GS-L Small General Service			130,648,364
LGS-L Large General Service			34,668,027
LIS-L Large Industrial Service			9,167,438
MMGS-L Master Metered General Service			61,157
WHSH-L Water Heating & Space Heating			126,821
DSL-L Directional Security Lighting			2,299,870
NW-L Night Watchman Lighting			127,852
HPSV-NW-L High Pressure Sodium Vapor Lighting			57,343
MV-L Mercury Vapor Street Lighting			1,242
RLU-L Street Lighting Service			396
TSL-L Traffic & Signal Lighting			1,377
RS-L Residential Service			(37)
Total Commercial Fuel Adjustment Revenues			$329,421,853

(b) Concept: SmallOrCommercialSalesElectricOperatingRevenue

Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	SGS-G Small General Service	28,639	4,439,701	3,441	8,323	0.1550
2	GS-G General Service	482,594	40,714,588	660	731,203	0.0844
3	GS-TOD-G Gen Serv Time-Of-Day	7,770	919,869	3	2,590,000	0.1184
4	LPS-G Large Power Service	3,892,798	237,919,118	53	73,449,019	0.0611
5	HLFS-G High Load Factor Serv	5,286,787	317,318,342	38	139,125,974	0.0600
6	EIS-G Energy Intensive Industry Serv	1,191,953	45,938,110	2	595,976,500	0.0385
7	EEIS-G Electrochemical Energy	662,439	26,392,467	2	331,219,500	0.0398
8	NGPCS-G Nat Gas Pipeline Comp Serv	12,063	954,570	1	12,063,000	0.0791
9	SCR-G Special Contract Rate	613,859	29,217,824	3	204,619,667	0.0476
10	SMQ-G Standby & Maint Service	548,219	35,130,122	3	182,739,667	0.0641
11	LQF-G Large Qualifying Facilities		4,200
12	SSTS-G Supp Short Term Serv	701,623	27,577,951	1	701,623,000	0.0393
13	GS-L Small General Service	1,614,513	144,117,043	6,816	236,871	0.0893
14	LGS-L Large General Service	186,361	18,313,538	282	660,855	0.0983
15	LIS-L Large Industrial Serv	1,837,334	132,403,230	40	45,933,350	0.0721
16	LIPS-L Large Ind. Powr Serv	459,414	30,658,334	2	229,707,000	0.0667
17	LLHLFPS-L Large Ld High Ld Ftr Pwr Serv	11,189,726	569,129,632	9	1,243,302,889	0.0509
18	LMPS Large Manufacturing Power Serv	152	65,219			0.4291
19	EECS-L Exper. Electrochemical Serv	481,998	23,112,760	1	481,998,000	0.0480
20	CS-L Curtailment Serv	389,047	15,329,416			0.0394
21	NGPCS-L Nat. Gas Pipe Comp Serv	63,622	5,087,226	3	21,207,333	0.0800
22	WHSH-L Water Heat & Space Heat	53	5,216	3	17,667	0.0984
23	QFSS-L Qualif. Fac. Standby Serv	205,154	19,507,121	1	205,154,000	0.0951
24	ALS-G Area Lighting Serv	3,765	539,244	53	71,038	0.1432
25	ALS-LED Area Lighting Serv-LED	2,290	799,117	50	45,800	0.3490
26	LS-E-G Light Serv to Existing Inst	536	69,538	15	35,733	0.1297
27	SHL-G Street & Hwy Lighting	11	2,988			0.2716
28	AFC Additional Facilties Charges		9,977,325	3
29	AFC-G Additional Facilties Charges		11,387,016	4
30	AFC-L Additional Facilities Charges		6,804,136
31	Facilities Charges - L		12,593,949	3
32	MS Miscellenous Services		1,020
33	DSL-L Directional Security Lgt	5,872	948,282	66	88,970	0.1615
34	NW-L Night Watchman Lgt	349	63,882	22	15,864	0.1830
35	HPSV-NW-L Hi Press Sod Lgt	190	51,330	19	10,000	0.2702
36	REP Renewable Energy Pilot Pur		440
37	MMGS-L Master Metered Gen Serv	55	26,871	11	5,000	0.4886
38	RS-G Residential Service		5
41	TOTAL Billed Large (or Ind.) Sales	29,869,186	(a) 1,767,520,730	11,610	2,572,712	0.0592
42	TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)
43	TOTAL Large (or Ind.)	29,869,186	1,767,520,730	11,610	2,572,712	0.0592

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: LargeOrIndustrialSalesElectricOperatingRevenueBilled


Industrial
Includes fuel adjustment revenues of:
SGS-G Small General Service			$896,583
GS-G General Service			14,844,587
GS-TOD-G General Service Time-Of-Day			236,567
LPS-G Large General Service			116,010,923
HLFS-G High Load Factor Service			157,693,775
EIS-G Energy Intensive Industry Service			34,919,428
EEIS-G Electrochemical Energy Intensive Indust			19,724,539
NGPCS-G Nat Gas Pipeln Compression			383,578
SCR-G Special Contract Rates - includes imputed fuel revenue			18,812,379
SMQ-G Qualifying Facilities			17,425,733
SSTS-G Supp Short Term Service			22,625,396
ALS-G Area Lighting Service			115,702
ALS-LED Area Lighting-LED			73,942
LS-E-G Light Serv to Existing Inst			16,502
SHL-G Street & Highway Lighting			341
GS-L Small General Service			51,752,710
LGS-L Large General Service			6,026,035
LIS-L Large Industrial Service			58,466,664
LIPS-L Large Industrial Power Service			13,445,488
LLHLFPS-L Large Load High Load Factor Power Service			346,404,382
LMPS-Large Manufacturing Power Service			5,592
EECS-L Experimental Electrochemical Curt. Serv			16,622,759
CS-L Curtailment Serv			12,397,664
NGPCS-L Natural Gas Pipeline Compression Service			1,988,180
WHSH-L Water Heating & Space Heating			1,704
QFSS-L Qualifying Facilities Standby Service			8,339,273
DSL-L Directional Security Lighting			190,051
NW-L Night Watchman Lighting			11,354
HPSV-NW-L High Pressure Sodium Vapor Lighting			6,159
MMGS-L Master Metered General Service			2,165
RS-G Residential Service			—
Total Industrial Fuel Revenues			$919,440,155

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

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

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	ALS-G Area Lighting Service	526	92,066	23	22,870	0.1750
2	ALS-LED Area Lighting Serv-LED	162	57,126	13	12,462	0.3526
3	LS-E-G Light Serv to Existing Inst	21,467	3,862,927	9	2,385,222	0.1799
4	SHL-G Street & Hwy Lighting	30,542	6,041,080	109	280,202	0.1978
5	TSS-G Municipal Traffic Signal	4,178	490,272	247	16,915	0.1173
6	SGS-G Small General Service	116	13,935	1	116,000	0.1201
7	GS-G General Service	12	1,896	1	12,000	0.1580
8	DSL-L Directional Security Lgt	622	112,156	56	11,107	0.1803
9	NW-L Night Watchman Lgt	8	1,641	7	1,143	0.2051
10	HPSV-NW-L Hi Press Sod. Lgt	15	3,959	4	3,750	0.2639
11	HPSV-L Hi Press Sod. Lgt	62,661	9,736,405	197	318,076	0.1554
12	LED-SL-L LED Street Lighting	1,752	209,624	15	116,800	0.1196
13	MV-L Mercury Vapor Street Lgt	44,977	6,278,412	15	2,998,467	0.1396
14	TSL-L Traffic & Signal Lgt	2,497	498,606	1,245	2,006	0.1997
15	SHL-LED Street & Hwy Lgt-LED	425	282,372	2	212,500	0.6644
16	SHL-EE Street & Hwy Lgt - Energy Efficiency	90	5,438	1	90,000	0.0604
41	TOTAL Billed Public Street and Highway Lighting	170,050	(a) 27,687,915	1,945	87,429	0.1628
42	TOTAL Unbilled Rev. (See Instr. 6)
43	TOTAL	170,050	27,687,915	1,945	87,429	0.1628

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: PublicStreetAndHighwayLightingBilled


Public Street and Highway Lighting Sales
Includes fuel adjustment revenues of:
ALS-G Area Lighting Service			$16,173
ALS-LED Area Lighting-LED			5,577
LS-E-G Light Serv to Existing Inst			662,801
SHL-G Street & Highway Lighting			942,209
TSS-G Municipal Traffic Signal			128,931
SGS-G Small General Service			3,590
GS-G General Service			361
DSL-L Directional Security Lighting			20,052
NW-L Night Watchman Lighting			278
HPSV-NW-L High Pressure Sodium Vapor Lighting			486
HPSV-L High Pressure Sodium Vapor Lighting			2,034,212
LED-SL-L LED Street Lighting			57,332
MV-L Mercury Vapor Lighting			1,453,047
TSL-L Traffic & Signal Lighting			79,973
SHL-LED Str & Hwy Ltg - LED			13,688
SHL-EE Street & Hwy Lgt Installed Under Energy Efficiency Order			3,217
Total Public Street and Highway Lighting			—
Fuel Adjustment Revenues			$5,421,927

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	SGS-G Small General Service	14,706	1,991,806	806	18,246	0.1354
2	GS-G General Service	81,422	6,764,440	192	424,073	0.0831
3	LPS-G Large Power Service	36,892	2,832,452	2	18,446,000	0.0768
4	WPS-G Municipal Water Pumping Service	82,509	6,239,441	459	179,758	0.0756
5	GS-L Small General Service	139,774	13,617,705	1,470	95,084	0.0974
6	LGS-L Large General Service	25,969	2,469,557	40	649,225	0.0951
7	LIS-L Large Industrial Service	19,379	1,436,485	1	19,379,000	0.0741
8	MP-L Municipal & Parish Pumping Serv	216,996	18,409,191	3,012	72,044	0.0848
9	ALS-G Area Lighting Service	800	114,137	15	53,333	0.1427
10	ALS-LED Area Lighting Serv-LED	552	200,053	14	39,429	0.3624
11	LS-E-G Ligt Serv to Existing Inst	126	15,597	2	63,000	0.1238
12	SHL-G Street & Hwy Lgt	1	125			0.1250
13	TSS-G Municipal Traffic Serv	6	990	19	316	0.1650
14	DSL-L Directional Security Lgt	2,175	357,975	48	45,313	0.1646
15	NW-L Night Watchman Lgt	128	23,409	7	18,286	0.1829
16	HPSV-NW-L Hi Press. Sod. Lgt	74	19,960	3	24,667	0.2697
17	CCL-L Christmas Community Lgt	10	1,132	2	5,000	0.1132
18	AFC Additional Facilities Charges		543
19	AFC-G Additional Facilities Charges		11,063
20	AFC-L Additional Facilties Charges		9,081
41	TOTAL Billed Other Sales to Public Authorities	621,519	(a) 54,515,142	6,092	102,022	0.0877
42	TOTAL Unbilled Rev. (See Instr. 6)
43	TOTAL	621,519	54,515,142	6,092	102,022	0.0877

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: OtherSalesToPublicAuthoritiesBilled


Other Sales to Public Authorities
Includes fuel adjustment revenues of:
SGS-G Small General Service			$452,516
GS-G General Service			2,489,276
LPS-G Large Power Service			1,126,011
WPS-G Municipal Water Pumping Service			2,471,152
ALS-G Area Lighting Service			24,580
ALS-LED Area Lighting-LED			17,590
LS-E-G Light Service to Existing Inst			3,891
SHL-G Street & Highway Lighting			14
TSS-G Municipal Traffic Serv			177
GS-L Small General Service			4,498,072
LGS-L Large General Service			842,837
LIS-L Large Industrial Service			626,834
MP-L Municipal & Parish Pumping			6,959,456
DSL-L Directional Security Lighting			70,303
NW-L Nightwatchman Lighting			4,156
HPSV-NW-L Hi Press Sod. Vapor Lighting			2,399
CCL-L Christmas Community Lighting			270
Total Other Sales to Public Authorities			—
Fuel Adjustment Revenues			$19,589,534

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41	TOTAL Billed Provision For Rate Refunds
42	TOTAL Unbilled Rev. (See Instr. 6)
43	TOTAL		42,175,702

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
41	TOTAL Billed - All Accounts	54,632,923	4,382,414,631	1,106,510	49,374	0.0802
42	TOTAL Unbilled Rev. (See Instr. 6) - All Accounts
43	TOTAL - All Accounts	54,632,923	4,382,414,631	1,106,510	49,374	0.0802

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

SALES FOR RESALE (Account 447)
Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326). Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k). In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24. Footnote entries as required and provide explanations following all required data.
					ACTUAL DEMAND (MW)			REVENUE
Line No.	Name of Company or Public Authority (Footnote Affiliations) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Average Monthly Billing Demand (MW) (d)	Average Monthly NCP Demand (e)	Average Monthly CP Demand (f)	Megawatt Hours Sold (g)	Demand Charges ($) (h)	Energy Charges ($) (i)	Other Charges ($) (j)	Total ($) (h+i+j) (k)
1	Sam Rayburn	RQ	197	448	310	295	445,535	16,231,889	16,041,577		32,273,466
2	(a) Entergy Texas, Inc.	LU	181				2,945,439	145,650,486	36,708,653		182,359,139
3	(b) Entergy New Orleans, LLC	LU	181				2,004,975	60,906,370	41,467,862		102,374,232
4	Nelson Co-Owners	RQ	51				9,406
5	Midcontinent ISO, Inc.	OS	N/A				2,308,612	33,708	66,792,725	(c) 6,829,797	73,656,230
6	Entergy System Power Pool	OS	181							(d) 760,664	760,664
15	Subtotal - RQ						454,941	16,231,889	16,041,577		32,273,466
16	Subtotal-Non-RQ						7,259,026	206,590,564	144,969,240	7,590,461	359,150,265
17	Total						7,713,967	222,822,453	161,010,817	7,590,461	391,423,731

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityReceivingElectricityPurchasedForResale

Energy and capacity sales associated with MSS-4.

(b) Concept: NameOfCompanyOrPublicAuthorityReceivingElectricityPurchasedForResale

Energy and capacity sales associated with MSS-4.

(c) Concept: OtherChargesRevenueSalesForResale


			Charges
MISO Ancillary			$1,691,393
MISO Residual Load			12,056,957
MISO Uplift			(6,918,553)
Total Other Purchases from MISO			$6,829,797

(d) Concept: OtherChargesRevenueSalesForResale

Settlement of Rough Production Cost Equalization per FERC Docket Nos. EL10-65-008 and EL10-65-009.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

ELECTRIC OPERATION AND MAINTENANCE EXPENSES
If the amount for previous year is not derived from previously reported figures, explain in footnote.
Line No.	Account (a)	Amount for Current Year (b)	Amount for Previous Year (c) (c)
1	PowerProductionExpensesAbstract 1. POWER PRODUCTION EXPENSES
2	SteamPowerGenerationAbstract A. Steam Power Generation
3	SteamPowerGenerationOperationAbstract Operation
4	OperationSupervisionAndEngineeringSteamPowerGeneration (500) Operation Supervision and Engineering	9,497,756	9,752,674
5	FuelSteamPowerGeneration (501) Fuel	(a) 1,208,925,434	(b) 639,537,094
6	SteamExpensesSteamPowerGeneration (502) Steam Expenses	4,524,749	4,866,756
7	SteamFromOtherSources (503) Steam from Other Sources
8	SteamTransferredCredit (Less) (504) Steam Transferred-Cr.
9	ElectricExpensesSteamPowerGeneration (505) Electric Expenses	4,369,978	4,199,335
10	MiscellaneousSteamPowerExpenses (506) Miscellaneous Steam Power Expenses	12,127,516	12,405,305
11	RentsSteamPowerGeneration (507) Rents	178,430	127,190
12	Allowances (509) Allowances	61,877	217,668
13	SteamPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 4 thru 12)	1,239,685,740	671,106,022
14	SteamPowerGenerationMaintenanceAbstract Maintenance
15	MaintenanceSupervisionAndEngineeringSteamPowerGeneration (510) Maintenance Supervision and Engineering	3,052,613	2,792,333
16	MaintenanceOfStructuresSteamPowerGeneration (511) Maintenance of Structures	3,295,388	3,723,423
17	MaintenanceOfBoilerPlantSteamPowerGeneration (512) Maintenance of Boiler Plant	15,727,498	16,287,594
18	MaintenanceOfElectricPlantSteamPowerGeneration (513) Maintenance of Electric Plant	5,161,505	11,201,299
19	MaintenanceOfMiscellaneousSteamPlant (514) Maintenance of Miscellaneous Steam Plant	2,640,018	3,184,568
20	SteamPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 15 thru 19)	29,877,022	37,189,217
21	PowerProductionExpensesSteamPower TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)	1,269,562,762	708,295,239
22	NuclearPowerGenerationAbstract B. Nuclear Power Generation
23	NuclearPowerGenerationOperationAbstract Operation
24	OperationSupervisionAndEngineeringNuclearPowerGeneration (517) Operation Supervision and Engineering	66,882,889	63,766,346
25	NuclearFuelExpense (518) Fuel	96,293,500	98,062,624
26	CoolantsAndWater (519) Coolants and Water	15,557,493	15,010,207
27	SteamExpensesNuclearPowerGeneration (520) Steam Expenses	60,364,657	63,634,750
28	SteamFromOtherSourcesNuclearPowerGeneration (521) Steam from Other Sources
29	SteamTransferredCreditNuclearPowerGeneration (Less) (522) Steam Transferred-Cr.
30	ElectricExpensesNuclearPowerGeneration (523) Electric Expenses
31	MiscellaneousNuclearPowerExpenses (524) Miscellaneous Nuclear Power Expenses	58,301,639	53,620,323
32	RentsNuclearPowerGeneration (525) Rents	4,442,503	5,688,045
33	NuclearPowerGenerationOperationsExpense TOTAL Operation (Enter Total of lines 24 thru 32)	301,842,681	299,782,295
34	NuclearPowerGenerationMaintenanceAbstract Maintenance
35	MaintenanceSupervisionAndEngineeringNuclearPowerGeneration (528) Maintenance Supervision and Engineering	32,564,090	31,619,500
36	MaintenanceOfStructuresNuclearPowerGeneration (529) Maintenance of Structures	2,548,962	1,829,748
37	MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration (530) Maintenance of Reactor Plant Equipment	17,776,790	19,421,352
38	MaintenanceOfElectricPlantNuclearPowerGeneration (531) Maintenance of Electric Plant	7,886,916	8,420,913
39	MaintenanceOfMiscellaneousNuclearPlant (532) Maintenance of Miscellaneous Nuclear Plant	77,802,716	67,657,462
40	NuclearPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 35 thru 39)	138,579,474	128,948,975
41	PowerProductionExpensesNuclearPower TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)	440,422,155	428,731,270
42	HydraulicPowerGenerationAbstract C. Hydraulic Power Generation
43	HydraulicPowerGenerationOperationAbstract Operation
44	OperationSupervisionAndEngineeringHydraulicPowerGeneration (535) Operation Supervision and Engineering
45	WaterForPower (536) Water for Power
46	HydraulicExpenses (537) Hydraulic Expenses
47	ElectricExpensesHydraulicPowerGeneration (538) Electric Expenses
48	MiscellaneousHydraulicPowerGenerationExpenses (539) Miscellaneous Hydraulic Power Generation Expenses
49	RentsHydraulicPowerGeneration (540) Rents
50	HydraulicPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 44 thru 49)
51	HydraulicPowerGenerationContinuedAbstract C. Hydraulic Power Generation (Continued)
52	HydraulicPowerGenerationMaintenanceAbstract Maintenance
53	MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration (541) Mainentance Supervision and Engineering
54	MaintenanceOfStructuresHydraulicPowerGeneration (542) Maintenance of Structures
55	MaintenanceOfReservoirsDamsAndWaterways (543) Maintenance of Reservoirs, Dams, and Waterways
56	MaintenanceOfElectricPlantHydraulicPowerGeneration (544) Maintenance of Electric Plant
57	MaintenanceOfMiscellaneousHydraulicPlant (545) Maintenance of Miscellaneous Hydraulic Plant
58	HydraulicPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 53 thru 57)
59	PowerProductionExpensesHydraulicPower TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
60	OtherPowerGenerationAbstract D. Other Power Generation
61	OtherPowerGenerationOperationAbstract Operation
62	OperationSupervisionAndEngineeringOtherPowerGeneration (546) Operation Supervision and Engineering	4,953,672	4,640,112
63	Fuel (547) Fuel
64	GenerationExpenses (548) Generation Expenses	9,094,189	7,489,148
64.1	OperationOfEnergyStorageEquipment (548.1) Operation of Energy Storage Equipment
65	MiscellaneousOtherPowerGenerationExpenses (549) Miscellaneous Other Power Generation Expenses	22,521,222	19,475,685
66	RentsOtherPowerGeneration (550) Rents	447,562	467,465
67	OtherPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 62 thru 67)	37,016,645	32,072,410
68	OtherPowerGenerationMaintenanceAbstract Maintenance
69	MaintenanceSupervisionAndEngineeringOtherPowerGeneration (551) Maintenance Supervision and Engineering	1,064,709	1,122,917
70	MaintenanceOfStructures (552) Maintenance of Structures	1,379,895	1,213,815
71	MaintenanceOfGeneratingAndElectricPlant (553) Maintenance of Generating and Electric Plant	29,589,855	24,548,933
71.1	MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration (553.1) Maintenance of Energy Storage Equipment
72	MaintenanceOfMiscellaneousOtherPowerGenerationPlant (554) Maintenance of Miscellaneous Other Power Generation Plant	3,837,483	3,209,461
73	OtherPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 69 thru 72)	35,871,942	30,095,126
74	PowerProductionExpensesOtherPower TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)	72,888,587	62,167,536
75	OtherPowerSuplyExpensesAbstract E. Other Power Supply Expenses
76	PurchasedPower (555) Purchased Power	768,416,236	596,361,715
76.1	PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations	0
77	SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching	2,009,697	2,212,215
78	OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses	36,460,038	53,802,205
79	OtherPowerSupplyExpense TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)	733,965,895	544,771,725
80	PowerProductionExpenses TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)	2,516,839,399	1,743,965,770
81	TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES
82	TransmissionExpensesOperationAbstract Operation
83	OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering	5,646,518	5,549,595
85	LoadDispatchReliability (561.1) Load Dispatch-Reliability
86	LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System	6,210,910	6,432,449
87	LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling	163,572	228,577
88	SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services	18,054,684	16,672,086
89	ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development	1,229,140	1,491,302
90	TransmissionServiceStudies (561.6) Transmission Service Studies	5,914
91	GenerationInterconnectionStudies (561.7) Generation Interconnection Studies
92	ReliabilityPlanningAndStandardsDevelopmentServices (561.8) Reliability, Planning and Standards Development Services	2,372,735	1,473,075
93	StationExpensesTransmissionExpense (562) Station Expenses	613,427	574,826
93.1	OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment
94	OverheadLineExpense (563) Overhead Lines Expenses	1,876,076	1,621,638
95	UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses
96	TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others	28,236,100	24,657,960
97	MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses	3,235,561	3,653,826
98	RentsTransmissionElectricExpense (567) Rents	7,948,345	7,872,216
99	TransmissionOperationExpense TOTAL Operation (Enter Total of Lines 83 thru 98)	75,592,982	70,227,550
100	TransmissionMaintenanceAbstract Maintenance
101	MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering	7,781,297	7,850,077
102	MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures	938,268	974,235
103	MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware	4,946
104	MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software	195,772	69,466
105	MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment
106	MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant
107	MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment	4,065,999	4,554,690
107.1	MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment
108	MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines	9,827,437	9,845,538
109	MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines
110	MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant	307,344	149,769
111	TransmissionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 101 thru 110)	23,121,063	23,443,775
112	TransmissionExpenses TOTAL Transmission Expenses (Total of Lines 99 and 111)	98,714,045	93,671,325
113	RegionalMarketExpensesAbstract 3. REGIONAL MARKET EXPENSES
114	RegionalMarketExpensesOperationAbstract Operation
115	OperationSupervision (575.1) Operation Supervision
116	DayAheadAndRealTimeMarketAdministration (575.2) Day-Ahead and Real-Time Market Facilitation
117	TransmissionRightsMarketAdministration (575.3) Transmission Rights Market Facilitation
118	CapacityMarketAdministration (575.4) Capacity Market Facilitation
119	AncillaryServicesMarketAdministration (575.5) Ancillary Services Market Facilitation
120	MarketMonitoringAndCompliance (575.6) Market Monitoring and Compliance
121	MarketFacilitationMonitoringAndComplianceServices (575.7) Market Facilitation, Monitoring and Compliance Services	9,805,315	10,296,740
122	RentsRegionalMarketExpenses (575.8) Rents
123	RegionalMarketOperationExpense Total Operation (Lines 115 thru 122)	9,805,315	10,296,740
124	RegionalMarketExpensesMaintenanceAbstract Maintenance
125	MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses (576.1) Maintenance of Structures and Improvements
126	MaintenanceOfComputerHardware (576.2) Maintenance of Computer Hardware
127	MaintenanceOfComputerSoftware (576.3) Maintenance of Computer Software
128	MaintenanceOfCommunicationEquipmentRegionalMarketExpenses (576.4) Maintenance of Communication Equipment
129	MaintenanceOfMiscellaneousMarketOperationPlant (576.5) Maintenance of Miscellaneous Market Operation Plant
130	RegionalMarketMaintenanceExpense Total Maintenance (Lines 125 thru 129)
131	RegionalMarketExpenses TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)	9,805,315	10,296,740
132	DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES
133	DistributionExpensesOperationAbstract Operation
134	OperationSupervisionAndEngineeringDistributionExpense (580) Operation Supervision and Engineering	20,122,580	19,311,325
135	LoadDispatching (581) Load Dispatching	3,261,445	2,958,080
136	StationExpensesDistribution (582) Station Expenses	599,104	701,426
137	OverheadLineExpenses (583) Overhead Line Expenses	1,341,314	979,165
138	UndergroundLineExpenses (584) Underground Line Expenses	2,613,649	2,408,359
138.1	OperationOfEnergyStorageEquipmentDistribution (584.1) Operation of Energy Storage Equipment
139	StreetLightingAndSignalSystemExpenses (585) Street Lighting and Signal System Expenses	429,483	347,700
140	MeterExpenses (586) Meter Expenses	4,917,697	6,705,144
141	CustomerInstallationsExpenses (587) Customer Installations Expenses	1,913,234	1,509,570
142	MiscellaneousDistributionExpenses (588) Miscellaneous Expenses	7,843,731	6,615,879
143	RentsDistributionExpense (589) Rents	5,310,889	5,233,325
144	DistributionOperationExpensesElectric TOTAL Operation (Enter Total of Lines 134 thru 143)	48,353,126	46,769,973
145	DistributionExpensesMaintenanceAbstract Maintenance
146	MaintenanceSupervisionAndEngineering (590) Maintenance Supervision and Engineering	3,505,656	3,911,907
147	MaintenanceOfStructuresDistributionExpense (591) Maintenance of Structures	2,093,135	1,818,691
148	MaintenanceOfStationEquipment (592) Maintenance of Station Equipment	4,076,828	3,115,026
148.1	MaintenanceOfEnergyStorageEquipment (592.2) Maintenance of Energy Storage Equipment
149	MaintenanceOfOverheadLines (593) Maintenance of Overhead Lines	44,756,537	34,206,034
150	MaintenanceOfUndergroundLines (594) Maintenance of Underground Lines	3,738,385	2,662,650
151	MaintenanceOfLineTransformers (595) Maintenance of Line Transformers	319,215	189,889
152	MaintenanceOfStreetLightingAndSignalSystems (596) Maintenance of Street Lighting and Signal Systems	3,555,095	1,906,064
153	MaintenanceOfMeters (597) Maintenance of Meters	169,703	72,134
154	MaintenanceOfMiscellaneousDistributionPlant (598) Maintenance of Miscellaneous Distribution Plant	2,342,351	1,952,661
155	DistributionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 146 thru 154)	64,556,905	49,835,056
156	DistributionExpenses TOTAL Distribution Expenses (Total of Lines 144 and 155)	112,910,031	96,605,029
157	CustomerAccountsExpensesAbstract 5. CUSTOMER ACCOUNTS EXPENSES
158	CustomerAccountsExpensesOperationsAbstract Operation
159	SupervisionCustomerAccountExpenses (901) Supervision	739,207	1,047,744
160	MeterReadingExpenses (902) Meter Reading Expenses	9,895,025	12,134,639
161	CustomerRecordsAndCollectionExpenses (903) Customer Records and Collection Expenses	33,038,996	27,770,196
162	UncollectibleAccounts (904) Uncollectible Accounts	8,716,449	7,577,037
163	MiscellaneousCustomerAccountsExpenses (905) Miscellaneous Customer Accounts Expenses	185,706	74,707
164	CustomerAccountExpenses TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)	52,575,383	48,604,323
165	CustomerServiceAndInformationalExpensesAbstract 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166	CustomerServiceAndInformationalExpensesOperationAbstract Operation
167	SupervisionCustomerServiceAndInformationExpenses (907) Supervision	1,184,114	1,295,999
168	CustomerAssistanceExpenses (908) Customer Assistance Expenses	19,628,001	11,433,990
169	InformationalAndInstructionalAdvertisingExpenses (909) Informational and Instructional Expenses	1,777,760	1,513,742
170	MiscellaneousCustomerServiceAndInformationalExpenses (910) Miscellaneous Customer Service and Informational Expenses	2,864,483	2,329,297
171	CustomerServiceAndInformationExpenses TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)	25,454,358	16,573,028
172	SalesExpenseAbstract 7. SALES EXPENSES
173	SalesExpenseOperationAbstract Operation
174	SupervisionSalesExpense (911) Supervision	4,662	3,901
175	DemonstratingAndSellingExpenses (912) Demonstrating and Selling Expenses	2,979,848	3,033,623
176	AdvertisingExpenses (913) Advertising Expenses	467,378	461,011
177	MiscellaneousSalesExpenses (916) Miscellaneous Sales Expenses	150,985	291,962
178	SalesExpenses TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)	3,602,873	3,790,497
179	AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
180	AdministrativeAndGeneralExpensesOperationAbstract Operation
181	AdministrativeAndGeneralSalaries (920) Administrative and General Salaries	95,381,959	85,317,090
182	OfficeSuppliesAndExpenses (921) Office Supplies and Expenses	4,001,547	4,505,176
183	AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit
184	OutsideServicesEmployed (923) Outside Services Employed	38,282,169	34,736,144
185	PropertyInsurance (924) Property Insurance	20,357,351	14,173,457
186	InjuriesAndDamages (925) Injuries and Damages	16,727,294	20,672,921
187	EmployeePensionsAndBenefits (926) Employee Pensions and Benefits	133,222,952	125,126,850
188	FranchiseRequirements (927) Franchise Requirements
189	RegulatoryCommissionExpenses (928) Regulatory Commission Expenses	7,704,511	7,384,919
190	DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr.
191	GeneralAdvertisingExpenses (930.1) General Advertising Expenses	1,185,382	1,496,047
192	MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses	8,960,424	10,595,959
193	RentsAdministrativeAndGeneralExpense (931) Rents	1,184,055	1,759,675
194	AdministrativeAndGeneralOperationExpense TOTAL Operation (Enter Total of Lines 181 thru 193)	327,007,644	305,768,238
195	AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance
196	MaintenanceOfGeneralPlant (935) Maintenance of General Plant	3,264,838	4,002,555
197	AdministrativeAndGeneralExpenses TOTAL Administrative & General Expenses (Total of Lines 194 and 196)	330,272,482	309,770,793
198	OperationsAndMaintenanceExpensesElectric TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)	3,150,173,886	2,323,277,505

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: FuelSteamPowerGeneration

Includes ($4,298,866) related to certain gas hedging activities.

(b) Concept: FuelSteamPowerGeneration

Includes $3,048,267 related to certain gas hedging activities.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

PURCHASED POWER (Account 555)
Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatthours shown on bills rendered to the respondent, excluding purchases for energy storage. Report in column (h) the megawatthours shown on bills rendered to the respondent for energy storage purchases. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. The data in columns (g) through (n) must be totaled on the last line of the schedule. The total amount in columns (g) and (h) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13. Footnote entries as required and provide explanations following all required data.
					Actual Demand (MW)				POWER EXCHANGES		COST/SETTLEMENT OF POWER
Line No.	NameOfCompanyOrPublicAuthorityProvidingPurchasedPower Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	RateScheduleTariffNumber Ferc Rate Schedule or Tariff Number (c)	AverageMonthlyBillingDemand Average Monthly Billing Demand (MW) (d)	AverageMonthlyNonCoincidentPeakDemand Average Monthly NCP Demand (e)	AverageMonthlyCoincidentPeakDemand Average Monthly CP Demand (f)	MegawattHoursPurchasedOtherThanStorage MegaWatt Hours Purchased (Excluding for Energy Storage) (g)	MegawattHoursPurchasedForEnergyStorage MegaWatt Hours Purchased for Energy Storage (h)	EnergyReceivedThroughPowerExchanges MegaWatt Hours Received (i)	EnergyDeliveredThroughPowerExchanges MegaWatt Hours Delivered (j)	DemandChargesOfPurchasedPower Demand Charges ($) (k)	EnergyChargesOfPurchasedPower Energy Charges ($) (l)	OtherChargesOfPurchasedPower Other Charges ($) (m)	SettlementOfPower Total (k+l+m) of Settlement ($) (n)
1	(a) Entergy Texas, Inc.	LU					1,364,346				17,162,695	47,161,699		64,324,394
2	(b) Entergy Arkansas, LLC	LU					757,233				28,272,731	6,842,614		35,115,345
3	(c) System Energy Resources, Inc.	LU					1,483,080				74,269,931	8,163,876		82,433,807
4	Midcontinent ISO, Inc.	OS					7,528,940				736,869	298,399,888	(d) 5,748,029	304,884,786
5	EDF Trading North America, LLC	OS											(e) 213,249	213,249
6	Agrilectric Power Partners LP	OS					73,706				1,064,868	4,398,601	(f) 63,034	5,400,435
7	LA3 West Baton Rouge, LLC	OS					113,230				1,512,925	3,517,460	(g) 55,798	4,974,587
8	TX LFG Energy, LP	OS					41					119,841	(h) 119,841
9	Occidental Power Services, Inc.	OS					1,988,571				36,143,866	73,112,494	(i) 1,265,363	110,521,723
10	Rain CII Carbon LLC	OS					227,919				3,947,499	9,172,771	(j) 165,015	12,955,255
11	Sam A. Murray Hydroelectric	OS					888,656					131,148,622		131,148,622
12	Sabine River Authority of TX	OS	163				147,860					6,439,480	(k) 17,860	6,421,620
13	APX North American Renewables	OS											(l) 2,000	2,000
14	Evonik	OS					9,374					339,933		339,933
15	Mosaic Phosphates	OS					149					5,946		5,946
16	Lafourche Sugars	OS					155					5,966		5,966
17	Eco Services	OS					38,978					2,701,376		2,701,376
18	South Alexander	OS					4,598					306,126		306,126
19	Small Residential Generation	OS					49,467					1,666,750		1,666,750
20	Capacity Deferrals	OS											(m) 5,420,814	5,420,814
15	TOTAL						14,676,221				163,111,384	593,503,443	11,801,409	768,416,236

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower

Energy and capacity charges associated with MSS-4.

(b) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower

Energy and capacity charges associated with MSS-4.

(c) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower

Energy and capacity charges from Grand Gulf Nuclear Power Plant.

(d) Concept: OtherChargesOfPurchasedPower


			CHARGES
MISO Ancillary			$4,034,613
MISO Congestion			(28,885,174)
MISO Residual Load			10,845,767
MISO Losses			(12,772,689)
MISO Uplift			31,440,279
MISO Administration			1,085,233
Total Other Purchases from MISO			$5,748,029

(e) Concept: OtherChargesOfPurchasedPower

Related to the sale of Entergy Louisiana's Auction Revenue Rights allocated to Entergy Louisiana as part of its participation in MISO.

(f) Concept: OtherChargesOfPurchasedPower

Related to non-energy MISO Charges/(Credits) passed on to counterparty through purchase power agreement.

(g) Concept: OtherChargesOfPurchasedPower

Liquidated Damages for delays in the initial operating date of the LA3 Solar Station.

(h) Concept: OtherChargesOfPurchasedPower

Related to non-energy MISO Charges/(Credits) passed on to counterparty through purchase power agreement.

(i) Concept: OtherChargesOfPurchasedPower

Related to non-energy MISO Charges/(Credits) passed on to counterparty through purchase power agreement.

(j) Concept: OtherChargesOfPurchasedPower

Related to non-energy MISO Charges/(Credits) passed on to counterparty through purchase power agreement.

(k) Concept: OtherChargesOfPurchasedPower

Related to non-energy MISO Charges/(Credits) passed on to counterparty through purchase power agreement.

(l) Concept: OtherChargesOfPurchasedPower

Renewable Energy Credit registration fee

(m) Concept: OtherChargesOfPurchasedPower

Deferral of capacity related Acadia, Occidental, Calpine, Perryville, Agrielectric, Entergy Arkansas MSS-4, Entergy Louisiana River Bend MSS-4, LA3 Solar PPA and planning resource adequacy.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

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

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

TRANSFER OF ENERGY

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS

Line No.

(a)

(b)

(c)

(d)

(e)

(f)

(g)

(h)

(i)

(j)

(k)

(l)

(m)

(n)

1

MISO

Various

84,107,614

2

Vinton Public Power Authority

(a)

14,863,318

35

TOTAL

84,107,614

14,863,318

98,970,932

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers

Transmission and ancillary service charges.

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

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

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. Enter ""TOTAL"" in column (a) as the last line. Footnote entries and provide explanations following all required data.
			TRANSFER OF ENERGY		EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.	NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	TransmissionOfElectricityByOthersEnergyReceived MegaWatt Hours Received (c)	TransmissionOfElectricityByOthersEnergyDelivered MegaWatt Hours Delivered (d)	DemandChargesTransmissionOfElectricityByOthers Demand Charges ($) (e)	EnergyChargesTransmissionOfElectricityByOthers Energy Charges ($) (f)	OtherChargesTransmissionOfElectricityByOthers Other Charges ($) (g)	ChargesForTransmissionOfElectricityByOthers Total Cost of Transmission ($) (h)
1	Midcontinent Independent System Operator Inc				(a) 28,191,209		(b) 44,891	28,236,100
	TOTAL		0	0	28,191,209	0	44,891	28,236,100

FOOTNOTE DATA

(a) Concept: DemandChargesTransmissionOfElectricityByOthers

The Utility operating companies are transmission owning members of the Midcontinent Independent System Operator (MISO) RTO. MISO is the transmission provider under the MISO Attachment O. Entergy Louisiana incurred charges from MISO for the purchase of network transmission service under the MISO Attachment O. MISO calculated the network service charges applicable to Entergy Louisiana and billed the entity for such service.

(b) Concept: OtherChargesTransmissionOfElectricityByOthers

Network upgrade charges incurred from MISO under the MISO Attachment O. Rates are calculated under Attachment GG. Charges are related to the MTEP (MISO Transmission Expansion Plan).

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.	Description (a)	Amount (b)
1	IndustryAssociationDues Industry Association Dues	916,457
2	NuclearPowerResearchExpenses Nuclear Power Research Expenses
3	OtherExperimentalAndGeneralResearchExpenses Other Experimental and General Research Expenses
4	PublicationAndDistributionExpensesForSecuritiesToStockholders Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities	848,101
5	OtherMiscellaneousGeneralExpenses Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6	5% surcharge on regulated billings to non-regulated affiliates	1,515,421
7	IT hardward applications/service contracts	10,641,145
8	Vidalia MTM - initial tax year	123,694
9	System aircraft	1,278,960
10	Corporate purchasing card rebates	815,363
11	Co-owner Big Cajun	431,250
12	Co-owner Nelson	3,116,182
13	HR leadsership development	59,995
14	Directors meetings and expenses	2,714
15	Travel to reimburse project	41,200
16	Section 263A tax research	109,612
17	Mobile device service	23,241
18	Other	13,421
46	MiscellaneousGeneralExpenses TOTAL	8,960,424

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
Report in section A for the year the amounts for: (b) Depreciation Expense (Account 403); (c) Depreciation Expense for Asset Retirement Costs (Account 403.1); (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405). Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year. Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used. In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used. For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type of mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
	A. Summary of Depreciation and Amortization Charges
Line No.	FunctionalClassificationAxis Functional Classification (a)	DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments Depreciation Expense (Account 403) (b)	DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments Depreciation Expense for Asset Retirement Costs (Account 403.1) (c)	AmortizationOfLimitedTermPlantOrProperty Amortization of Limited Term Electric Plant (Account 404) (d)	AmortizationOfOtherElectricPlant Amortization of Other Electric Plant (Acc 405) (e)	DepreciationAndAmortization Total (f)
1	Intangible Plant			(a) 60,780,107		60,780,107
2	Steam Production Plant	38,483,952	356,220			38,127,732
3	Nuclear Production Plant	120,287,094	13,642,713			133,929,807
4	Hydraulic Production Plant-Conventional
5	Hydraulic Production Plant-Pumped Storage
6	Other Production Plant	106,765,398				106,765,398
7	Transmission Plant	115,672,862				115,672,862
8	Distribution Plant	156,798,467				156,798,467
9	Regional Transmission and Market Operation
10	General Plant	(b) 28,326,774				28,326,774
11	Common Plant-Electric
12	TOTAL	566,334,547	13,286,493	60,780,107		640,401,147

B. Basis for Amortization Charges

	C. Factors Used in Estimating Depreciation Charges
Line No.	AccountNumberFactorsUsedInEstimatingDepreciationCharges Account No. (a)	DepreciablePlantBase Depreciable Plant Base (in Thousands) (b)	UtilityPlantEstimatedAverageServiceLife Estimated Avg. Service Life (c)	UtilityPlantNetSalvageValuePercentage Net Salvage (Percent) (d)	UtilityPlantAppliedDepreciationRate Applied Depr. Rates (Percent) (e)	MortalityCurveType Mortality Curve Type (f)	UtilityPlantWeightedAverageRemainingLife Average Remaining Life (g)
12	Production Nuclear - WF3	3,627.442	40 years	7	1.53		23 years
13	Prod Nuclear-WF3 New Stm Gen	557.23	12 years		3.32		23 years
14	Production Other - Functional Rate	0.707	26 years, 2 months		0.93
15	Acadia Plant Common	19.698			3.12
16	Acadia Power Block 2	198.666			3.12
17	J. Wayne Leonard SP1	781.09			3.12
18	Ninemile Point Unit No. 6	625.135			3.12
19	Perryville Common	13.303			3.12
20	Perryville Unit 1	191.919			3.12
21	Perryville Unit 2	24.668			3.12
22	Washington Parish Unit 1	208.444			3.12
23	WF Startup Unit - WF4	27.034			3.23
24	Production Steam	829.901	36 years, 5 months	18	3.23
25	Transmission Plt	2,646.551	39 years, 8 months	14	2.85
26	Distribution Plt	3,464.207	30 years, 6 months	12	3.37
27	General Plant Exlcuding L.I.	217.945	23 years, 4 months	3	3.17
28	General Plant - L.I. 3901	2.901
29	Big Cajun Common 311	1.14			2.47
30	Big Cajun Common 312	1.356			2.47
31	Big Cajun Common 314	0.377			2.47
32	Big Cajun Common 315	1.148			2.47
33	Big Cajun Common 316	0.723			2.47
34	Big Cajun Unit 3 311	26.626	40 years	4	2.47
35	Big Cajun Unit 3 312	81.878	40 years	4	2.47
36	Big Cajun Unit 3 314	22.892	40 years	4	2.47
37	Big Cajun Unit 3 315	16.474	40 years	4	2.47
38	Big Cajun Unit 3 316	1.117	40 years	4	2.47
39	LA Sta No 2 Com 311	0.895			2.37
40	LA Sta No 2 Com 312	2.862			2.63
41	LA Sta No 2 Com 314	1.291			2.92
42	LA Sta No 2 Com 315	2.019			2.74
43	LA Sta No 2 Com 316	0.121			2.21
44	LA Sta No 2 Unit 7 311	2.568			2.37
45	LA Sta No 2 Unit 7 312	8.163			2.63
46	LA Sta No 2 Unit 7 314	8.506			2.92
47	LA Sta No 2 Unit 7 315	2.733			2.74
48	LA Sta No 2 Unit 9 311	0.633			2.37
49	LA Sta No 2 Unit 9 312	3.107			2.63
50	LA Sta No 2 Unit 9 314	2.657			2.92
51	LA Sta No 2 Unit 9 315	1.366			2.74
52	Nelson Common 311	1.396			1.7
53	Nelson Common 312	3.754			1.7
54	Nelson Common 314	0.087			1.7
55	Nelson Common 315	0.516			1.7
56	Nelson Common 316	0.871			1.7
57	Nelson Common, NL0 311	9.9	61 years	7	1.7
58	Nelson Common, NL0 312	8.565	61 years	7	1.7
59	Nelson Common, NL0 314	0.479	61 years	7	1.7
60	Nelson Common, NL0 315	1.267	61 years	7	1.7
61	Nelson Common, NL0 316	0.844	61 years	7	1.7
62	Nelson Unit 4 311	0.024	40 years	14	2.6
63	Nelson Unit 6 311	40.55			2.43
64	Nelson Unit 6 312	174.414			2.43
65	Nelson Unit 6 314	42.867			2.43
66	Nelson Unit 6 315	28.745			2.43
67	Nelson Unit 6 316	2.239			2.43
68	(c) Contra-Sec 311 (Note1)	0.078
69	(d) Contra-Sec 312 (Note1)	0.496
70	(e) Contra-Sec 314 (Note1)	0.238
71	(f) Contra-Sec 315 (Note1)	0.033
72	Calcasieu Com 341	0.564			2.72
73	Calcasieu Com 343	4.333			2.72
74	Calcasieu Com 344	11.424			2.72
75	Calcasieu Com 345	0.952			2.72
76	Calcasieu Com 346	2.161			2.72
77	Calcasieu Unit 1 341	0.076			2.72
78	Calcasieu Unit 1 343	5.648			2.72
79	Calcasieu Unit 1 344	22.997			2.72
80	Calcasieu Unit 1 345	0.494			2.72
81	Calcasieu Unit 1 346	0.037			2.72
82	Calcasieu Unit 2 341	0.02			2.72
83	Calcasieu Unit 2 343	1.684			2.72
84	Calcasieu Unit 2 344	30.434			2.72
85	Calcasieu Unit 2 345	0.522			2.72
86	Calcasieu Unit 2 346	0.048			2.72
87	Lake Charles Pwr Station 341	66.771			3.12
88	Lake Charles Pwr Station 342	193.129			3.12
89	Lake Charles Pwr Station 343	2.719			3.12
90	Lake Charles Pwr Station 344	408.866			3.12
91	Lake Charles Pwr Station 345	105.5			3.12
92	Lake Charles Pwr Station 346	18.348			3.12
93	Ouachita Com 341	4.99			3.12
94	Ouachita Com 342	0.074			3.12
95	Ouachita Com 343	4.999			3.12
96	Ouachita Com 344	5.287			3.12
97	Ouachita Com 345	0.457			3.12
98	Ouachita Com 346	0.778			3.12
99	Ouachita Gas Yd 342	2.218			3.12
100	Ouachita Unit 3 341	3.429			3.12
101	Ouachita Unit 3 342	0.051			3.12
102	Ouachita Unit 3 343	5.353			3.12
103	Ouachita Unit 3 344	50.681			3.12
104	Ouachita Unit 3 345	1.326			3.12
105	Ouachita Unit 3 346	0.262			3.12
106	Union Power Block 3 341	7.705			3.12
107	Union Power Block 3 342	1.503			3.12
108	Union Power Block 3 343	119.93			3.12
109	Union Power Block 3 344	35.641			3.12
110	Union Power Block 3 345	13.088			3.12
111	Union Power Block 3 346	0.018			3.12
112	Union Power Block 4 341	7.877			3.12
113	Union Power Block 4 342	1.503			3.12
114	Union Power Block 4 343	134.197			3.12
115	Union Power Block 4 344	35.267			3.12
116	Union Power Block 4 345	12.871			3.12
117	Union Power Block 4 346	0.018			3.12
118	Union Power Common - All Units 342	0.751			3.12
119	Union Power Common - All Units 343	2.707			3.12
120	Union Power Common - All Units 345	2.714			3.12
121	UPB 3&4 341	1.008			3.12
122	UPB 3&4 345	0.149			3.12
123	UPC - All Units 341	51.01			3.12
124	UPC - All Units 346	1.006			3.12
125	Riverbend Nuclear 321	1,470.424	40 years		1.47		24 years
126	Riverbend Nuclear 322	895.022	40 years		1.47		24 years
127	Riverbend Nuclear 323	448.655	40 years		1.47		24 years
128	Riverbend Nuclear 324	712.398	40 years		1.47		24 years
129	Riverbend Nuclear 325	158.126	40 years		1.47		24 years
130	(g) Contra UA 321	5.905
131	(h) Contra UA 325	0.243
132	Transmission Plant 350.2	23.597	65 years		1.38	R5	49 years, 6 months
133	Transmission Plant 350.3	82.786	65 years		1.38	R5	49 years, 6 months
134	Transmission Plant 352	95.82	45 years	5	1.77	R3	28 years, 7 months
135	Transmission Plant 353	1,081.186	43 years	5	2.01	R2.5	26 years, 7 months
136	Transmission Plant 354	79.058	45 years	5	1.75	R5	25 years, 4 months
137	Transmission Plant 355	830.285	50 years	25	2.39	R4	33 years, 1 month
138	Transmission Plant 356.1	480.747	55 years	20	1.82	R4	36 years, 4 months
139	Transmission Plant 356.2	9.504	55 years	20	1.82	R4	36 years, 4 months
140	Transmission Plant 356.3	63.558	55 years	20	1.82	R4	36 years, 4 months
141	Transmission Plant 357	0.008	60 years		0.05	R3	46 years
142	Transmission Plant 358	0.247	40 years	5	0.18	R2.5	21 years, 5 months
143	Transmission Plant 359	1.039	65 years		0.42	R5	33 years, 10 months
144	(i) Contra UA 352	0.386
145	(j) Contra UA 353	0.957
146	(k) Contra UA 354	1.104
147	(l) Contra UA 355	12.609
148	(m) Contra UA 3561	10.281
149	Distribution Plant 360.2	5.162	50 years		2.12	R5	34 years
150	Distribution Plant 361	31.274	45 years	5	1.44	S2	23 years, 4 months
151	Distribution Plant 362	349.682	34 years	15	1.97	R2	19 years, 7 months
152	Distribution Plant 364	366.279	40 years	30	2.96	R2.5	28 years
153	Distribution Plant 365.1	365.433	40 years	10	1.6	S1	28 years, 5 months
154	Distribution Plant 365.3	25.402	40 years	10	1.6	S1	28 years, 5 months
155	Distribution Plant 366	147.654	60 years		1.54	R3	50 years, 1 month
156	Distribution Plant 367	181.86	40 years	5	2.58	R2.5	31 years, 2 months
157	Distribution Plant 368.1	634.873	39 years		2.31	S0	28 years, 10 months
158	Distribution Plant 369.1	181.334	36 years	10	2.86	R5	23 years, 8 months
159	Distribution Plant 369.2	145.073	36 years	10	2.86	R5	23 years, 8 months
160	Distribution Plant 370	51.708	33 years		2.76	R2.5	20 years, 11 months
161	Distribution Plant 370.1	3.413			2.76
162	Distribution Plant 370.15	143.746			6.67
163	Distribution Plant 371	122.282	39 years		2.57	S0	36 years, 1 month
164	Distribution Plant 373	105.942	40 years	20	1.06	R2.5	27 years, 5 months
165	Distribution Plant 373.2	0.009			1.06
166	(n) Contra UA 361	0.071
167	(o) Contra UA 362	1.218
168	(p) Contra UA 364	48.636
169	(q) Contra UA 3651	13.725
170	(r) Contra UA 3651 2	13.134
171	(s) Contra UA 366 1	0.165
172	(t) Contra UA 366 2	0.057
173	(u) Contra UA 367	0.996
174	(v) Contra UA 3681	55.319
175	(w) Contra UA 3691	10.08
176	(x) Contra UA 3692	0.758
177	(y) Contra UA 371	4.98
178	(z) Contra UA 373	4.743
179	General Plant 390	76.97	40 years		2.25	R4	28 years, 5 months
180	General Plant 391.1	1.409	26 years	5	4.38	R2.5	15 years
181	General Plant 391.2	24.429	10 years		20	R2.5	7 years, 4 months
182	General Plant 391.3	1.903	5 years		15	R4	8 months
183	General Plant 392	0.442	20 years		1.82	R5	11 years, 7 months
184	General Plant 393	0.135	25 years		4.24	R3	15 years, 8 months
185	General Plant 394	8.734	20 years		6.79	R5	10 years, 7 months
186	General Plant 395	3.311	22 years		4.87	R5	15 years, 1 month
187	General Plant 396	0.766	16 years		5.36	R3	7 years, 4 months
188	General Plant 397.1	16.842	19 years		5.93	S3	9 years, 11 months
189	General Plant 397.2	16.297	19 years		5.93	S3	9 years, 11 months
190	General Plant 398	1.686	24 years		4.63	R5	13 years, 1 month
191	General Plant 391.1_RES	0.007
192	General Plant 391.2_RES	0.041
193	General Plant 391.3_RES	0.008
194	General Plant 392_RES	0.002
195	General Plant 393_RES	0.007
196	General Plant 394_RES	0.01
197	General Plant 395_RES	0.035
198	General Plant 396_RES	0.001
199	General Plant 397.1_RES	0.023
200	General Plant 397.2_RES	0.034
201	General Plant 398_RES	0.011
202	(aa) Contra UA 390	3.365
203	(ab) Contra UA 3912	0.002
204	(ac) Contra UA 3972	0.007
205	(ad) Contra UA 3972 2	0.024

Name of Respondent:

Entergy Louisiana, LLC

This report is:

(1)

☐ An Original

(2)

☑ A Resubmission

Date of Report:

04/19/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: AmortizationOfLimitedTermPlantOrProperty

Includes $2,364 of service company amortization billing allocations.

(b) Concept: DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments

Includes $12,616,767 of service company depreciation billing allocations.

(c) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges