CNRO-2019-00007, Grand Gulf Nuclear Station; and Waterford 3 Steam Electric Station - Decommissioning Funding Status Report

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Grand Gulf Nuclear Station; and Waterford 3 Steam Electric Station - Decommissioning Funding Status Report
ML19087A327
Person / Time
Site: Grand Gulf, Arkansas Nuclear, River Bend, Waterford  Entergy icon.png
Issue date: 03/28/2019
From: Halter M
Entergy Operations
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
CNRO-2019-00007
Download: ML19087A327 (66)
v • d • e


Text

Entergy Operations, Inc.

1340 Echelon Parkway Jackson, MS 39213 Tel 601-368-5573 Mandy K. Halter Director, Nuclear Licensing 10 CFR 50.75(f)(1)

CNRO-2019-00007 March 28, 2019 ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001

SUBJECT:

Decommissioning Funding Status Report - Entergy Operations, Inc Arkansas Nuclear One, Units 1 & 2 River Bend Station NRC Docket Nos. 50-313 & 50-368 NRC Docket No. 50-458 Grand Gulf Nuclear Station Waterford 3 Steam Electric Station NRC Docket No. 50-416 NRC Docket No. 50-382

References:

1) NUREG-1307, Report on Waste Burial Charges, Revision 17, dated February 2019.
2) NRC Regulatory Issue Summary 2001-07, 10 CFR 50.75(f)(1) Reports on the Status of Decommissioning Funds (Due March 31, 2001).

Dear Sir or Madam:

10 CFR 50.75(f)(1) requires each power reactor licensee to report to the NRC by March 31, 1999, and every two years thereafter, on the status of its decommissioning funding for each reactor, or share of a reactor, that it owns. On behalf of Entergy Arkansas, LLC for Arkansas Nuclear One (ANO), System Entergy Resources, Inc. (SERI) and Cooperative Energy (formerly South Mississippi Electric Power Association (SMEPA)) for Grand Gulf Nuclear Station (GGNS),

Entergy Louisiana, LLC for for River Bend Station (RBS) and Waterford 3 Steam Electric Station (WF3), Entergy Operations, Inc. hereby submits the information requested for power reactors operated by Entergy Operations, Inc.

The estimated minimum decommissioning fund values were determined using the NRCs methodology in NUREG-1307, Rev 17.

The 70 percent regulated interest of RBS contains funds accumulated for separate rate regulatory jurisdictions. There are not separate trust funds for the individual jurisdictions responsible for decommissioning of the 70 percent regulated share of RBS. Balances in the nuclear decommissioning trust for the 70 percent regulated share of RBS attributable to the

CNRO-2019-00007 Page 2 of 4 separate jurisdictions are accounted for by the Trustee, the Bank of New York Mellon. The following information provides the balances in the 70 percent regulated share trust attributable to each of the relevant jurisdictions as of December 31, 2018:

Louisiana $182,696,235 Texas $212,747,177 FERC $ 11,361,349 The trust fund amounts reported for each facility in the responses to item 3 in the attachments represent the market value of decommissioning trust funds as of December 31, 2018 net of any material current income tax liability on realized gains, interest, dividends and other income of the trusts. Cooperative Energy is a not-for-profit electric cooperative, and is exempt from federal income tax. Accordingly, the amounts reported as of December 31, 2018 of funds separately accumulated by Cooperative Energy for GGNS decommissioning were after-tax amounts. The trusts for the following plants had balances on their 2018 tax liabilities (in thousands), not reflected in the trust fund balances, as follows (does not include Cooperative Energy):

ANO $ 0 GGNS $ 0 RBS $ 0 WF3 $ 0 In accordance with guidance provided by the NRC Staff in April 2014 requests for additional information (Accession No. ML14120A273) that [f]uture 10 CFR 50.75(f) reports should clearly delineate estimated reactor and ISFSI decommissioning costs, the information in Attachments 1-4 includes line item 2 identifying the ISFSI decommissioning obligation, from the most recent 10 CFR 72.30 filing. This obligation is also accounted for in the Excess/Shortfall calculations for each plant in Attachment 5.

The information provided in Attachments 1-4 is based on NRC Regulatory Issue Summary 2001-07. Consistent with your letter dated March 11, 2011 (Accession No. ML110280410),

we are providing with this submittal or incorporating by reference certain agreements providing for original (not resale) nuclear plant power sales (that may, from time to time, include decommissioning collections) between Entergy operating companies that invoke Federal Energy Regulatory Commission (FERC) tariffs. Considering these agreements and the applicable NRC regulations, Entergy respectfully asserts that these rate-making tariffs should not be viewed as contractual obligations as that term is used within 10 CFR 50.75(e)(1)(v).

These arrangements describe exchanges among regulated utilities that operate within the confines of a FERC-approved tariff, under the ratemaking jurisdiction of the FERC. As such, the various agreements are simply extensions of the FERC tariff and not the type of contractual obligations contemplated by 10 CFR 50.75(e)(1)(v), and Entergys decommissioning funding is still provided by the external sinking fund method in accordance with 10 CFR 50.75(e)(1)(ii). In an abundance of caution and in a spirit of cooperation, however, Entergy is providing or incorporating various tariff agreements for each affected plant.

Additionally, Attachment 5 includes Minimum Funding Assurance calculation worksheets (not required for this filing) derived from LIC-205 Revision 4 for the plants, provided for the convenience of the reviewer.

CNRO-2019-00007 Page 3 of 4 The aforementioned worksheets, using the December 31, 2018 trust fund balances, indicate that all of the plants covered by this submittal met or exceeded the NRCs funding requirements.

This submittal contains no new commitments. If you have any questions, please contact me at 601-368-5573.

Respectfully, MKH/LJS/gpn Attachments:

1. Entergy Arkansas, LLC - ANO 1 & 2 Status Reports 1-A Entergy Arkansas, LLC - Calculation of Minimum Amount 1-B Schedule of Remaining Principal Payments - ANO-2 1-C ANO Purchase Power Agreements
2. SERI & Cooperative Energy - GGNS Status Report 2-A SERI & Cooperative Energy - Calculation of Minimum Amount
3. Entergy Louisiana, LLC RBS Status Report - 70% Regulated 3-A Entergy Louisiana, LLC - Calculation of Minimum Amount 3-B Schedule of Remaining Principal Payments - RBS 3-C Entergy Louisiana, LLC RBS Status Report - 30% Non-Regulated 3-D River Bend 70% Purchase Power Agreement 3-E River Bend 30% Purchase Power Agreement
4. Entergy Louisiana, LLC - Waterford 3 Status Report 4-A Entergy Louisiana, LLC - Calculation of Minimum Amount 4-B Schedule of Remaining Principal Payments - Waterford 3 4-C Waterford 3 Purchase Power Agreement
5. Minimum Funding Assurance Calculation Worksheets

CNRO-2019-00007 Page 4 of 4 cc: USNRC Regional Administrator, Region IV USNRC Project Manager, ANO USNRC Project Manager, GGN USNRC Project Manager, RBS USNRC Project Manager, WF3 USNRC Resident Inspector, ANO USNRC Resident Inspector, GGN USNRC Resident Inspector, RBS USNRC Resident Inspector, WF3 Arkansas Department of Health Mississippi Department of Health Louisiana Department of Environmental Quality

CNRO-2019-00007 Page 1 of 2 ENTERGY ARKANSAS, LLC Status Report of Decommissioning Funding For Year Ending December 31, 2018 - 10 CFR 50.75(f)(1)

Plant Name: Arkansas Nuclear One Unit 1 (ANO 1)

1. Minimum Financial Assurance (MFA)

Estimated per 10 CFR 50.75(b) and (c) (2018$): $472.4 million1

2. ISFSI Obligation as of 12/31/18 $7.36 million2
3. Decommissioning Trust Fund Total As of 12/31/18: $506.7 million
4. Annual amounts remaining to be collected: $03
5. Assumptions used in determining rates of escalation in decommissioning costs, rates of earnings on decommissioning funds, and rates of other factors used in funding projections 2% annual real rate of return per 10 CFR 50.75(e)(1)(i)
6. Contracts upon which licensee is relying For Decommissioning Funding: See Footnote4
7. Modifications to Method of Financial Assurance since Last Report: None
8. Material Changes to Trust Agreements: None 1

See Attachment 1-A 2

From Entergys ISFSI Decommissioning Funding Plans Pursuant to 10 CFR 72.30, December 17, 2018 (Accession No. ML18351A491). The ISFSI obligation is shared equally between ANO 1 and ANO 2.

3 Decommissioning funding has been suspended by the Arkansas Public Service Commission in Docket No. 87-166-TF. The NRC has granted license renewal to May 20, 2034.

4 See the agreements in attachment 1-C for unit power purchase agreements under FERC tariffs for ANO. The licensee believes these contracts do not qualify as contractual obligations, but rather are simply cost of service recovery mechanisms as defined in 10 CFR §50.75(e)(1)(ii)(A). Out of an abundance of caution, the licensee identifies this information here. By FERC Order dated March 21, 2019, these agreements were modified to substitute Entergy Arkansas, LLC for Entergy Arkansas, Inc. As of the date of this filing, executed copies of the amended agreements were not available.

CNRO-2019-00007 Page 2 of 2 ENTERGY ARKANSAS, LLC Status Report of Decommissioning Funding For Year Ending December 31, 2018 - 10 CFR 50.75(f)(1)

Plant Name: Arkansas Nuclear One Unit 2 (ANO 2)

1. Minimum Financial Assurance (MFA)

Estimated per10CFR50.75(b) and (c) (2018$): $491.9 million1

2. ISFSI Obligation as of 12/31/18 $7.36 million2
3. Decommissioning Fund Total As of 12/31/18: $405.3 million
4. Annual amounts remaining to be collected: See Attachment 1-B3
5. Assumptions used in determining rates of escalation in decommissioning costs, rates of earnings on decommissioning funds, and rates of other factors used in funding projections: 2% annual real rate of return per 10 CFR 50.75(e)(1)(i)
6. Contracts upon which licensee is relying None For Decommissioning Funding:
7. Modifications to Method of Financial Assurance since Last Report: None
8. Material Changes to Trust Agreements: None 1

See Attachment 1-A 2

From Entergys ISFSI Decommissioning Funding Plans Pursuant to 10 CFR 72.30, December 17, 2018 (Accession No. ML18351A491). The ISFSI obligation is shared equally between ANO 1 and ANO 2.

3 Decommissioning funding has been allowed by the Arkansas Public Service Commission in Revised Attachment A to Rider NDCR in Order No. 66 in Docket No. 87-166-TF.

CNRO-2019-00007 -A Page 1 of 1 ENTERGY ARKANSAS, LLC Calculation for Minimum Amount - ANO For Year Ending December 31, 2018 - 10 CFR 50.75(f)(1)

Entergy Arkansas, Inc.: 100% ownership interest Plant Location: Russellville, Arkansas Reactor Type: Pressurized Water Reactor (PWR)

ANO Unit 1 Power Level: <3,400 MWt (2,568 MWt)

ANO Unit 1 PWR Base Year 1986$: $97,598,400 ANO Unit 2 Power Level: <3,400 MWt (3,026 MWt)

ANO Unit 2 PWR Base Year 1986$: $101,628,800 Labor Region: South Waste Burial Facility: Generic Disposal Site 10CFR50.75(c)(2) Escalation Factor Formula:

0.65(L) +0.13(E) +0.22(B)

Factor

=L Labor (South) 2.621

=

E Energy (PWR) 2.372 B=Waste Burial-Vendor (PWR) 12.8533 PWR Escalation Factor:

0.65(L) +0.13(E) +0.22(B)= 4.84041 1986 PWR Base Year $ Escalated:

ANO1: $97,598,400

  • Factor= $472,416,347 ANO2: $101,628,800
  • Factor= $491,925,138 1

Bureau of Labor Statistics, Series Report ID: CIU2010000000220i (4th Quarter 2018) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2018) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 17, Table 2.1 (2019)

CNRO-2019-00007 -B Page 1 of 1 ENTERGY ARKANSAS, LLC Schedule of Remaining Principal Payments into ANO-2 Decommissioning Fund For Year Ending December 31, 2018 - 10 CFR 50.75(f)(1)

ANO-2 Total 2019 $2,169 $3,160 2020 $2,169 $3,098 2021 $2,169 $3,037 2022 $2,169 $2,978 2023 $2,169 $2,919 2024 $2,169 $2,862 2025 $2,169 $2,806 2026 $2,169 $2,751 2027 $2,169 $2,697 2028 $2,169 $2,644 2029 $2,169 $2,592 2030 $2,169 $2,541 2031 $2,169 $2,491 2032 $2,169 $2,443 2033 $2,169 $2,395 2034 $2,169 $2,348 2035 $2,169 $2,302 2036 $2,169 $2,257 2037 $2,169 $2,212 2038 $2,169 $2,169 Note: Approved in Revised Attachment A to Rider NDCR in Order No. 66 in Docket No. 87-166-TF

Attachment 1-C CNRO-2019-00007 ANO Purchase Power Agreements (14 pages to follow)

EAI-ELL WBL Amended PPA AGREEMENT This Agreement is dated as of May 9, 2017 between Entergy Arkansas, Inc. (EAI or Seller), and Entergy Louisiana, LLC (ELL or Buyer).

WHEREAS, EAI has agreed to make a unit power sale from the designated units set forth on Attachment A (individually a Designated Unit and collectively Designated Units) to ELL; and WHEREAS, the Agreement among EAI, the former Entergy Louisiana, LLC (Entergy Louisiana), Entergy New Orleans, Inc., Entergy Mississippi, Inc., and Entergy Services, Inc.

(hereinafter referred to as the System Agreement), was filed with FERC on April 30, 1982, and became effective on January l, 1983, and was amended in 1993 to incorporate Entergy Gulf States, Inc. and its successors Entergy Gulf States Louisiana, L.L.C. (EGSL) and Entergy Texas, Inc., in 2008, and EGSLs and Entergy Louisianas successor, ELL, in 2015; and WHEREAS, EAI withdrew from and terminated its participation in the System Agreement effective December 19, 2013; and WHEREAS, the parties herein previously executed this Agreement to provide for a unit power purchase by ELL under System Agreement Service Schedule MSS-4 from the Designated Units; and WHEREAS, as of December 19, 2013, the Parties have applied and shall apply the terms and conditions of the Unit Power Sales and Designated Power Purchases Tariff accepted by FERC in Docket No. ER13-1508 (Sales and Purchases Tariff), which was designed to replicate System Agreement Service Schedule MSS-4 as the umbrella tariff for this Agreement following EAIs withdrawal from the System Agreement; and WHEREAS, on October 1, 2015, EGSL and Entergy Louisiana completed a transaction

EAI-ELL WBL Amended PPA in which EGSL and Entergy Louisiana combined substantially all of their respective assets and liabilities into a single successor public utility operating company now known as ELL; and WHEREAS, on October 30, 2015, ELL succeeded to the tariffs and rate schedules of EGSL and Entergy Louisiana; and WHEREAS, the System Agreement terminated effective August 31, 2016 at 11:59:59 PM Central Daylight Time; THEREFORE, the parties agree as follows:

1. Designated Units. The designated generating units for purposes of this unit power purchase under the Sales and Purchases Tariff shall be those units set forth on Attachment A.
2. Unit Power Purchase. EAI agrees to sell and ELL agrees to purchase that quantity of generating capacity and associated energy from the Designated Units equivalent to the percentage (the Allocated Percentage) of EAIs baseload capacity in each such Designated Unit set forth on Attachment A, with such sale and purchase to become effective as of May 9, 2017 and to continue thereafter until the retirement date of the Designated Units set forth on Attachment A, plus, for the Designated Units Arkansas Nuclear One (ANO) Units 1 and 2 listed on Attachment A, any time required to decommission ANO Units 1 and 2.
3. Pricing. The pricing of the capacity and energy to be sold and purchased pursuant to paragraph 2 above shall be as specified in the Sales and Purchases Tariff. Should the trust funds set aside for Buyers share of the responsibility for the decommissioning of ANO Units 1 and 2 be found to be insufficient to cover the aforesaid Buyers share of the cost for such decommissioning, Buyer will promptly pay to Seller such deficit. The Buyer will fully pay for the Buyers share of the decommissioning responsibility for ANO Units 1 and 2 notwithstanding the operational status of ANO Units 1 and 2 or any force majeure provisions. All proceeds from decommissioning collections under the Sales and Purchases Tariff pursuant to this Agreement

EAI-ELL WBL Amended PPA will be deposited to the external sinking fund(s) that collect(s) Buyers decommissioning funding.

4. Energy Entitlement. ELL is entitled to receive on an hourly basis the Allocated Percentage of the energy generated by each of the Designated Units.
5. Termination. Neither party shall have the right to terminate the unit power purchase and sale required by this Agreement without the express written consent of the other party.
6. Condition Precedent. This contract shall be conditioned upon Buyer receiving all regulatory approvals required for this Agreement.
7. Notices. Unless specifically stated otherwise herein, any notice to be given hereunder shall be sent by Registered Mail, postage prepaid, to the party to be notified at the address set forth below, and shall be deemed given when so mailed.

To EAI: Entergy Arkansas, Inc.

425 West Capitol Avenue Little Rock, AR 72201 ATTN: Chief Executive Officer To ELL: Entergy Louisiana, LLC 4809 Jefferson Highway Jefferson, LA 70121 ATTN: Chief Executive Officer

8. Nonwaiver. The failure of either party to insist upon or enforce, in any instance, strict performance by the other of any of the terms of this Agreement or to exercise any rights herein conferred shall not be considered as a waiver or relinquishment to any extent of its rights to assert or rely upon any such terms or rights on any future occasion.
9. Amendments. No waiver, alteration, amendment, or modification of any of the provisions of this Agreement shall be binding unless in writing and signed by a duly authorized

EAI-ELL WBL Amended PPA representative of both parties.

10. Entire Agreement. This Agreement, which is entered into in accordance with the authority of the Sales and Purchases Tariff, constitutes the entire agreement between the parties with respect to the subject matter hereof and supersedes all previous and collateral agreements or understandings with respect to the subject matter hereof.
11. Severability. It is agreed that if any clause or provision of this Agreement is held by the courts to be illegal or void, the validity of the remaining portions and provisions of the Agreement shall not be affected, and the rights and obligations of the parties shall be enforced as if the Agreement did not contain such illegal or void clauses or provisions.

EAi-ELL WBL Amended PPA WITNESS OUR SIGNATURES as of May 9, 2017.

ENTERGY ARKANSAS, INC.

BY: ~~ C. R~

TITLE: f1-'c..~*,.ale.n..'t t (_EL)

WITNESS: - - - - - - - - ENTERGY LOUISIANA, LLC BY:

TITLE:

Signature page to EAi-ELL WBl Amended PPA

EAI-ELL WBL Amended PP A WITNESS OUR SIGNATURES as of May 9, 2017.

WITNESS: ENTERGY ARKANSAS, INC.

BY:

TITLE: ---------

WITNESS:

BY; __,__,e.;~'----,<"--'.L.1...>,<£.1-- ---

TITLE: -"-'--"---"--~u.L-_;__ __

Signature page to EAi-EU WBL Amended PPA

EAI-ELL WBL Amended PPA ATTACHMENT A SALE OF CAPACITY AND ENERGY BY ENTERGY ARKANSAS, INC. TO ENTERGY LOUISIANA, LLC This Attachment A is attached to and forms a part of the Agreement dated as of May 9, 2017, between Entergy Louisiana, LLC (ELL or Buyer) and Entergy Arkansas, Inc. (EAI or Seller) pursuant to the Unit Power Sales and Designated Power Purchases Tariff.

During the period, May 9, 2017 through the end of the term, the capacity and energy amount is as follows:

EAIs BUYERS BUYERS BASELOAD ALLOCATED ALLOCATED CAPACITY* CAPACITY* PERCENTAGE DESIGNATED UNIT ANO Unit 1 846.00 23.00 2.72%

ANO Unit 2 998.00 27.00 2.71%

White Bluff Unit 1 461.70 13.00 2.82%

White Bluff Unit 2 461.70 12.00 2.60%

Independence Unit 1 257.00 7.00 2.72%

Grand Gulf - EAI 324.00 9.00 2.78%

TOTAL 3,348.40 91.00 2.72%

  • Expressed in megawatts. To the extent EAIs Baseload Capacity increases or decreases, Buyers Allocated Capacity shall adjust correspondingly based on Buyers Allocated Percentage of EAIs Baseload Capacity.

EAI-ENO WBL Amended PPA AGREEMENT This Agreement is dated as of May 9, 2017 between Entergy Arkansas, Inc. (EAI or Seller), and Entergy New Orleans, Inc. (ENO or Buyer).

WHEREAS, EAI has agreed to make a unit power sale from the designated units set forth on Attachment A (individually a Designated Unit and collectively Designated Units) to ENO; and WHEREAS, the Agreement among EAI, ENO, and the former Entergy Louisiana, LLC (Entergy Louisiana), Entergy Mississippi, Inc., and Entergy Services, Inc. (hereinafter referred to as the System Agreement), was filed with FERC on April 30, 1982, and became effective on January 1, 1983, and was amended in 1993 to incorporate Entergy Gulf States, Inc. and its successors Entergy Gulf States Louisiana, L.L.C. (EGSL) and Entergy Texas, Inc., in 2008, and EGSLs and Entergy Louisianas successor, Entergy Louisiana, LLC, in 2015; and WHEREAS, EAI withdrew from and terminated its participation in the System Agreement effective December 19, 2013; and WHEREAS, the parties herein previously executed this Agreement to provide for a unit power purchase by ENO under System Agreement Service Schedule MSS-4 from the Designated Units; and WHEREAS, as of December 19, 2013, the Parties have applied and shall apply the terms and conditions of the Unit Power Sales and Designated Power Purchases Tariff accepted by FERC in Docket No. ER13-1508 (Sales and Purchases Tariff), which was designed to replicate System Agreement Service Schedule MSS-4 as the umbrella tariff for this Agreement following EAIs withdrawal from the System Agreement; and WHEREAS, the System Agreement terminated effective August 31, 2016 at 11:59:59

EAI-ENO WBL Amended PPA PM Central Daylight Time; THEREFORE, the parties agree as follows:

1. Designated Units. The designated generating units for purposes of this unit power purchase under the Sales and Purchases Tariff shall be those units set forth on Attachment A.
2. Unit Power Purchase. EAI agrees to sell and ENO agrees to purchase that quantity of generating capacity and associated energy from the Designated Units equivalent to the percentage (the Allocated Percentage) of EAIs baseload capacity in each such Designated Unit set forth on Attachment A, with such sale and purchase to become effective as of May 9, 2017 and to continue thereafter until the retirement date of the Designated Units set forth on Attachment A, plus, for the Designated Units Arkansas Nuclear One (ANO) Units 1 and 2 listed on Attachment A, any time required to decommission ANO Units 1 and 2.
3. Pricing. The pricing of the capacity and energy to be sold and purchased pursuant to paragraph 2 above shall be as specified in the Sales and Purchases Tariff. Should the trust funds set aside for Buyers share of the responsibility for the decommissioning of ANO Units 1 and 2 be found to be insufficient to cover the aforesaid Buyers share of the cost for such decommissioning, Buyer will promptly pay to Seller such deficit. The Buyer will fully pay for the Buyers share of the decommissioning responsibility for ANO Units 1 and 2 notwithstanding the operational status of ANO Units 1 and 2 or any force majeure provisions. All proceeds from decommissioning collections under the Sales and Purchases Tariff pursuant to this Agreement will be deposited to the external sinking fund(s) that collect(s) Buyers decommissioning funding.
4. Energy Entitlement. ENO is entitled to receive on an hourly basis the Allocated

EAI-ENO WBL Amended PPA Percentage of the energy generated by each of the Designated Units.

5. Termination. Neither part shall have the right to terminate the unit power purchase and sale required by this Agreement without the express written consent of the other party.
6. Condition Precedent. This contract shall be conditioned upon Buyer receiving all regulatory approvals required for this Agreement.
7. Notices. Unless specifically stated otherwise herein, any notice to be given hereunder shall be sent by Registered Mail, postage prepaid, to the party to be notified at the address set forth below, and shall be deemed given when so mailed.

To EAI: Entergy Arkansas, Inc.

425 West Capitol Avenue Little Rock, AR 72201 ATTN: Chief Executive Officer To ENO: Entergy New Orleans, Inc.

1600 Perdido Street Building 505 New Orleans, LA 70112 ATTN: Chief Executive Officer

8. Nonwaiver. The failure of either party to insist upon or enforce, in any instance, strict performance by the other of any of the terms of this Agreement or to exercise any rights herein conferred shall not be considered as a waiver or relinquishment to any extent of its rights to assert or rely upon any such terms or rights on any future occasion.
9. Amendments. No waiver, alteration, amendment, or modification of any of the provisions of this Agreement shall be binding unless in writing and signed by a duly authorized representative of both parties.
10. Entire Agreement. This Agreement, which is entered into in accordance with the authority of the Sales and Purchases Tariff, constitutes the entire agreement between the parties

EAI-ENO WBL Amended PPA with respect to the subject matter hereof and supersedes all previous and collateral agreements or understandings with respect to the subject matter hereof.

11. Severability. It is agreed that if any clause or provision of this Agreement is held by the courts to be illegal or void, the validity of the remaining portions and provisions of the Agreement shall not be affected, and the rights and obligations of the parties shall be enforced as if the Agreement did not contain such illegal or void clauses or provisions.

EAI-ENO WBL Amended PPA WITNESS OUR SIGNATURES as of May 9, 2017.

WITNESS: . ~ C.~ ' ENTERGY ARKANSAS, INC.

BY: K ~ C..~ 'R~

TITLE: Pre '5\olc""-."t' 4, GfL)

WITNESS: - - - - - - - - - ENTERGY NEW ORLEANS, INC.

BY:

TITLE: _ __

Signalure page to £41-ENO WBl Amended PPA

EAi-ENO WBL Amended PPA WllNESS OUR SIGNATURES as of May 9, 2017.

WllNESS: --------- ENTERGY ARKANSAS, INC.

BY:----------

TITLE: - - - - - - - - -

WllNESS: ~~o TITLE: ~Id~ S Cf::O Signature page to EAi-ENO WBL Amended PPA

EAI-ENO WBL Amended PPA ATTACHMENT A SALE OF CAPACITY AND ENERGY BY ENTERGY ARKANSAS, INC. TO ENTERGY NEW ORLEANS, INC.

This Attachment A is attached to and forms a part of the Agreement dated as of May 9, 2017, between Entergy New Orleans, Inc. (ENO or Buyer) and Entergy Arkansas, Inc. (EAI or Seller) pursuant to the Unit Power Sales and Designated Power Purchases Tariff.

During the period, May 9, 2017 through the end of the term, the capacity and energy amount is as follows:

EAIs BUYERS BUYERS BASELOAD ALLOCATED ALLOCATED CAPACITY* CAPACITY* PERCENTAGE DESIGNATED UNIT ANO Unit 1 846.00 23.00 2.72%

ANO Unit 2 998.00 27.00 2.71%

White Bluff Unit 1 461.70 12.00 2.60%

White Bluff Unit 2 461.70 13.00 2.82%

Independence Unit 1 257.00 7.00 2.72%

Grand Gulf - EAI 324.00 9.00 2.78%

TOTAL 3,348.40 91.00 2.72%

  • Expressed in megawatts. To the extent EAIs Baseload Capacity increases or decreases, Buyers Allocated Capacity shall adjust correspondingly based on Buyers Allocated Percentage of EAIs Baseload Capacity.

CNRO-2019-00007 Page 1 of 1 SYSTEM ENERGY RESOURCES, INC. and COOPERATIVE ENERGY Status Report of Decommissioning Funding For Year Ending December 31, 2018 - 10 CFR 50.75(f)(1)

Plant Name: Grand Gulf Station (Owned & leased 90% by System Energy Resources, Inc (SERI) and 10% by Cooperative Energy)

1. Minimum Financial Assurance (MFA)

Estimated per 10 CFR 50.75(b) and (c) (2018$):

SERI (90% ownership share) $603.7 million1 Cooperative Energy (10% ownership share) $67.1 million

2. ISFSI Obligation as of 12/31/182 SERI $11.48 million Cooperative Energy $1.28 million
3. Decommissioning Fund Total as of 12/31/18:

SERI $869.5 million Cooperative Energy $75.5 million

4. Annual amounts remaining to be collected: None
5. Assumptions used:

Rate of Escalation of Decommissioning Costs:

SERI See item below Cooperative Energy 3.0%

Rate of Earnings on Decommissioning Funds:

SERI 2% real rate of return per 10 CFR 50.75(e)(1)(i)

Cooperative Energy Approx. 2.91%3 Authority for use of Real Earnings Over 2%:

SERI N/A Cooperative Energy Cooperative Energy Board

6. Contracts upon which licensee is relying For Decommissioning Funding: See footnote4
7. Modifications to Method of Financial Assurance since Last Report: None
8. Material Changes to Trust Agreements:

SERI None Cooperative Energy None 1

See Attachment 2-A 2

From Entergys ISFSI Decommissioning Funding Plans Pursuant to 10 CFR 72.30, December 17, 2018 (Accession No. ML18351A491).

3 Established by Cooperative Energy board resolution. A copy of that resolution was previously provided in the licensees March 27, 2015 decommissioning financial assurance filing as Attachment 2-C, Accession No. ML15092A183, and is incorporated herein by reference.

4 See the Unit Power Sales Agreement and the Availability Agreement, FERC tariffs, previously provided in the licensees March 27, 2015 decommissioning financial assurance filing as Attachment 2-D, Accession No. ML15092A183, incorporated herein by reference. It is the licensees position that these agreements are not 10 CFR §50.75(e)(1)(v) contractual obligations, but rather cost of service tariffs which may appropriately be used to fund the external sinking fund in accordance with 10 CFR §50.75(e)(1)(ii). Out of abundance of caution, the licensee identifies this information here.

CNRO-2019-00007 -A Page 1 of 1 SYSTEM ENERGY RESOURCES, INC. and COOPERATIVE ENERGY Calculation for Minimum Amount For Year Ending December 31, 2018 - 10 CFR 50.75(f)(1)

System Energy Resources, Inc.: 90% ownership/leasehold interest Cooperative Energy: 10% ownership interest Plant Location: Port Gibson, Mississippi Reactor Type: Boiling Water Reactor (BWR)

Power Level: >3,400 MWt BWR Base Year 1986$: $135,000,000 Labor Region: South Waste Burial Facility: Generic Disposal Site 10CFR50.75(c)(2) Escalation Factor Formula:

0.65(L) +0.13(E) +0.22(B)

Factor

=L Labor (South) 2.621

=

E Energy (BWR) 2.392+

B=Waste Burial-Vendor (BWR) 13.4223 BWR Escalation Factor:

0.65(L) +0.13(E) +0.22(B)= 4.96883 1986 BWR Base Year $ Escalated:

$135,000,000

  • Factor= $670,792,452 System Energy interest (90%): $603,713,207 Cooperative Energy interest (10%): $ 67,079,245 Total $670,792,452 1

Bureau of Labor Statistics, Series Report ID: CIU2010000000220i (4th Quarter 2018) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2018) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 17, Table 2.1 (2019)

CNRO-2019-00007 Page 1 of 1 ENTERGY LOUISIANA, LLC.

Status Report of Decommissioning Funding For Year Ending December 31, 2018 - 10 CFR 50.75(f)(1)

Plant Name: River Bend Station (70% Regulated Interest)

1. Minimum Financial Assurance (MFA)

Estimated per 10 CFR 50.75(b) and (c) (2018$): $458.5 million1

2. ISFSI Obligation as of 12/31/18 $7.31 million2
3. Decommissioning Fund Total As of 12/31/18: $406.8 million
4. Annual amounts remaining to be collected: See Attachment 3-B
5. Assumptions used:

Rate of Escalation of Decommissioning Costs: See item below Rate of Earnings on Decommissioning Funds: 2% real rate of return per 10 CFR 50.75(e)(1)(i)

Authority for use of Real Earnings Over 2%: N/A

6. Contracts upon which licensee is relying For Decommissioning Funding: See footnote 3
7. Modifications to Method of Financial Assurance since Last Report: None
8. Material Changes to Trust Agreements: None 1

See Attachment 3-A.

2 From Entergys ISFSI Decommissioning Funding Plans Pursuant to 10 CFR 72.30, December 17, 2018 (Accession No. ML18351A491), 70% of River Bend value.

3 See the agreement in attachment 3-D for a unit power purchase agreement under a FERC tariff for the Texas-jurisdictional share of the River Bend 70% share. The licensee believes this contract does not qualify as a contractual obligation, but rather is simply a cost of service recovery mechanism as defined in 10 CFR §50.75(e)(1)(ii)(A). Out of an abundance of caution, the licensee identifies this information here.

CNRO-2019-00007 -A Page 1 of 1 ENTERGY LOUISIANA, LLC.

Calculation for Minimum Amount For Year Ending December 31, 2018 - 10 CFR 50.75(f)(1)

Entergy Louisiana, LLC: Factors below used for all of ownership interests Plant Location: West Feliciana Parish, Louisiana Reactor Type: Boiling Water Reactor (BWR)

Power Level: <3,400 MWt (3,091MWt)

BWR Base Year 1986$: $131,819,000 Labor Region: South Waste Burial Facility: Generic Disposal Site 10CFR50.75(c)(2) Escalation Factor Formula:

0.65(L) +0.13(E) +0.22(B)

Factor

=L Labor (South) 2.621

=

E Energy (BWR) 2.392 B=Waste Burial-Vendor (BWR) 13.4223 BWR Escalation Factor:

0.65(L) +0.13(E) +0.22(B)= 4.96883 1986 BWR Base Year $ Escalated:

$131,819,000

  • Factor= $654,986,595 River Bend 70% Regulated Interest: $458,490,616 River Bend 30% Non-Regulated Interest: $196,495,978 Total $654,986,595 1

Bureau of Labor Statistics, Series Report ID: CIU2010000000220i (4th Quarter 2018) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2018) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 17, Table 2.1 (2019)

CNRO-2019-00007 -B Page 1 of 1 ENTERGY LOUISIANA, LLC.

Schedule of Remaining Principal Payments into RBS (70%) Decommissioning Fund For Year Ending December 31, 2018 - 10 CFR 50.75(f)(1)

Year LPSC PUCT FERC Total 2019 $ 8,996 $ 1,126 $ 113 $10,235 2020 $10,195 $ 1,126 $ 113 $11,434 2021 $10,195 $ 1,126 $ 113 $11,434 2022 $10,195 $ 1,126 $ 113 $11,434 2023 $10,195 $ 1,126 $ 113 $11,434 2024 $10,195 $ 1,126 $ 113 $11,434 2025 $11,693 $ 1,126 $ 113 $12,931 2026 $11,693 $ 1,126 $ 113 $12.932 2027 $11,693 $ 1,126 $ 113 $12.932 2028 $11,693 $ 1,126 $ 113 $12.932 2029 $11,693 $ 1,126 $ 113 $12.932 2030 $13,513 $ 1,126 $ 113 $14,752 Note: Approved in LPSC Docket No.U-31237; PUCT Order in Docket No. 39896; FERC Order in Docket Nos.

ER86-558-002. Copies of those orders were previously provided in the licensees March 27, 2015 decommissioning financial assurance filing as Attachments 3-D, 3-E and 3-F, respectively, Accession No. ML15092A183, and are incorporated herein by reference.

CNRO-2019-00007 -C Page 1 of 1 ENTERGY LOUISIANA, LLC.

Status Report of Decommissioning Funding For Year Ending December 31, 2018 - 10 CFR 50.75(f)(1)

Plant Name: River Bend Station (30% Non-Regulated Interest)

1. Minimum Financial Assurance (MFA)

Estimated per 10 CFR 50.75(b) and (c) (2018$): $196.5 million1

2. ISFSI Obligation as of 12/31/18 $3.13 million2
3. Decommissioning Fund Total As of 12/31/18: $396.5 million
4. Annual amounts remaining to be collected: None
5. Assumptions used:

Rate of Escalation of Decommissioning Costs: See next item Rate of Earnings on Decommissioning Funds: 2% real rate of return per 10 CFR 50.75(e)(1)(i)

Authority for use of Real Earnings Over 2%: N/A

6. Contracts upon which licensee is relying For Decommissioning Funding: None3
7. Modifications to Method of Financial Assurance since Last Report: None
8. Material Changes to Trust Agreements: None 1

See Attachment 3-A.

2 From Entergys ISFSI Decommissioning Funding Plans Pursuant to 10 CFR 72.30, December 17, 2018 (Accession No. ML18351A491), 30% of River Bend value.

3 The River Bend 30% share is sold under contract, but since the 30% share is fully funded with a pre-paid decommissioning fund, the licensee does not rely on this contract for decommissioning.

Attachment 3-D CNRO-2019-00007 River Bend 70% Purchase Power Agreement (7 pages to follow)

AGREEMENT This Agreement is dated as of September 1, 2016, between Entergy Texas, Inc.

(ETI or Buyer), and Entergy Louisiana, LLC (ELL or Seller).

WHEREAS, Seller has agreed to make a unit power sale from the designated units set forth on Attachment A (individually a Designated Unit and collectively Designated Units) to Buyer; and WHEREAS, the agreement among the former Entergy Louisiana, LLC (Entergy Louisiana), Entergy Mississippi, Inc., Entergy New Orleans, Inc., and Entergy Arkansas, Inc., (collectively the Companies), and Entergy Services, Inc. (ESI) was filed with FERC on April 30, 1982, and became effective on January 1, 1983, and amended to incorporate Entergy Gulf States, Inc. (EGS) in 1993 and its successor, Entergy Gulf States Louisiana, L.L.C. (EGSL), and ETI in 2008 (hereinafter referred to as the System Agreement); and WHEREAS, on October 1, 2015, EGSL and Entergy Louisiana completed a transaction in which EGSL and Entergy Louisiana combined substantially all of their respective assets and liabilities into a single successor public utility operating company now known as ELL; and WHEREAS, on October 30, 2015, ELL succeeded to the tariffs and rate schedules of EGSL and Entergy Louisiana; and WHEREAS, pursuant to a Settlement Agreement approved by FERC in Docket Nos.

ER14-75, et al., on December 29, 2015, the System Agreement will terminate effective August 31, 2016 at 11:59:59 PM Central Daylight Time; and WHEREAS, the parties herein previously executed this Agreement to provide for a unit power purchase by Buyer under Service Schedule MSS-4 from the Designated Units; and

WHEREAS, upon termination of the System Agreement, the Parties intend to apply the terms and conditions of the Unit Power Sales and Designated Power Purchases Tariff accepted by FERC in Docket No. ER13-1508 (Sales and Purchases Tariff), which is designed to replicate System Agreement Service Schedule MSS-4 as the umbrella tariff for this Agreement; THEREFORE, the parties agree as follows:

1. Designated Units. The designated generating units for purposes of this unit power sale under the Sales and Purchases Tariff shall be those units set forth on Attachment A.
2. Unit Power Purchase. Seller agrees to sell and Buyer agrees to purchase that quantity of generating capacity and associated energy from the Designated Units equivalent to the percentage (the Allocated Percentage) of Sellers capacity in each such Designated Unit set forth on Attachment A.
3. Pricing. The pricing of the capacity and energy to be sold and purchased pursuant to paragraph 2 above shall be as specified in the Sales and Purchases Tariff; however, the input values for decommissioning, Generating Plant Accounts (DGUPTPLT), Accumulated Provision for Depreciation (DGUDR),

Accumulated Deferred Income Taxes (DGUADIT), and Depreciation Expense (DGUDE) will reflect the ratemaking decisions of the Public Utility Commission of Texas. In addition, the Operations and Maintenance expenses will be reduced by the 30% portion allocable to the unregulated portion of River Bend Station, which is not in retail rate base. This 30% portion of River Bend Station was formerly owned by Cajun Electric Power Cooperative before it was owned by EGSL and now ELL.

Should the trust funds set aside for Buyers share of the responsibility

for River Bend Station decommissioning be found to be insufficient to cover the aforesaid Buyers share of the cost for such decommissioning, Buyer will promptly pay to Seller such deficit. The Buyer will fully pay for the Buyers share of the decommissioning responsibility for River Bend notwithstanding the operational status of River Bend or any force majeure provisions. All proceeds from decommissioning collections under the Sales and Purchases Tariff pursuant to this Agreement will be deposited to the external sinking fund(s) that collect(s) Buyers decommissioning funding.

4. Energy Entitlement. Buyer is entitled to receive on an hourly basis the Allocated Percentage of the energy generated by each of the Designated Units.
5. Term. The term of this Agreement shall be the operating life of the Designated Units, plus any time required to decommission the Designated Units.
6. Termination. Neither party shall have the right to terminate the unit power purchase and sale required by this Agreement without the express written consent of the other party.
7. Assignment. This Agreement is not assignable by Buyer without the consent of Seller, and Seller must consent to any transfer or assignment to any new or restructured entity resulting from any restructuring or business combination of Buyer, the effect of which would cause a successor to become a party hereto.

Any assignment approved by Seller shall be on terms as then agreed.

8. Condition Precedent. This contract shall be conditioned upon Buyer receiving all regulatory approvals required for this Agreement.
9. Notices. Unless specifically stated otherwise herein, any notice to be given hereunder shall be sent by Registered Mail, postage prepaid, to the party to be

notified at the address set forth below, and shall be deemed given when so mailed.

To ETI: Entergy Texas, Inc.

10055 Grogans Mill Road The Woodlands, TX 77380 ATTN: Chief Executive Officer To ELL: Entergy Louisiana, LLC 4809 Jefferson Hwy Jefferson, LA 70121 ATTN: Chief Executive Officer

10. Nonwaiver: The failure of either party to insist upon or enforce, in any instance, strict performance by the other of any of the terms of this Agreement or to exercise any rights herein conferred shall not be considered as a waiver or relinquishment to any extent of its rights to assert or rely upon any such terms or rights on any future occasion.
11. Amendments. No waiver, alteration, amendment or modification of any of the provisions of this Agreement shall be binding unless in writing and signed by a duly authorized representative of both parties.
12. Entire Agreement. This Agreement, which is entered into in accordance with the authority of the Sales and Purchases Tariff, constitutes the entire agreement between the parties with respect to the subject matter hereof and supersedes all previous and collateral agreements or understandings with respect to the subject matter hereof.
13. Severability. It is agreed that if any clause or provision of this Agreement is held by the courts to be illegal or void, the validity of the remaining portions and provisions of the Agreement shall not be affected, and the rights and obligations of the parties shall be enforced as if the Agreement did not contain such illegal or void clauses or provisions.

BY:

TITLE:

ENTERGY LLC BY:

TITLE:

Signature page to Power Purchase Agreement by and between ELL (Sellerj and ETI (Buyer) for River Bend 70

ENTERGY TEXAS, INC.

BY:

TITLE:

ENTER9m SIAN , LLC BY:/;}£~

TITLE: Pte s,'d.e/'\l: "' Leo Signature page to Power Purchase Agreement by and between ELL (Seller) and ETI (Buyer) for River Bend 70

ATTACHMENT A SALE OF CAPACITY AND ENERGY BY ENTERGY LOUISIANA, LLC TO ENTERGY TEXAS, INC.

This Attachment A is attached to and forms a part of the Agreement dated September 1, 2016, between Entergy Louisiana, LLC (Seller) and Entergy Texas, Inc. (Buyer) pursuant to the Unit Power Sales and Designated Power Purchases Tariff.

SELLERS BUYERS BUYERS CAPACITY* ALLOCATED ALLOCATED CAPACITY* PERCENTAGE DESIGNATED UNITS River Bend Station 689 292.83 42.5%

TOTAL 689 292.83 42.5%

  • Expressed in megawatts. To the extent Sellers Capacity increases or decreases from time to time, Buyers Allocated Capacity shall adjust correspondingly based on Buyers Allocated Percentage of Sellers Capacity.

Attachment 3-E CNRO-2019-00007 River Bend 30% Purchase Power Agreement (7 pages to follow)

AGREEMENT This Agreement is dated as of September 1, 2016 between Entergy Louisiana, LLC (ELL or Seller), and Entergy New Orleans, Inc. (ENO or Buyer).

WHEREAS, ELL has agreed to make a unit power sale from the designated unit set forth on Attachment A (Designated Unit) to ENO; and WHEREAS, the Agreement among ENO, the former Entergy Louisiana, LLC (Entergy Louisiana), Entergy Mississippi, Inc. (EMI), Entergy Arkansas, Inc. (EAI) and Entergy Services, Inc. (ESI) (hereinafter referred to as the System Agreement), was filed with FERC on April 30, 1982, and became effective on January 1, 1983, and amended to incorporate Entergy Gulf States, Inc., the predecessor to Entergy Gulf States Louisiana, L.L.C. (EGSL) and Entergy Texas, Inc. (ETI), in 1993; and WHEREAS, by Order dated July 20, 2007, FERC approved the addition of EGSL and ETI as parties to the System Agreement; and WHEREAS, on October 1, 2015, EGSL and Entergy Louisiana completed a transaction in which EGSL and Entergy Louisiana combined substantially all of their respective assets and liabilities into a single successor public utility operating company now known as ELL; and WHEREAS, on October 30, 2015, ELL succeeded to the tariffs and rate schedules of EGSL and Entergy Louisiana; and WHEREAS, pursuant to a Settlement Agreement approved by FERC in Docket Nos.

ER14-75, et al., on December 29, 2015, the System Agreement will terminate effective August 31, 2016 at 11:59:59 PM Central Daylight Time; and

WHEREAS, the parties herein previously executed this Agreement to provide for a unit power purchase by ENO under System Agreement Service Schedule MSS-4 from the Designated Unit; and WHEREAS, upon termination of the System Agreement, the Parties intend to apply the terms and conditions of the Unit Power Sales and Designated Power Purchases Tariff accepted by FERC in Docket No. ER13-1508 (Sales and Purchases Tariff), which is designed to replicate System Agreement Service Schedule MSS-4 as the umbrella tariff for this Agreement; THEREFORE, the parties agree as follows:

1. Designated Unit. The designated generating unit for purposes of this unit power purchase under the Sales and Purchases Tariff shall be the unit set forth on Attachment A.
2. Unit Power Purchase. ELL agrees to sell and ENO agrees to purchase that quantity of generating capacity and associated energy from the Designated Unit equivalent to the percentage (the Allocated Percentage) of ELLs baseload capacity in such Designated Unit set forth on Attachment A, with such sale and purchase to become effective as of September 1, 2016 and to continue thereafter until the retirement date of the Designated Unit set forth on Attachment A, plus any time required to decommission the Designated Unit.
3. Pricing. The pricing of the capacity and energy to be sold and purchased pursuant to paragraph 2 above shall be as specified in the Sales and Purchases Tariff; however, the accounting treatment of this Agreement will deviate from the specific account references included in the Sales and Purchases Tariff. The Designated Unit is recorded by ELL as a non-utility investment because that portion of River Bend Station is a non-regulated investment and not in retail rate base. Consequently, the values for the plant investment calculation is as reported in Account 121 and plant accounts 310-346, and not in Account 101. Similarly, the

depreciation expense value is as reported in Account 417, and the depreciation reserve value is reported in Account 122, both of which are non-utility accounts, rather than Accounts 403, 404, and 108 as specified in the Sales and Purchases Tariff. In addition, because the Designated Unit is a non-regulated investment, it is not appropriate to allocate a portion of the regulated General and Intangible Plant; and, thus, those values are set to zero.

Should the trust funds set aside for Buyers share of the responsibility for River Bend Station decommissioning be found to be insufficient to cover the aforesaid Buyers share of the cost for such decommissioning, Buyer will promptly pay to Seller such deficit. The Buyer will fully pay for the Buyers share of the decommissioning responsibility for River Bend notwithstanding the operational status of River Bend or any force majeure provisions. All proceeds from decommissioning collections under the Sales and Purchases Tariff pursuant to this Agreement will be deposited to the external sinking fund(s) that collect(s) Buyers decommissioning funding.

4. Energy Entitlement. ENO is entitled to receive on an hourly basis the Allocated Percentage of the energy generated by the Designated Unit.
5. Termination. Neither party shall have the right to terminate the unit power purchase and sale required by this Agreement without the express written consent of the other party.
6. Condition Precedent. This contract shall be conditioned upon Buyer receiving all regulatory approvals required for this Agreement.
7. Notices. Unless specifically stated otherwise herein, any notice to be given hereunder shall be sent by Registered Mail, postage prepaid, to the party to be notified at the address set forth below, and shall be deemed given when so mailed.

To ELL: Entergy Louisiana, LLC 4809 Jefferson Highway Jefferson, LA 70121 ATTN: Chief Executive Officer To ENO: Entergy New Orleans, Inc.

1600 Perdido Street Building 505 New Orleans, LA 70112 ATTN: Chief Executive Officer

8. Nonwaiver. The failure of either party to insist upon or enforce, in any instance, strict performance by the other of any of the terms of this Agreement or to exercise any rights herein conferred shall not be considered as a waiver or relinquishment to any extent of its rights to assert or rely upon any such terms or rights on any future occasion.
9. Amendments. No waiver, alteration, amendment or modification of any of the provisions of this Agreement shall be binding unless in writing and signed by a duly authorized representative of both parties.
10. Entire Agreement. This Agreement, which is entered into in accordance with the authority of the Sales and Purchases Tariff, constitutes the entire agreement between the parties with respect to the subject matter hereof and supersedes all previous and collateral agreements or understandings with respect to the subject matter hereof.
11. Severability. It is agreed that if any clause or provision of this Agreement is held by the courts to be illegal or void, the validity of the remaining portions and provisions of the Agreement shall not be affected, and the rights and obligations of the parties shall be enforced as if the Agreement did not contain such illegal or void clauses or provisions.

ENTERGY NEW ORLEANS, INC.

BY: - - - - - - - - - - -

TITLE:

Signature page to Power Purchase Agreement by and between ELL (Seller) and ENO (Buyer) for River Bend 30

ENTERGY LOUISIANA, LLC BY:

TITLE:

/

TITLE: ~,es; J..,_,n t . . CE-o Signature page to Power Purchase Agreement by and bdween ELL (Seller) and ENO (Buyer) for River Bend 30

ATTACHMENT A SALE OF CAPACITY AND ENERGY BY ENTERGY LOUISIANA, LLC TO ENTERGY NEW ORLEANS, INC.

During the period September 1, 2016 and to continue thereafter until the retirement date of the Designated Unit, the capacity and energy amount is as follows:

ELLS BUYERS BUYERS BASELOAD ALLOCATED ALLOCATED DESIGNATED UNIT CAPACITY* CAPACITY* PERCENTAGE RB30 300.00 100.00 33.33%

  • Expressed in megawatts. To the extent ELLs Baseload Capacity increases or decreases, Buyers Allocated Capacity shall adjust correspondingly based on Buyers Allocated Percentage of ELLs Baseload Capacity.

CNRO-2019-00007 Page 1 of 1 ENTERGY LOUISIANA, LLC.

Status Report of Decommissioning Funding For Year Ending December 31, 2018 - 10 CFR 50.75(f)(1)

Plant Name: Waterford 3 Steam Electric Station

1. Minimum Financial Assurance (MFA)

Estimated per 10 CFR 50.75(b) and (c) (2018$): $508.2 million1

2. ISFSI Obligation as of 12/31/18 $9.04 million2
3. Decommissioning Fund Total As of 12/31/18: $481.6 million
4. Annual amounts remaining to be collected: See Attachment 4-B
5. Assumptions used:

Rate of Escalation of Decommissioning Costs: See item below Rate of Earnings on Decommissioning Funds: 2% real rate of return per 10 CFR 50.75(e)(1)(i)

Authority for use of Real Earnings Over 2%: N/A

6. Contracts upon which licensee is relying For Decommissioning Funding: See Footnote3
7. Modifications to Method of Financial Assurance since Last Report: None
8. Material Changes to Trust Agreements: None 1

See Attachment 4-A.

2 From Entergys ISFSI Decommissioning Funding Plans Pursuant to 10 CFR 72.30, December 17, 2018 (Accession No. ML18351A491).

3 See the agreements in attachment 4-C for a unit power purchase agreement under FERC tariffs for Waterford 3. The licensee believes this contract does not qualify as a contractual obligation, but rather is simply a cost of service recovery mechanism as defined in 10 CFR §50.75(e)(1)(ii)(A). Out of an abundance of caution, the licensee identifies this information here.

CNRO-2019-00007 -A Page 1 of 1 ENTERGY LOUISIANA, LLC.

Calculation for Minimum Amount For Year Ending December 31, 2018 - 10 CFR 50.75(f)(1)

Entergy Louisiana, LLC: 100% ownership interest Plant Location: Taft, Louisiana Reactor Type: Pressurized Water Reactor (PWR)

Power Level: >3,400 MWt PWR Base Year 1986$: $105,000,000 Labor Region: South Waste Burial Facility: Generic Disposal Site 10CFR50.75(c)(2) Escalation Factor Formula:

0.65(L) +0.13(E) +0.22(B)

Factor

=L Labor (South) 2.621

=

E Energy (PWR) 2.372 B=Waste Burial-Vendor (PWR) 12.8533 PWR Escalation Factor:

0.65(L) +0.13(E) +0.22(B)= 4.84041 1986 PWR Base Year $ Escalated:

$105,000,000

  • Factor= $508,243,131 1

Bureau of Labor Statistics, Series Report ID: CIU2010000000220i (4th Quarter 2018) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2018) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 17, Table 2.1 (2019)

-B CNRO-2019-00007 age 1 of 1 ENTERGY LOUISIANA, LLC.

Schedule of Remaining Principal Payments into WF3 Decommissioning Fund For Year Ending December 31, 2018 - 10 CFR 50.75(f)(1)

Year LPSC City of New Orleans Total 2019 $6,688 $133 $6,821 2020 $7,580 $151 $7,731 2021 $7,580 $151 $7,731 2022 $7,580 $151 $7,731 2023 $7,580 $151 $7,731 2024 $7,580 $151 $7,731 2025 $8,867 $8,867 2026 $8,867 $8,867 2027 $8,867 $8,867 2028 $8,867 $8,867 2029 $8,867 $8,867 2030 $10,246 $10,246 Note: Approved in LPSC Docket No. U-31237, CNO Resolution R-95-1081 in Docket UD-95-1, and CNO Resolution R-14-494 in Docket UD-13-01. Copies of those orders were previously provided in the licensees March 27, 2015 decommissioning financial assurance filing as Attachments 4-C, 4-D, and 4-E, respectively, Accession No. ML15092A183, and are incorporated herein by reference.

Attachment 4-C CNRO 2019-00007 Waterford 3 Purchase Power Agreement (7 pages to follow)

AGREEMENT This Agreement is dated as of September 1, 2016, between Entergy Louisiana, LLC (ELL or Seller) and Entergy New Orleans, Inc. (ENO or Buyer, and together with the Seller, the Parties).

WHEREAS, the former Entergy Louisiana, LLC (Entergy Louisiana) transferred to ENO certain Entergy Louisiana assets (and related liabilities) that are necessary to provide electric service to customers in the Fifteenth Ward of the City of New Orleans, commonly referred to as Algiers (the Algiers Transaction); and WHEREAS, as part of the Algiers Transaction, Entergy Louisiana agreed to make a unit power sale from the designated units set forth on Attachment A (Designated Units) to ENO; and WHEREAS, the Agreement among Entergy Louisiana, ENO, Entergy Mississippi, Inc.

and Entergy Services, Inc. (hereinafter referred to as the System Agreement), was filed with FERC on April 30, 1982, and became effective on January 1, 1983, and was amended in 1993 to incorporate Entergy Gulf States, Inc., and its successors Entergy Gulf States Louisiana, L.L.C.

(EGSL) and Entergy Texas, Inc., in 2008; and WHEREAS, on October 1, 2015, EGSL and Entergy Louisiana completed a transaction in which EGSL and Entergy Louisiana combined substantially all of their respective assets and liabilities into a single successor public utility operating company now known as ELL; and WHEREAS, on October 30, 2015, ELL succeeded to the tariffs and rate schedules of EGSL and Entergy Louisiana; and

WHEREAS, pursuant to a Settlement Agreement approved by FERC in Docket Nos.

ER14-75, et al., on December 29, 2015, the System Agreement will terminate effective August 31, 2016 at 11:59:59 Central Daylight Time; and WHEREAS, the Parties previously executed this Agreement to provide for a unit power purchase by Buyer under System Agreement Service Schedule MSS-4 from the Designated Units; and WHEREAS, the Entergy Operating Committee previously considered and approved the terms of this Agreement; and WHEREAS, upon termination of the System Agreement, the Parties intend to apply the terms and conditions of the Unit Power Sales and Designated Power Purchases Tariff accepted by FERC in Docket No. ER13-1508 (Sales and Purchases Tariff), which is designed to replicate System Agreement Service Schedule MSS-4 as the umbrella tariff for this Agreement; THEREFORE, the Parties agree as follows:

1. Unit Power Purchase. Subject to the other terms of this Agreement, Seller agrees to sell and Buyer agrees to purchase that quantity of generating capacity and associated energy from the Designated Units on a life-of-unit basis under the Sales and Purchases Tariff, as described herein, equivalent to the Buyers Allocated Percentage of Sellers Unit Capacity of the Designated Units, all as set forth on Attachment A. Buyers Allocated Percentage will remain fixed as specified on Attachment A for the entire term of this Agreement.
2. Designated Units. The designated generating units for purposes of this unit power purchase under the Sales and Purchases Tariff shall be the units set forth on Attachment A.
3. Pricing. The pricing of the capacity and energy to be sold and purchased pursuant to paragraph 2 above shall be as specified in the Sales and Purchases Tariff. Should the trust 2

funds set aside for Buyers share of the responsibility for Waterford Unit 3 decommissioning be found to be insufficient to cover the aforesaid Buyers share of the cost for such decommissioning, Buyer will promptly pay to Seller such deficit. The Buyer will fully pay for the Buyers share of the decommissioning responsibility for Waterford Unit 3 notwithstanding the operational status of Waterford Unit 3 or any force majeure provisions. All proceeds from decommissioning collections under the Sales and Purchases Tariff pursuant to this Agreement will be deposited to the external sinking fund(s) that collect(s) Buyers decommissioning funding.

4. Energy Entitlement. Buyer is entitled to receive on an hourly basis Buyers Allocated Percentage (set forth in Attachment A) of the energy generated by the Designated Units.
5. Term. The term of this Agreement shall be the operating life of the Designated Units, plus any time required to decommission the Designated Units.
6. Termination. Neither party shall have the right to terminate the unit power purchase and sale required by this Agreement without the express written consent of the other party.
7. Condition Precedent. This contract shall be conditioned upon Buyer and Seller receiving all regulatory approvals required for this Agreement.
8. Notices. Unless specifically stated otherwise herein, any notice to be given hereunder shall be sent by Registered Mail, postage prepaid, to the party to be notified at the address set forth below, and shall be deemed given when so mailed.

To ELL: Entergy Louisiana, LLC 4809 Jefferson Highway Jefferson, LA 70121 ATTN: Chief Executive Officer 3

To ENO: Entergy New Orleans, Inc.

1600 Perdido Street, Bldg. No. 505 New Orleans, LA 70112 ATTN: Chief Executive Officer

9. Nonwaiver. The failure of either party to insist upon or enforce, in any instance, strict performance by the other of any of the terms of this Agreement or to exercise any rights herein conferred shall not be considered as a waiver or relinquishment to any extent of its rights to assert or rely upon any such terms or rights on any future occasion.
10. Amendments. No waiver, alteration, amendment or modification of any of the provisions of this Agreement shall be binding unless in writing and signed by a duly authorized representative of both Parties.
11. Entire Agreement. This Agreement, which is entered into in accordance with the authority of the Sales and Purchases Tariff, constitutes the entire agreement between the Parties with respect to the subject matter hereof and supersedes all previous and collateral agreements or understandings with respect to the subject matter hereof.
12. Severability. It is agreed that if any clause or provision of this Agreement is held by the courts to be illegal or void, the validity of the remaining portions and provisions of the Agreement shall not be affected, and the rights and obligations of the Parties shall be enforced as if the Agreement did not contain such illegal or void clauses or provisions.

4

WITNESS OUR SIGNATURES as of September 1, 2016.

WITNESS:

NAME: Phillip R. May, Jr.

TITLE: President and Chief Executive Officer WITNESS: ENTERGY NEW ORLEANS, INC.

BY:----------

NAME: Charles L. Rice, Jr.

TITLE: President and Chief Executive Officer 5

Signature page to Power Purchase Agreement by and between ELL (&Uer) and ENO (Buyer) for the Algiers Tl'tlnsaction

WITNESS OUR SIGNATURES as of September I, 2016.

WITNESS: ENTERGY LOUISIANA, LLC BY: - - - - - - - - - - -

NAME: Phillip R. May, Jr.

TITLE: President and Chief Executive Officer NAME: Charles L. Rice, Jr.

TITLE: President and Chief Executive Officer 5

Signature page to Power Purchase Agreement by and between ELL (Seller) and ENO (Buyer) for the Algiers Transaction

ATTACHMENT A SALE OF CAPACITY AND ENERGY BY ENTERGY LOUISIANA, LLC TO ENTERGY NEW ORLEANS, INC.

This Attachment A is attached to and forms a part of the Agreement, dated as of September 1, 2016, between Entergy New Orleans, Inc. (ENO or Buyer) and Entergy Louisiana, LLC (ELL or Seller) pursuant to the Unit Power Sales and Designated Power Purchases Tariff.

During the term of this Agreement, Buyers Allocated Percentage of capacity and associated energy will be determined as follows:

SELLERS BUYERS BUYERS UNIT ALLOCATED ALLOCATED CAPACITY* CAPACITY* PERCENTAGE DESIGNATED UNIT Waterford Unit 3 1,156.4 21.3 1.84%

Ninemile Point Unit 5 716.9 13.2 1.84%

Ninemile Point Unit 4 699.0 12.9 1.84%

Little Gypsy Unit 3 520.3 9.6 1.84%

Oxy-Taft 480.0 8.8 1.84%

Waterford Unit 1 410.9 7.6 1.84%

Waterford Unit 2 410.8 7.6 1.84%

Little Gypsy Unit 2 410.7 7.6 1.84%

Acadia Power Block 2 363.6 6.7 1.84%

Ninemile Unit 6 308.0 5.7 1.84%

River Bend 30 194.5 3.6 1.84%

Grand Gulf ELMP 178.1 3.3 1.84%

Perryville Unit 1 132.5 2.4 1.84%

Sterlington Unit 7 125.7 2.3 1.84%

Vidalia 105.3 1.9 1.84%

Ninemile Point Unit 3 103.2 1.9 1.84%

Perryville Unit 2 36.5 0.7 1.84%

Waterford Unit 4 33.4 0.6 1.84%

Grand Gulf EAMP 30.9 0.6 1.84%

Arkansas Nuclear One - Unit 2 26.7 0.5 1.84%

Arkansas Nuclear One - Unit 1 22.7 0.4 1.84%

White Bluff Unit 1 13.1 0.2 1.84%

White Bluff Unit 2 12.2 0.2 1.84%

Buras 8 12.0 0.2 1.84%

Toledo Bend Unit 1 9.9 0.2 1.84%

Toledo Bend Unit 2 9.9 0.2 1.84%

Independence Unit 1 7.2 0.1 1.84%

Montauk 3.2 0.1 1.84%

TOTAL** 6,533.5 120.2 1.84%

  • Expressed in megawatts. To the extent Sellers Unit Capacity in any Designated Unit increases or decreases, Buyers Allocated Capacity with respect to such Designated Unit shall adjust so that it equals the product of Sellers Unit Capacity and Buyers Allocated Percentage. Buyers Allocated Percentage will remain fixed for the entire Term of the Agreement.
    • Total may not add due to rounding.

CNRO-2019-00007 (Page 1 of 10) Minimum Funding Assurance Calculation Worksheets Plant name: Arkansas Nuclear One, Unit 1 Month Day Year Year of Biennial: 12 31 2018 Termination of Operation: 5 20 2034 MWth 1986$ ECI Base Lx Lx Px Fx Ex Bx PWR 2568 $97,598,400 132.5 1.98 0.65 2.62 2.103 2.727 0.13 2.37 0.22 12.853 NRC Minimum: $472,416,347 Site Specific:

Licensee:  % Owned: Amount of NRC Minimum/Site Specific: Amount in Trust Fund:

Entergy 100.00% $472,416,347 $506,719,075 Step 1:

Earnings Credit:

Real Rate of Years Left Trust Fund Balance: Return per in License Total Real Rate of Return: Total Earnings:

$506,719,075 2% 15.39 1.35621 $687,217,249 Total Earnings = Trust Fund balance x (1+RRR)^Years left in license Step 2:

Accumulation:

Value of Annuity per Real Rate of year Return per Years of Annuity: Total Annuity:

$0 2% 0 $0 Total Step 2

$0 Total Step 1 + Step 2

$687,217,249 Step 3:

Decom Period:

Real Rate of Decom Total Earnings: Return per Period: Total Real Rate of Return: Total Earnings for Decom:

$687,217,249 2% 7 0.14869 $51,089,678 Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]

Accumulation during Decom Total of Steps 1 - 3:

$738,306,926 Total = Total Earnings + Total Earnings for Decom Excess (Shortfall) $ 265,890,580 to NRC minimum

$ (7,360,500) Less ISFSI

$ - Parent Co Guaranty

$ 258,530,080 Total Excess Financial Assurance

CNRO-2019-00007 (Page 2 of 10) Minimum Funding Assurance Calculation Worksheets Plant name: Arkansas Nuclear One, Unit 2 Month Day Year Year of Biennial: 12 31 2018 Termination of Operation: 7 17 2038 MWth 1986$ ECI Base Lx Lx Px Fx Ex Bx PWR 3026 $101,628,800 132.5 1.98 0.65 2.62 2.103 2.727 0.13 2.37 0.22 12.853 NRC Minimum: $491,925,138 Site Specific:

Licensee:  % Owned: Amount of NRC Minimum/Site Specific: Amount in Trust Fund:

Entergy 100.00% $491,925,138 $405,329,792 Step 1:

Earnings Credit:

Real Rate of Years Left Trust Fund Balance: Return per in License Total Real Rate of Return: Total Earnings:

$405,329,792 2% 19.54 1.47262 $596,896,025 Total Earnings = Trust Fund balance x (1+RRR)^Years left in license Step 2:

Accumulation:

Value of Annuity per Real Rate of year Return per Years of Annuity: Total Annuity:

See Annuity Sheet 2% 21 $52,700,995 Total Step 2

$52,700,995 Total Step 1 + Step 2

$649,597,020 Step 3:

Decom Period:

Real Rate of Decom Total Earnings: Return per Period: Total Real Rate of Return: Total Earnings for Decom:

$649,597,020 2% 7 0.14869 $48,292,883 Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]

Accumulation during Decom Total of Steps 1 - 3:

$697,889,904 Total = Total Earnings + Total Earnings for Decom Excess (Shortfall) $ 205,964,765 to NRC minimum

$ (7,360,500) Less ISFSI

$ - Parent Co Guaranty

$ 198,604,265 Total Excess Financial Assurance

CNRO-2019-00007 (Page 3 of 10) Minimum Funding Assurance Calculation Worksheets Plant name: ANO-2 Termination of Operations: 2038 Real Total Year Annuity: Rate of Accumulation 2019 $2,169,000 2.00% $3,159,823 2020 $2,169,000 2.00% $3,097,866 2021 $2,169,000 2.00% $3,037,124 Total Accumulation = Annuity x (1+RRR)^Years left from 2022 $2,169,000 2.00% $2,977,572 Accum 2023 $2,169,000 2.00% $2,919,188 2024 $2,169,000 2.00% $2,861,949 2025 $2,169,000 2.00% $2,805,833 2026 $2,169,000 2.00% $2,750,816 2027 $2,169,000 2.00% $2,696,879 2028 $2,169,000 2.00% $2,643,999 2029 $2,169,000 2.00% $2,592,156 2030 $2,169,000 2.00% $2,541,329 2031 $2,169,000 2.00% $2,491,499 2032 $2,169,000 2.00% $2,442,646 2033 $2,169,000 2.00% $2,394,751 2034 $2,169,000 2.00% $2,347,795 2035 $2,169,000 2.00% $2,301,760 2036 $2,169,000 2.00% $2,256,628 2037 $2,169,000 2.00% $2,212,380 2038 $2,169,000 2.00% $2,169,000 Total: $52,700,995

CNRO-2019-00007 (Page 4 of 10) Minimum Funding Assurance Calculation Worksheets Plant name: Grand Gulf Nuclear Station (SERI 90%)

Month Day Year Year of Biennial: 12 31 2018 Termination of Operation: 11 1 2044 MWth 1986$ ECI Base Lx Lx Px Fx Ex Bx BWR 4408 $135,000,000 132.5 1.98 0.65 2.62 2.103 2.727 0.13 2.39 0.22 13.422 NRC Minimum: $670,792,452 Site Specific:

Licensee:  % Owned: Amount of NRC Minimum/Site Specific: Amount in Trust Fund:

Entergy 90.00% $603,713,207 $869,542,840 Step 1:

Earnings Credit:

Real Rate of Years Left Trust Fund Balance: Return per in License Total Real Rate of Return: Total Earnings:

$869,542,840 2.0% 25.83 1.66794 $1,450,346,947 Total Earnings = Trust Fund balance x (1+RRR)^Years left in license Step 2:

Accumulation:

Value of Annuity per Real Rate of year Return per Years of Annuity: Total Annuity:

See Annuity Sheet 2.0% 0 $0 Total Step 2

$0 Total Step 1 + Step 2

$1,450,346,947 Step 3:

Decom Period:

Real Rate of Decom Total Earnings: Return per Period: Total Real Rate of Return: Total Earnings for Decom:

$1,450,346,947 2% 7 0.14869 $107,822,902 Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]

Accumulation during Decom Total of Steps 1 - 3:

$1,558,169,849 Total = Total Earnings + Total Earnings for Decom Excess (Shortfall) $ 954,456,641 to NRC minimum

$ (11,479,500) Less ISFSI

$ - Parent Co Guaranty

$ 942,977,141 Total Excess Financial Assurance

CNRO-2019-00007 (Page 5 of 10) Minimum Funding Assurance Calculation Worksheets Plant name: Grand Gulf Nuclear Station (Cooperative Energy 10%)

Month Day Year Year of Biennial: 12 31 2018 Termination of Operation: 11 1 2044 MWth 1986$ ECI Base Lx Lx Px Fx Ex Bx BWR 4408 $135,000,000 132.5 1.98 0.65 2.62 2.103 2.727 0.13 2.39 0.22 13.422 NRC Minimum: $670,792,452 Site Specific:

Licensee:  % Owned: Amount of NRC Minimum/Site Specific: Amount in Trust Fund:

Entergy 10.00% $67,079,245 $75,475,193 Step 1:

Earnings Credit:

Real Rate of Years Left Trust Fund Balance: Return per in License Total Real Rate of Return: Total Earnings:

$75,475,193 2.91% 25.83 2.09814 $158,357,714 Total Earnings = Trust Fund balance x (1+RRR)^Years left in license Step 2:

Accumulation:

Value of Annuity per Real Rate of year Return per Years of Annuity: Total Annuity:

See Annuity Sheet 2.91% 0 $0 Total Step 2

$0 Total Step 1 + Step 2

$158,357,714 Step 3:

Decom Period:

Real Rate of Decom Total Earnings: Return per Period: Total Real Rate of Return: Total Earnings for Decom:

$158,357,714 2% 7 0.14869 $11,772,761 Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]

Accumulation during Decom Total of Steps 1 - 3:

$170,130,475 Total = Total Earnings + Total Earnings for Decom Excess (Shortfall) $ 103,051,230 to NRC minimum

$ (1,275,500) Less ISFSI

$ - Parent Co Guaranty

$ 101,775,730 Total Excess Financial Assurance

CNRO-2019-00007 (Page 6 of 10) Minimum Funding Assurance Calculation Worksheets Plant name: River Bend (Regulated 70%)

Month Day Year Year of Biennial: 12 31 2018 Termination of Operation: 8 29 2045 MWth 1986$ ECI Base Lx Lx Px Fx Ex Bx BWR 3091 $131,819,000 132.5 1.98 0.65 2.62 2.103 2.727 0.13 2.39 0.22 13.422 NRC Minimum: $654,986,595 Site Specific:

Licensee:  % Owned: Amount of NRC Minimum/Site Specific: Amount in Trust Fund:

Entergy 70.00% $458,490,616 $406,804,761 Step 1:

Earnings Credit:

Real Rate of Years Left Trust Fund Balance: Return per in License Total Real Rate of Return: Total Earnings:

$406,804,761 2.00% 26.66 1.69547 $689,726,348 Total Earnings = Trust Fund balance x (1+RRR)^Years left in license Step 2:

Accumulation:

Value of Annuity per Real Rate of year Return per Years of Annuity: Total Annuity:

See Annuity Sheet 2.00% 8 $85,150,688 Total Step 2

$85,150,688 Total Step 1 + Step 2

$774,877,036 Step 3:

Decom Period:

Real Rate of Decom Total Earnings: Return per Period: Total Real Rate of Return: Total Earnings for Decom:

$774,877,036 2% 7 0.14869 $57,606,555 Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]

Accumulation during Decom Total of Steps 1 - 3:

$66,479,570 $898,963,161 Total = Total Earnings + Total Earnings for Decom Excess (Shortfall) $ 440,472,545 to NRC minimum

$ (7,308,700) Less ISFSI

$ - Parent Co Guaranty

$ 433,163,845 Total Excess Financial Assurance

CNRO-2019-00007 (Page 7 of 10) Minimum Funding Assurance Calculation Worksheets Plant name: River Bend Station (Regulated 70%)

Assumed Termination of Operations: 2025 Real Total Year LPSC PUCT FERC Annuity: Rate of Accumulation 2019 $8,996,000 $1,126,000 $112,914 $10,234,914 2.0% $11,526,176 2020 $10,195,000 $1,126,000 $112,914 $11,433,914 2.0% $12,623,965 2021 $10,195,000 $1,126,000 $112,914 $11,433,914 2.0% $12,376,436 Total Accumulation = Annuity x (1+RRR)^Years left from 2022 $10,195,000 $1,126,000 $112,914 $11,433,914 2.0% $12,133,761 Accum 2023 $10,195,000 $1,126,000 $112,914 $11,433,914 2.0% $11,895,844 2024 $10,195,000 $1,126,000 $112,914 $11,433,914 2.0% $11,662,592 2025 $11,693,000 $1,126,000 $112,914 $12,931,914 2.0% $12,931,914 Total: $85,150,688 Accumulation During Assumed Decomm Period 2026 $11,693,000 $1,126,000 $112,914 $12,931,914 $12,931,914 2027 $11,693,000 $1,126,000 $112,914 $12,931,914 $12,931,914 2028 $11,693,000 $1,126,000 $112,914 $12,931,914 $12,931,914 2029 $11,693,000 $1,126,000 $112,914 $12,931,914 $12,931,914 2030 $13,513,000 $1,126,000 $112,914 $14,751,914 $14,751,914 2031 $0 $0 $0 $0 $0 2032 $0 $0 $0 $0 $0 2033 $0 $0 $0 $0 $0 2034 $0 $0 $0 $0 $0 Total: $66,479,570

  • Decommissioning collections based on original license termination of plant assumed when orders implementing collections were issued. Collections are subject to change in the future.

CNRO-2019-00007 (Page 8 of 10) Minimum Funding Assurance Calculation Worksheets Plant name: River Bend (Non-Regulated 30%)

Month Day Year Year of Biennial: 12 31 2018 Termination of Operation: 8 29 2045 MWth 1986$ ECI Base Lx Lx Px Fx Ex Bx BWR 3091 $131,819,000 132.5 1.98 0.65 2.62 2.103 2.727 0.13 2.39 0.22 13.422 NRC Minimum: $654,986,595 Site Specific:

Licensee:  % Owned: Amount of NRC Minimum/Site Specific: Amount in Trust Fund:

Entergy 30.00% $196,495,978 $396,547,484 Step 1:

Earnings Credit:

Real Rate of Years Left Total Real Trust Fund Balance: Return per in License Rate of Total Earnings:

$396,547,484 2% 26.66 1.69547 $672,335,415 Total Earnings = Trust Fund balance x (1+RRR)^Years left in license Step 2:

Accumulation:

Value of Annuity per Real Rate of year Return per Years of Annuity: Total Annuity:

$0 2% 0 $0 Real Rate of Years remaining after Total Annuity Return per annuity Total Step 2

$0 2% 26.66118721 $0 Total Step 1 + Step 2

$672,335,415 Step 3:

Decom Period:

Real Rate of Decom Total Real Total Earnings: Return per Period: Rate of Total Earnings for Decom:

$672,335,415 2% 7 0.14869 $49,983,320 Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]

Total of Steps 1 - 3:

$722,318,735 Total = Total Earnings + Total Earnings for Decom Excess (Shortfall) $ 525,822,757 to NRC minimum

$ (3,132,300) Less ISFSI

$ - Parent Co Guaranty

$ 522,690,457 Total Excess Financial Assurance

CNRO-2019-00007 (Page 9 of 10) Minimum Funding Assurance Calculation Worksheets Plant name: Waterford 3 Month Day Year Year of Biennial: 12 31 2018 Termination of Operation: 12 18 2044 MWth 1986$ ECI Base Lx Lx Px Fx Ex Bx PWR 3716 $105,000,000 132.5 1.98 0.65 2.62 2.103 2.727 0.13 2.37 0.22 12.853 NRC Minimum: $508,243,131 Site Specific:

Licensee:  % Owned: Amount of NRC Minimum/Site Specific: Amount in Trust Fund:

Entergy 100.00% $508,243,131 $481,644,236 Step 1:

Earnings Credit:

Real Rate of Years Left Trust Fund Balance: Return per in License Total Real Rate of Return: Total Earnings:

$481,644,236 2% 25.96 1.67224 $805,423,925 Total Earnings = Trust Fund balance x (1+RRR)^Years left in license Step 2:

Accumulation:

Value of Annuity per Real Rate of year Return per Years of Annuity: Total Annuity:

See Annuity Sheet 2% 7 $48,718,637 Total Step 2

$48,718,637 Total Step 1 + Step 2

$854,142,562 Step 3:

Decom Period:

Real Rate of Decom Total Earnings: Return per Period: Total Real Rate of Return: Total Earnings for Decom:

$854,142,562 2% 7 0.14869 $63,499,379 Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]

Accumulation during Decom Total of Steps 1 - 3:

$54,581,000 $972,222,940 Total = Total Earnings + Total Earnings for Decom Excess (Shortfall) $ 463,979,809 to NRC minimum

$ (9,040,000) Less ISFSI

$ - Parent Co Guaranty

$ 454,939,809 Total Excess Financial Assurance

CNRO-2019-00007 (Page 10 of 10) Minimum Funding Assurance Calculation Worksheets Plant name: Waterford Generating Station, Unit 3 Assumed Termination of Operations: 2025 Real Total Year LPSC CNO Annuity: Rate of Accumulatio 2019 $6,688,000 $133,000 $6,821,000 2.00% $7,681,554 2020 $7,580,000 $151,000 $7,731,000 2.00% $8,535,649 2021 $7,580,000 $151,000 $7,731,000 2.00% $8,368,283 Total Accumulation = Annuity x (1+RRR)^Years left from 2022 $7,580,000 $151,000 $7,731,000 2.00% $8,204,199 Accum 2023 $7,580,000 $151,000 $7,731,000 2.00% $8,043,332 2024 $7,580,000 $151,000 $7,731,000 2.00% $7,885,620 Total: $48,718,637 Accumulation During Assumed Decomm Period 2025 $8,867,000 $0 $8,867,000 2026 $8,867,000 $0 $8,867,000 2027 $8,867,000 $0 $8,867,000 2028 $8,867,000 $0 $8,867,000 2029 $8,867,000 $0 $8,867,000 2030 $10,246,000 $0 $10,246,000 2031 0 $0 $0 Total: $54,581,000

  • Decommissioning collections based on original license termination of plant assumed when orders implementing collections were issued. Collections are subject to change in the future.
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