CNRO-2017-00009, Entergy Nuclear Operations, Inc. - Decommissioning Funding Status Report Per 10 CFR 50.75(f)(1) and 10 CFR 50.82(a)(8)(v)

Entergy Nuclear Operations, Inc. - Decommissioning Funding Status Report Per 10 CFR 50.75(f)(1) and 10 CFR 50.82(a)(8)(v)

ML17093A926
Person / Time
Site:	Palisades, Indian Point, Pilgrim, Vermont Yankee, Big Rock Point, FitzPatrick
Issue date:	03/31/2017
From:	Ford B Entergy Nuclear Operations
To:	Document Control Desk, Office of Nuclear Material Safety and Safeguards, Office of Nuclear Reactor Regulation
References
CNRO-2017-00009
Download: ML17093A926 (36)

Text

z: # Entergy Nuclear Operations, Inc.

ntt9rg*)1 1340 Ech&on Parkway Tel: 601-368-5516 Bryan S. Ford Senior Manager, Fleet Regulatory Assurance CNRO-201 7-00009 March 31, 2017 U.S Nuclear Regulatory Commission Attn: Document Control Desk 11555 Rockville Pike Rockville, MD 20852-2738

SUBJECT:

Decommissioning Funding Status Report per 10 CFR §50.75(f)(1) and 10 CFR 50.82(a)(8)(v) -- Entergy Nuclear Operations, Inc.

Big Rock Point Indian Point Nuclear Docket No. 50-1 55 Generating Stations 1 2, & 3 Docket Nos. 50-3, 50-247, & 50-286 James A. FitzPatrick Pilgrim Nuclear Power Station Nuclear Power Plant Docket 50-293 Docket No. 50-333 Vermont Yankee Nuclear Power Station Palisades Nuclear Plant Docket No. 50-271 Docket No. 50-255

REFERENCES:

1. NUREG-1307, Report on Waste Burial Charges, Revision 16, dated November 2016.

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:

1 0 CFR 50.75(f)(1) requires each power reactor licensee to report to the NRC by March 31, 1 999, and every two years thereafter with certain exceptions, on the status of its decommissioning funding for each reactor, or share of a reactor, that it owns. 1 0 CFR 50.82(a)(8)(v) requires licensees of shutdown sites to report to the NRC annually, by March 31, on the status of decommissioning financial assurance for those sites. On behalf of Entergy Nuclear Indian Point 2, LLC (Indian Point 1 & 2), Entergy Nuclear Indian Point 3, LLC, Entergy Nuclear Vermont Yankee, LLC, Entergy Nuclear Generation Company (Pilgrim Station), Entergy Nuclear FitzPatrick, LLC, and Entergy Nuclear Palisades, LLC (Palisades and Big Rock Point),

Entergy Nuclear Operations, Inc. hereby submits the information requested for power reactors operated by Entergy Nuclear Operations, Inc. The reports provided in Attachments I through I 3 for the licensed facilities addressed by this filing, were prepared in accordance with NUREG I 307 (Reference 1) and NRC Regulatory Issue Summary 2001 -07 (Reference 2). Attachments 14 and 15 are updated site specific decommissioning cost estimates for Indian Point Unit I and Vermont Yankee, respectively. The Minimum Funding Assurance calculation worksheets, (not

CNRO-201 7-00009 Page 2 of 4 required for this filing) derived from LIC-205, Rev. 4, are provided in Attachment 1 6 for the convenience of the reviewer.

The estimated minimum decommissioning fund values were determined using the NRCs methodology in NUREG-1307, Rev 16.

The trust fund amounts reported for each facility in the responses to item 3 represent the market value of decommissioning trust funds as of December 31 201 6 net of any material current income tax liability on realized gains, interest, dividends and other income of the trusts. The trusts for the following plants had estimated balances on their 201 6 tax liabilities, not reflected in the trust fund balances, as follows (in thousands):

Indian Point 1 $ 0 Indian Point 2 $ 0 Indian Point 3 $ 0 Vermont Yankee $ 0 Pilgrim $ 0 FitzPatrick $ 0 Palisades $ 0 In accordance with guidance provided by the NRC Staff in April 2014 requests for additional information (Accession No. ML14120A273) that future 10 CFR 50.75(f) reports should clearly delineate estimate reactor and ISFSI decommissioning costs, the information in Attachments 1, 2, 3, 5, 7, 9, and 1 1 includes line item 2 identifying the ISFSI decommissioning obligation, escalated 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 14.

The aforementioned worksheets, using the December 31 201 6 trust fund balances (excepting Palisades, that uses the February 28, 2017 balance) and parent guarantee amounts, indicate that all of the plants covered by this submittal met or exceeded the NRCs funding requirements.

Accordingly, the licensees conclude that no further action is required at this time to demonstrate adequate funding assurance for decommissioning the plants covered by this submittal.

There are no new commitments made in this letter. If you have any questions, please contact me at (601) 368-5516.

Sincerely, BSF/ljs Attachments:

1 . Entergy Nuclear Operations, Inc. Status of Decommissioning Funding Indian Point 1

2. Entergy Nuclear Operations, Inc. Status of Decommissioning Funding Indian Point 2

3. Entergy Nuclear Operations, Inc. Status of Decommissioning Funding Indian Point 3

4. Entergy Nuclear Operations, Inc. Calculation of Minimum Amount Indian Point

5. Entergy Nuclear Operations, Inc. Status of Decommissioning Funding Vermont Yankee

CNRO-201 7-00009 Page 3 of 4

6. Entergy Nuclear Operations, Inc. Calculation of Minimum Amount Vermont Yankee

7. Entergy Nuclear Operations, Inc. Status of Decommissioning Funding Pilgrim

8. Entergy Nuclear Operations, Inc. Calculation of Minimum Amount Pilgrim

9. Entergy Nuclear Operations, Inc. Status of Decommissioning Funding James A. Fitzpatrick 1 0. Entergy Nuclear Operations, Inc. Calculation of Minimum Amount James A. Fitzpatrick 11 . Entergy Nuclear Operations, Inc. Status of Decommissioning Funding Palisades

12. Entergy Nuclear Operations, Inc. Calculation of Minimum Amount Palisades

13. Entergy Nuclear Operations, Inc. Status of Decommissioning Funding Big Rock Point

14. Entergy Nuclear Operations, Inc. IP1 DTF Balance Based on Decommissioning Funding Assurance Plan 1 5. Entergy Nuclear Operations, Inc. Vermont Yankee Annual Cash Flow Analysis 1 6. Entergy Nuclear Operations, Inc. Minimum Financial Assurance Calculation Worksheets cc: See next page

CNRO-201 7-00009 Page 4 of 4 cc: Mr. C. Bakken (ECH)

Mr. B. E. Green (TMBR)

Mr. J. R. Davis (ECH)

Mr. L. M. Coyle (ECH)

Mr. L. J. Smith (ECH)

Mr. J. A. Ventosa (ECH)

Mr. B. R. Sullivan (JAF)

Mr. J. A. Dent (PIL)

Mr. A. J. Vitale (IPEC)

Mr. C. F. Arnone(PAL)

Mr. J. W. Boyle (VTY)

USNRC Regional Administrator, Region I USNRC Regional Administrator, Region III USNRC Project Manager, Indian Point 1 USNRC Project Manager, Indian Point 2 I 3 USNRC Project Manager, J. A. FitzPatrick USNRC Project Manager, Palisades USNRC Project Manager, Pilgrim USNRC Project Manager, Vermont Yankee USNRC Resident Inspector, Indian Point 2 I 3 USNRC Resident Inspector, J. A. FitzPatrick USNRC Resident Inspector, Palisades USNRC Resident Inspector, Pilgrim USNRC Resident Inspector, Vermont Yankee Michigan Department of Environmental Quality Michigan Public Service Commission NYS Department of Public Service Vermont Department of Public Service Massachusetts Emergency Management Agency

Attachment I CNRO-201 7-00009 (Page 1 of 2)

Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding Indian Point I For Year Ending December 31, 2016 10 CFR 50.75(fl(I) and 10 CFR 50.82(a)f8)(v)

Plant Name: Indian Point Nuclear Generating Unit No. I 10 CFR 50.75(f)(I) 1 Minimum Financial Assurance (MFA)

[NotelJ

$590.76 million estimated per 10 CFR 50.75(b) and (c) (2016$)

2. ISFSI Obligation as of 12/31/16 [Note2J

$1 1 million

3. Decommissioning Trust Fund Total $ 442.9 million as of 12/31/16

4. A schedule of the annual amounts remaining to be collected None

5. Assumptions used in determining rates of escalation in 2% annual real rate decommissioning costs, rates of earnings on decommissioning of return per 1 0 CFR funds, and rates of other factors used in funding projections 50.75(e)(1)(i)

6. Any contracts upon which the licensee is relying pursuant to 10 None CFR 50.75(e)(1 )(v)

7. Modifications occurring to a licensees current method of providing None financial assurance since the last submitted report

8. Any material changes to trust agreements None Note I : This amount is based upon total SAFSTOR expenditures for radiological remediation and license termination set forth in the updated Decommissioning Funding Assurance Plan and SAFSTOR analysis that are provided in Attachment 1 4. (Calculation of the NRC Minimum Amount is provided in Attachment 4.)

Note 2: From 10 CFR 50.82(a)(8)(vii) filing for Indian Point I of March 2017.

Attachment I CNRO-201 7-00009 (Page 2 012)

Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding Indian Point I For Year Ending December 31, 2016 10 CFR 50.75(f)(J) and 10 CFR 50.82(a)(8)(v)

Plant Name: Indian Point Nuclear Generating Unit No. I 10 CFR 50.82(a)(8)(v) 1 Cumulative decommissioning spending [Notel]

$99.43 million

2. 2016 decommissioning spending $5.15 million [Notel]

3. Fund Balance See above in 10 CFR 50.75 information

4. No other financial assurance mechanism is being relied upon, but costs through 12/31/2016 have been funded by operations, and not the decommissioning fund.

5. Estimated costs to complete from latest estimate $560.5 million 0te2]

6. Estimate is based on unrestricted release of the site per I 0 CFR 20.1402

7. Modifications to financial assurance since last report See above in 10 CFR 50.75 information

8. Any material changes to trust agreements See above in 10 CFR 50.75 information Note I : Entergy does not possess records that would permit determination of charges to IPI prior to its acquisition in September 2001 by Entergy Nuclear Indian Point 2, LLC. The costs presented here represent those costs charged in 2016 and the total costs that have been assigned to IPI since 2001 Entergy has not fully determined what portion of those costs would be considered decommissioning costs as that term is defined in I 0 CFR 50.2. Cumulative and 201 6 decommissioning spending only consists of costs related to license termination.

Note 2: This amount is based upon total SAFSTOR expenditures for radiological remediation and license termination set forth in the updated Decommissioning Funding Assurance Plan and SAFSTOR analysis that are provided in Attachment 1 4. (Calculation of the NRC Minimum Amount is provided in Attachment 4.) This estimate does not include 2016 spending because current costs are being paid out of operating funds.

Attachment 2 CNRO-20J 7-00009 (Page 1 of 1)

Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding Indian Point 2 For Year Ending December 31, 2016 10 CFR 50.75(fl(1)

Plant Name: Indian Point Nuclear Generating Unit No. 2 I . Minimum Financial Assurance (MFA) $495.20 mitlion0te estimated per 10 CFR 50.75(b) and (c) (2016$)

2. ISFSI Obligation as of 12/31/16 [Note 2]

$5.8 million

3. Decommissioning Trust Fund Total

[Note 3]

as of 12/31/16 $564.01 million

4. A schedule of the annual amounts remaining to be collected None

5. Assumptions used in determining rates of escalation in 2% annual real rate decommissioning costs, rates of earnings on decommissioning of return per 10 CFR funds, and rates of other factors used in funding projections 50.75(e)(1 )(i)

6. Any contracts upon which the licensee is relying pursuantto 10 None CFR 50.75(e)(1 )(v)

7. Modifications occurring to a licensees current method of providing None financial assurance since the last submitted report

8. Any material changes to trust agreements None Note 1 : Calculation of the NRC Minimum Amount is provided in Attachment 4.

Note 2: From Entergys ISFSI Decommissioning Funding Plans Pursuantto 10 CFR 72.30, December 17, 2015 (Accession No. ML15351A524), escalated for inflation.

Note 3: Includes provisional fund balance of $32.42 million.

Attachment 3 CNRO-201 7-00009 (Page 1 cii)

Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding Indian Point 3 For Year Ending December 31, 2016 JO CFR 50.75(fl(1)

Plant Name: Indian Point Nuclear Generating Unit No. 3 i . Minimum Financial Assurance (MFA) $495.20 million [Note 11 estimated per iO CFR 50.75(b) and (c) (2016$)

2. ISFSI Obligation as of 12/31/16 $6.97 million [Note 2]

3. Decommissioning Trust Fund Total $ 7i9.iO million as of i2/3i/i6

4. A schedule of the annual amounts remaining to be collected None

5. Assumptions used in determining rates of escalation in 2% annual real rate decommissioning costs, rates of earnings on decommissioning of return per 10 CFR funds, and rates of other factors used in funding projections 50.75(e)(i)(i)

6. Any contracts upon which the licensee is relying pursuant to 10 None CFR 50.75(e)(i )(v)

7. Modifications occurring to a licensees current method of providing Note 3 financial assurance since the last submitted report

8. Any material changes to trust agreements Note 3 Note 1 : Calculation of the NRC Minimum Amount is provided in Attachment 4.

Note 2: From Entergys ISFSI Decommissioning Funding Plans Pursuant to iO CFR 72.30, December 17, 2015 (Accession No. ML15351A524), escalated for inflation.

Note 3: While the method for financial assurance (prepaid decommissioning fund) did not change, the decommissioning trust fund has been transferred from New York Power Authority to the licensee. See Order Approving Transfer Of Control Of Master Decommissioning Trust For Indian Point Nuclear Generating Unit No. 3 and James A.

Fitzpatrick Nuclear Power Plant From the Power Authority Of The State Of New York To Entergy Nuclear Operations, Inc., dated January 27, 20i7 (Accession No. ML16336A492), and application dated August i6, 2016 (Accession No. i6230A308).

Attachment 4 CNRO-201 7-00009 (Page 1 of I)

Entergy Nuclear Operations, Inc.

Calculation of Minimum Amount Indian Point For Year Ending December 31, 2016 JO CFR 50.75(fl(1)

Entergy Nuclear Indian Point 2, LLC: 100% ownership interest of Indian Point 1 & 2 Entergy Nuclear Indian Point 3, LLC: 100% ownership interest of Indian Point 3 Plant Location: Buchanan, New York Reactor Type: Pressurized Water Reactor (PWR)

Indian Point Unit I Power Level: <3,400 MWt (615 MWt)

Indian Point Unit I PWR Base Year 1986$: $85,560,000 Indian Point Unit 2 Power Level: <3,400 MWt (3,216 MWt)

Indian Point Unit 2 PWR Base Year 1986$: $103,300,800 Indian Point Unit 3 Power Level: <3,400 MWt (3,216 MWt)

Indian Point Unit 3 PWR Base Year 1986$: $103,300,800 Labor Region: North Waste Burial Facility: Generic Disposal Site I OCFR5O.75(c)(2) Escalation Factor Formula:

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

Factor L=Labor (North) 2.781 E=Energy (PWR) 1.872 B=Waste Burial-Vendor (PWR) 12.471 PWR Escalation Factor:

0.65(L) +0.13(E) +0.22(B)= 4.79373 1986 PWR Base Year $ Escalated:

Indian Point 1: $85,560,000

• Factor= $410,151,579 Indian Point 2 & 3: $103,300,800

• Factor= $495,196,193 1

Bureau of Labor Statistics, Series Report ID: CIU2OI000000021Oi (4th Quarter 2016) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpuO5Z3 (December 2016) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 16, Table 2.1 (2016)

Attachment 5 CNRO-201 7-00009 (Page 1 of 2)

Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding Vermont Yankee For Year Ending December 31, 2016 10 CFR 50.75(0(1) and 10 CFR 50.82(a)(8)(v)

Plant Name: Vermont Yankee Nuclear Power Station 10 CFR 50.75(f)(1)

1. Minimum Financial Assurance (MFA) $ 728.1 million [t0tehj estimated per 10 CFR 50.75(b) and (c) (2016$)

2. ISFSI Obligation as of 12/31/16 $5.20 million [Note 2]

3. Decommissioning Trust Fund Total $ 561.61 million as of 12/31/16

4. A schedule of the annual amounts remaining to be collected None

5. Assumptions used in determining rates of escalation in 2% annual real rate decommissioning costs, rates of earnings on decommissioning of return per 10 CFR funds, and rates of other factors used in funding projections 50.75(e)(1)(i)

6. Any contracts upon which the licensee is relying pursuant to I 0 None CFR 50.75(e)(1 )(v)

7. Modifications occurring to a licensees current method of None providing financial assurance since the last submitted report

8. Any material changes to trust agreements None Note 1 : This amount is based upon total SAFSTOR expenditures for radiological remediation and license termination set forth in the updated Decommissioning Funding Assurance Plan and SAFSTOR analysis provided in Attachment 1 5. (Calculation of the NRC Minimum Amount is provided in Attachment 6).

Note 2: From Entergys ISFSI Decommissioning Funding Plans Pursuantto 10 CFR 72.30, December 17, 2015 (Accession No. ML15351A524), escalated for inflation.

Attachment 5 CNRO-201 7-00009 (Page 2 of 2)

Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding Vermont Yankee For Year Ending December 31, 2016 JO CFR 50.75(fl(J) and 10 CFR 50.82(a)(8)(v)

Plant Name: Vermont Yankee Nuclear Power Station 10 CFR 50.82(a)(8)(v)

1. Cumulative decommissioning spending through 12/31/2016 11097 million

[NotelJ

2. 2016 decommissioning spending $ 36.62 million [Note2]

3. Fund Balance See above in 10 CFR 50.75 information

4. No other financial assurance mechanism is being relied upon.

5. Estimated costs to complete from latest estimate $ 728.1 million

6. Estimate is based on unrestricted release ofthe site per 10 CFR 20.1402

7. Modifications to financial assurance since last report See above in 10 CFR 50.75

\

information

8. Any material changes to trust agreements See above in 10 CFR 50.75 information Note 1 : Some decommissioning costs have been paid by the parent company, and not refunded from the decommissioning trust.

Note 2: This estimate only includes 2016 decommissioning costs. 2014 and 2015 costs are included in item I and have been reimbursed in 2016.

Attachment 6 CNRO-201 7-00009 (Page 1 of I)

Entergy Nuclear Operations, Inc.

Calculation of Minimum Amount Vermont Yankee For Year Ending December 31, 2016 JO CFR 50.75(fl(J)

Entergy Nuclear Vermont Yankee LLC. : I 00% ownership interest Plant Location: Vernon, Vermont Reactor Type: Boiling Water Reactor (BWR)

Power Level: <3,400 MWt (1912 MWt)

BWR Base Year 1986$: $121,208,000 Labor Region: North Waste Burial Facility: Generic Disposal Site IOCFR5O.75(c)(2) Escalation Factor Formula:

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

Factor L=Labor (North) 2.781 E=Energy (BWR) 1.872 B=Waste Burial-Vendor (BWR) 13.132 BWR Escalation Factor:

0.65(L) +0. 1 3(E) +0.22(B)= 4.93900 1986 BWR Base Year $ Escalated:

$121,208,000

• Factor= $598,646,270 1

Bureau of Labor Statistics, Series Report ID: CIU2O100000002IOi (4th Quarter 2016) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2016) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 16, Table 2.1 (2016)

Attachment 7 CNRO-201 7-00009 (Page 1 of 1)

Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding Pilgrim For Year Ending December 31, 2016 JO CFR 50.75(fl(1)

Plant Name: Pilgrim Nuclear Power Station 1 . Minimum Financial Assurance (MFA) $ 603.80 million [Note 1]

estimated per 10 CFR 50.75(b) and (c) (2016$)

2. ISFSI Obligation as of 12/31/16 $9.21 million [Note 2]

3. Decommissioning Trust Fund Total $ 96030 million as of 12/31/16

4. A schedule of the annual amounts remaining to be collected None

5. Assumptions used in determining rates of escalation in 2% annual real rate decommissioning costs, rates of earnings on decommissioning of return per 10 CFR funds, and rates of other factors used in funding projections 50.75(e)(1 )(i)

6. Any contracts upon which the licensee is relying pursuant to I 0 None CFR 50.75(e)(1 )(v)

7. Modifications occurring to a licensees current method of None providing financial assurance since the last submitted report

8. Any material changes to trust agreements None Note 1 : Calculation of the NRC Minimum Amount is provided in Attachment 8.

Note 2: From Entergys ISFSI Decommissioning Funding Plans Pursuantto 10 CFR 72.30, December 17, 2015 (Accession No. ML15351A524), escalated for inflation.

Attachment 8 CNRO-201 7-00009 (Page 1 of I)

Entergy Nuclear Operations, Inc.

Calculation of Minimum Amount Pilgrim For Year Ending December 31, 2016 10 CFR 50.75(fl(1)

Entergy Nuclear Generation Co.: 100% ownership interest Plant Location: Plymouth, Massachusetts Reactor Type: Boiling Water Reactor (BWR)

Power Level: <3,400 MWt (2028 MWt)

BWR Base Year 1986$: $122,252,000 Labor Region: North Waste Burial Facility: Generic Disposal Site IOCFR5O.75(c)(2) Escalation Factor Formula:

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

Factor L=Labor (North) 2.781 E=Energy (BWR) I .872 B=Waste Burial-Vendor (BWR) 13.132 BWR Escalation Factor:

0.65(L) +0. 1 3(E) +0.22(B)= 4.93900 1986 BWR Base Year $ Escalated:

$122,252,000 Factor= $603,802,586 1

Bureau of Labor Statistics, Series Report ID: CIU2OI000000021Oi (4th Quarter 2016) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2016) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 16, Table 2.1 (2016)

Attachment 9 CNRO-201 7-00009 (Page 1 of I)

Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding James A. Fitzpatrick For Year Ending December 31, 2016 10 CFR 50.75(fl(J)

Plant Name: James A. Fitzpatrick Nuclear Power Plant 1 . Minimum Financial Assurance (MFA) $ 626.38 million [Note 1]

estimated per 10 CFR 50.75(b) and (c) (2016$)

2. 1SFSI Obligation as of 12/31/16 $ 8.38 million [Note 21

3. Decommissioning Trust Fund Total $ 784.67 million as of 12/31/16

4. A schedule of the annual amounts remaining to be collected None

5. Assumptions used in determining rates of escalation in 2% annual real rate decommissioning costs, rates of earnings on of return per 10 CFR decommissioning funds, and rates of other factors used in 50.75(e)(1)(i) funding projections

6. Any contracts upon which the licensee is relying pursuant to None 10 CFR 50.75(e)(1)(v)

7. Modifications occurring to a licensees current method of Note 3 providing financial assurance since the last submitted report

8. Any material changes to trust agreements Note 3 Note 1 : Calculation of the NRC Minimum Amount is provided in Attachment I 0.

Note 2: From Entergys ISFSI Decommissioning Funding Plans Pursuantto 10 CFR 72.30, December 17, 2015 (Accession No. ML15351A524), escalated for inflation.

Note 3: While the method for financial assurance (prepaid decommissioning fund) did not change, the decommissioning trust fund has been transferred from New York Power Authority to the licensee. See Order Approving Transfer Of Control Of Master Decommissioning Trust For Indian Point Nuclear Generating Unit No. 3 and James A.

Fitzpatrick Nuclear Power Plant From the Power Authority Of The State Of New York To Entergy Nuclear Operations, Inc., dated January 27, 2017 (Accession No. ML16336A492), and application dated August 16, 2016 (Accession No. 16230A308).

Attachment JO CNRO-201 7-00009 (Page 1 of 1)

Entergy Nuclear Operations, Inc.

Calculation of Minimum Amount James A. Fitzpatrick For Year Ending December 31, 2OJ6 JO CFR 50.75(fl(1)

Entergy Nuclear FitzPatrick LLC.: 100% ownership interest Plant Location: Oswego, New York Reactor Type: Boiling Water Reactor (BWR)

Power Level: <3,400 MWt (2536 MWt)

BWR Base Year J986$: $126,824,000 Labor Region: North Waste Burial Facility: Generic Disposal Site JOCFR5O.75(c)(2) Escalation Factor Formula:

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

Factor L=Labor (North) 2.781 EEnergy (BWR) I .872 B=Waste Burial-Vendor (BWR) 13.132 BWR Escalation Factor:

0.65(L) +0. 1 3(E) +0.22(B)= 4.93900 J986 BWR Base Year $ Escalated:

$126,824,000

• Factor= $626,383,692 1

Bureau of Labor Statistics, Series Report ID: CIU2OI00000002IOi (4th Quarter 2016) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2016) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 16, Table 2.1 (2016)

Attachment 11 CNRO-201 7-00009 (Page 1 of I)

Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding Palisades For Year Ending December 31, 2016 10 CFR 50.75(fl(J)

Plant Name: Palisades Nuclear Plant I . Minimum Financial Assurance (MFA) $ 457.25 million [Note 1]

estimated per 10 CFR 50.75(b) and (c) (2016$)

2. ISFSI Obligation as of 12/31/16 $ 7.86 million [Note 2]

3. Decommissioning Trust Fund Total $ 425.73 million 0te 31 as of 2/28/17

4. A schedule of the annual amounts remaining to be collected None

5. Assumptions used in determining rates of escalation in 2% annual teal rate decommissioning costs, rates of earnings on of return per I 0 CFR decommissioning funds, and rates of other factors used in 50.75(e)(1)(i) funding projections

6. Any contracts upon which the licensee is relying pursuant to None 10 CFR 50.75(e)(1)(v)

7. Modifications occurring to a licensees current method of None providing financial assurance since the last submitted report

8. Any material changes to trust agreements None Note 1: Calculation ofthe NRC Minimum Amount is provided in Attachment 12.

Note 2: From Entergys ISFSI Decommissioning Funding Plans Pursuant to 10 CFR 72.30, December 17, 2015 (Accession No. ML15351A524), escalated for inflation.

Note 3: The fund balance as of December 31 201 6 was $41 I .8 million.

Attachment 12 CNRO-201 7-00009 (Page 1 of 1)

Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding Palisades For Year Ending December 31. 2016 10 CFR 50.75(fl(1)

Entergy Nuclear Palisades LLC.: 100% ownership interest Plant Location: Covert, Michigan Reactor Type: Pressure Water Reactor (PWR)

Power Level: <3,400 MWt (2565 MWt)

PWR Base Year 1986$: $97,572,000 Labor Region: Midwest Waste Burial Facility: Generic Disposal Site I OCFR5O.75(c)(2) Escalation Factor Formula:

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

Factor L=Labor (Midwest) 2.611 E=Energy (PWR) 1.872 B=Waste Burial-Vendor (PWR) 12.471 PWR Escalation Factor:

0.65(L) +0. 1 3(E) +0.22(B)= 4.68625 1986 PWR Base Year $ Escalated:

$97,572,000 Factor= $457,246,441 1

Bureau of Labor Statistics, Series Report ID: C1U2010000000230i (4th Quarter 2016) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2016) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 16, Table 2.1 (2016)

Attachment 13 CNRO-201 7-00009 (Page 1 of I)

Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding Big Rock Point For Year Ending December 31, 2016 10 CFR 50.75(fl(f)

Plant Name: Big Rock Point ISFSI I . Amount of decommissbning funds required from $ 2.50 million [Note 11 most recent estimate (2016 dollars).

2. Decommissioning Funding Assurance Method. Parent Guarantee ($5 million)

3. A schedule of the annual amounts remaining to None be collected

4. Assumptions used in determining rates of Escalation rate: CPIU escalation in decommissioning costs, rates of earnings on decommissioning funds, and rates of Rate of earnings: n/a other factors used in funding projections

5. Any contracts upon which the licensee is relying None pursuant to 10 CFR 50.75(e)(1)(v)

6. Modifications occurring to a licensees current None method of providing financial assurance since the last submitted report

7. Any material changes to trust agreements None Note 1 : From Entergys ISFSI Decommissioning Funding Plans Pursuant to 1 0 CFR 72.30, December 17, 2015 (Accession No. ML15351A524), escalated for inflation.

Attachment 14 CNRO-201 7-00009 (Page 1 of 4)

Entergy Nuclear Operations, Inc.

IPI DIF Balance Based on Decommissioning Funding Assurance Plan E2r Year Ending December 31, 2016 JO CFR 50.75(fihi) on October 23, 2008, Entergy Nuclear Indian Point 2, LLC (ENIP2) submitted a preliminary decommiSsiOning cost analysis to the NRC in conjunction with its spe fue ma nt l nagement plan under 10 CFR 50.75(f)(3) and 10 CFR 50.54(bb) (Accession No. ML083040378, as supplemented by ENIP2s reply to PAls on July 1 5, 2009 (Accession No. ML092050204). The preliminary decommissioning cost analysis contained separate site-specific decommissioning cost estimates for lndian Point I and Indian Point 2. The estimates were subsequently found to be reasonable by the NRC on March 17, 2010 (Accession No. MLI 00280544).

Pursuantto Regulatory Guide 1.159, Revision 2, adjustmenttO the site-specific cost estim ates should be made at least once a year for the effects of inflation. Adjustment to site-specific cost estimates for the effects of technological and status changes should be made according to the amount of change experienced, as appropriate, but in no event, less than once every 5 years.

As such, ENIP2 has updated the aforementioned estimates consistent with the requirements of Regulatory Guide 1.159, Revision 2.

ENIP2 has determined that use of a SAFSTOR analysis shows that there is presently reasonable assurance that adequate funds will be available for the decommissioning proces in s

compliance with NRC ecommi55ioning funding assurance rules.

Pursuant to I 0 CFR 50.75(e)(1)(i), A licensee that has prepaid funds based on a site-specifi c

estimate under § 50.75(b)(1 ) of this section may take credit for projected earnings on the prepaid ecommi55ioning trust funds, using up to a 2 percent annual real rate of return from the time of future funds collection through the projected ecommis5iOning period, provided that the site-specific estimate is based on a period of safe storage that is specifically described in the estimate. ENIP2 understands that a facility-specific analysis may be used for demonstrating the adequacy of decommissioning funds, provided that the NRC-required cost estimate for ecommi55iOning costs as defined in I 0 CFR 50.2 is equal to or greate than r the amount stated in the formulas in I 0 CFR 50.75(c)(1 ) and (2) as the basis for justifying a higher than minimum funding level. (Regulatory Guide 1.159 Rev. 2, Section 1.1.1) ENIP2 also understands that NRC should be provided the analysis, and that the analysis should include data for each year of the analysis.

The updated Indian Point I site-specific decommissioning cost estimate is based on a period of safe storage that is specifically described in the estimate, namely storage until 2073, at which time the plant will be decommissioned and the site released for alternative use without restriction. Table 14-1 below provides the annual license termination costs computed in the updated estimate. These costs to date have been funded by operations, and not by the decommissioning fund. The decommissioning trust fund (DTF) ending bal ance is escalated each year by the 2% real growth figure allowed pursuant to I 0 CFR 50.75(e)(1)(i).

Attachment 14 CNRO-201 7-00009 (Page 2 of 4)

Entergy Nuclear Operations, Inc.

IPI DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2016 10 CFR 50.75(fl(1)

Table 14-1 NRC License Termination Cost

($ millions) 2016 $ Unit I Ending DTF Radiological Balance 2017 0.970 450.743 2018 3.878 455.880 2019 3.878 461.119 2020 3.889 466.453 2021 3.878 471 .904 2022 3.878 477.464 2023 3.878 483.135 2024 3.889 488.910 2025 3.878 494.810 2026 3.878 500.828 2027 3.878 506.966 2028 3.889 513.217 2029 3.878 519.603 2030 3.878 526.118 2031 3.878 532.762 2032 3.889 539.529 2033 3.878 546.441 2034 3.878 553.492 2035 3.878 560.684 2036 3.889 568.009 2037 3.878 575.491 2038 3.878 583.123 2039 3.878 590.907 2040 3.889 598.837 2041 3.878 606.935 2042 3.878 615.196 2043 3.878 623.622 2044 3.889 632.206 2045 3.878 640.972 2046 3.878 649.913 2047 3.878 659.034 2048 3.889 668.326 2049 3.878 677.814 2050 3.878 687.492 2051 3.878 697.364 2052 3.889 707.423 2053 3.878 717.693

Attachment 14 CNRO-201 7-00009 (Page 3 of 4)

Entergy Nuclear Operations, Inc.

IPI DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2016 10 CFR 50.75(f)(1)

Table 14-1 NRC License Termination Cost

($ millions) 2016 $ Unit I Ending DTF Radiological Balance 2054 3878 728.169 2055 3.878 738.855 2056 3.889 749.743 2057 3.878 760.860 2058 3.878 772.199 2059 3.878 783.765 2060 3.889 795.552 2061 3.878 807.585 2062 3.878 81 9.858 2063 3.878 832.378 2064 3.889 845.136 2065 28.467 833.572 2066 62.491 787.752 2067 104.214 699.294 2068 110.621 602.659 2069 15.962 598.750 2070 15.854 594.871 2071 15.854 590.915 2072 15.897 586.836 2073 7.818 590.755 Total 560.541

Attachment 14 CNRO-201 7-00009 (Page 4 of 4)

Entergy Nuclear Operations, Inc.

IPI DTF Balance Based on Decommissioning Funding Assurance Plan ForYear Ending December 31, 2016 10 CFR 50.75(0(1)

As can be seen from the information provided in Table 1 4-1 the required funding for SAFSTOR decommissioning, $560.54 million, is greater than the NRC formula amount per I 0 CFR 50.75(b) and (c) of $410.15 million, therefore, the site-specific analysis complies with the requirementfrom Regulatory Guide 1.159 section 1.1.1 previously discussed. The foregoing SAFSTOR analysis shows that when the December 31, 2016 DTF balance is escalated at the allowable rate and compared against the annual figures for the SAFSTOR period, that an approximately $590.76 million surplus exists at the end of the decommissioning project.

Accordingly, ENIP2 concludes that no further action is required at this time to demonstrate adequate funding assurance for decommissioning Indian Point I.

Attachment 15 CNRO-201 7-00009 (Page 1 of 6)

Entergy Nuclear Operations, Inc.

Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2016 10 CFR 50.75(f)(1)

Vermont Yankee Nuclear Power Station (Vermont Yankee) permanently ceased operations on December 29, 2014. The Vermont Yankee decommissioning trust fund balance is approximately $562 million as of December 31 201 6. Tables 3.4 and 3.5 of the site-specific decommissioning cost estimate (Reference 1 Attachment I set forth the estimated annual

)

expenditures for license termination and spent fuel management, respectively. A cash flow analysis utilizing this annual expenditure information is included as Table I 5-1.

The cash flow analysis demonstrates that the Vermont Yankee decommissioning trust fund is sufficiently funded for all license termination activities and certain spent fuel management activities (i.e., operational costs). As discussed in the Irradiated Fuel Management Program Update (Reference 2) costs related to spent fuel management operations (e.g., operations and maintenance costs for the spent fuel pool and Independent Spent Fuel Storage Installation, totaling approximately $175 million, Table 15-1 Column 2, minus Column 3 amounts funded by external credit facilities) will be funded from the decommissioning trust fund. Entergy Nuclear Operations, Inc. obtained an exemption that allows the use of trust funds for spent fuel management activities (NRC Approval of Exemption Request for Spent Fuel Management, 80 Fed. Reg. 35992, June 23, 2015).

The licensee has determined that use of a SAFSTOR analysis shows that there is presently reasonable assurance that adequate funds will be available for the decommissioning process in compliance with NRC decommissioning funding assurance rules.

Pursuant to I 0 CFR 50.75(e)(1)(i), A licensee that has prepaid funds based on a site-specific estimate under § 50.75(b)(1) of this section may take credit for projected earnings on the prepaid decommissioning trust funds, using up to a 2 percent annual real rate of return from the time of future funds collection through the projected decommissioning period, provided that the site-specific estimate is based on a period of safe storage that is specifically described in the estimate. The licensee understands that a facility-specific analysis may be used for demonstrating the adequacy of decommissioning funds, provided that the NRC-required cost estimate for decommissioning costs as defined in I 0 CFR 50.2 is equal to or greater than the amount stated in the formulas in 10 CFR 50.75(c)(1) and (2) as the basis forjustifying a higher than minimum funding level. (Regulatory Guide 1.159 Rev. 2, Section 1.1.1.) The licensee also understands that NRC should be provided the analysis, and that the analysis should include data for each year of the analysis. An updated decommissioning estimate was provided with the licensees Post Shutdown Decommissioning Activities Report on December 19, 2014 (Accession No. ML14357A110).

The updated Vermont Yankee site-specific decommissioning cost estimate is based on a period of safe storage that is specifically described in the estimate, namely storage until approximately 2075, at which time the plant will be decommissioned and the site released for alternative use without restriction. Table 15-1 below provides the annual license termination and spent fuel management costs computed in the updated estimate. The decommissioning trust fund (DTF) ending balance is escalated each year by the 2% real growth figure allowed pursuantto 10 CFR 50.75(e)(1 )(i).

Attachment 15 CNRO-201 7-00009 (Page2 of 6)

Entergy Nuclear Operations, Inc.

Vermont Yankee Annual Cash Flow Analysis ForYear Ending December 31, 2016 10 CFR 50.75(fl(1) -

Thus, considering the fund balance of $562 million, as of December 31 201 6, and projected ,

fund earnings during the SAFSTOR period (assuming an annual 2% growth rate), the trust fund is expected to have an excess of $196.6 million after completion of license termination and the operational spent fuel management activities that will be funded by the trust fund.

REFERENCES:

1 . Letter, Entergy Nuclear Operations, Inc. to USNRC, Post Shutdown Decommissioning Activities Report, BW 14-078, dated December 19, 2014 (Accession No. ML14357A110).

2. Letter, Entergy Nuclear Operations, Inc. to USNRC, Update to Irradiated Fuel Management Program Pursuant to 10 CFR 50.54(bb), BVY 14-085, dated December 19, 2014(Accession No. ML14358A251).

3. NRC Approval of Exemption Request for Spent Fuel Management, 80 Fed. Reg. 35992 (June 23, 2015).

Table 15.1 Vermont Yankee Nuclear Power Station SAFSTOR Methodology Annual Cash Flow Analysis Total License Termination, Spent Fuel Management less Dry Fuel Costs (In Thousands in 2016 Dollars) (see column definitions below)

Year Column I Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 Column 9 50.75 50.54 (bb) Exclude License Beginning Withdraw Contribute Trust Year License Spent Fuel Dry Fuel Termination of Year ($000s) ($000s) Fund Termination Ending Management Spent Fuel Cost plus Trust Fund Earnings Cost Trust Cost Management Spent Fuel Balance ($000s)

($000s) Fund

($000s) Cost Management ($000s) Balance

($000s) Cost less ($000s)

Dry Fuel Cost

($000s) 2017 42386 64,082 46,134 60,333 561,615 60,333 0 10,026 511,307 2018 51,878 60,258 43,366 68,771 511,307 68,771 0 8,851 451,387 2019 5,414 4,131 9,545 451,387 9,545 0 8,837 450,678 2020 5,362 4,131 9,492 450,678 9,492 0 8,824 450,010 2021 5,362 4,131 9,492 450,010 9,492 0 8,810 449,327 2022 3,741 4,131 7,872 449,327 7,872 0 8,829 450285 2023 3,741 4,131 7,872 450,285 7,872 0 8,848 451,261 2024 3,741 4,142 7,883 451,261 7,883 0 8,868 452,245 2025 3,680 4,131 7,811 452,245 7,811 0 8,889 453,323 2026 3,829 4,131 7,960 453,323 7,960 0 8,907 454,271 2027 3,882 4,131 8,012 454,271 8,012 0 8,925 455,183 2028 3,838 4,142 7,980 455,183 7,980 0 8,944 456,148

Attachment 15 CNRO-201 7-00009 (Page 3 of 6)

Entergy Nuclear Operations, Inc.

Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2016 10 CFR 50.75(fl(1) -

Table 15-1 Vermont Yankee Nuclear Power Station SAFSTOR Methodology Annual Cash Flow Analysis Total License Termination, Spent Fuel Management less Dry Fuel Costs (In Thousands in 2016 Dollars) (see column definitions below)

Year Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 Column 9 50.75 50.54 (bb) Exclude License Beginning Withdraw Contribute Trust Year License Spent Fuel Dry Fuel Termination of Year ($000s) ($000s) Fund Ending Termination Management Spent Fuel Cost plus Trust Fund Earnings Trust Cost Cost Management Spent Fuel Balance f$000s) Fund

($000s) ($000s) Cost Management ($000s) Balance

($000s) Cost less ($000s)

Dry Fuel Cost

($000s) 2029 3,829 4,131 7,960 456,148 7,960 0 8,964 457,152 2030 3,882 4,131 8,012 457,152 8,012 0 8,983 458,122 2031 3,829 4,131 7,960 458,122 7,960 0 9,003 459,166 2032 3,838 4,142 7,980 459,166 7,980 0 9,024 460,209 2033 3,882 4,131 8,012 460,209 8,012 0 9,044 461,241 2034 3,829 4,131 7,960 461,241 7,960 0 9,066 462,347 2035 3,829 4,131 7,960 462,347 7,960 0 9,088 463,475 2036 3,891 4,142 8,033 463,475 8,033 0 9,109 464,551 2037 3,829 4,131 7,960 464,551 7,960 0 9,132 465,724 2038 3,829 4,131 7,960 465,724 7,960 0 9,155 466,919 2039 3,882 4,131 8,012 466,919 8,012 0 9,178 468,085 2040 3,838 4,142 7,980 468,085 7,980 0 9,202 469,307 2041 3,829 4,131 7,960 469,307 7,960 0 9,227 470,574 2042 3,882 4,131 8,012 470,574 8,012 0 9,251 471,813 2043 3,829 4,131 7,960 471,813 7,960 0 9,277 473,131 2044 3,838 4,142 7,980 473,131 7,980 0 9,303 474,454 2045 3,882 4,131 8,012 474,454 8,012 0 9,329 475,770 2046 3,829 4,131 7,960 475,770 7,960 0 9,356 477,167 2047 3,829 4,131 7,960 477,167 7,960 0 9,384 478,591 2048 3,891 4,142 8,033 478,591 8,033 0 9,411 479,970 2049 3,829 4,131 7,960 479,970 7,960 0 9,440 481,451 2050 3,829 4,131 7,960 481,451 7,960 0 9,470 482,961 2051 3,882 4,131 8,012 482,961 8,012 0 9,499 484,447 2052 3,838 4,142 7,980 484,447 7,980 0 9,529 485,997 2053 3,671 0 3,671 485,997 3,671 0 9,647 491,972 2054 3,724 0 3,724 491,972 3,724 0 9,765 498,013 3,671 0 3,671 498,013 3,671 0 9,887 504,228 2056 3,680 0 3,680 504,228 3,680 0 10,011 510,559

Attachment 15 CNRO-201 7-00009 (Page 4 of 6)

Entergy Nuclear Operations, Inc.

Vermont Yankee Annual Cash Flow Analysis ForYear Ending December 31, 2016 10 CFR 50.75(fl(1) -

Table 15-1 Vermont Yankee Nuclear Power Station SAFSTOR Methodology Annual Cash Flow Analysis Total License Termination, Spent Fuel Management less Dry Fuel Costs (In Thousands in 2016 Dollars) (see column definitions below)

Year Column I Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 Column 9 50.75 5O54 (bb) Exclude License Beginning Withdraw Contribute Trust Year License Spent Fuel Dry Fuel Termination of Year ($000s) ($000s) Fund Ending Termination Management Spent Fuel Cost plus Trust Fund Earnings Trust Cost Cost Management Spent Fuel Balance ($000s) Fund

($000s) ($000s) Cost Management ($000s) Balance

($000s) Cost less ($000s)

Dry Fuel Cost

($000s) 2057 3724 0 3,724 510,559 3,724 0 10,137 516971 2058 3,671 0 3,671 516,971 3,671 0 10,266 523,566 2059 3,671 0 3,671 523,566 3,671 0 10,398 530,292 2060 3,733 0 3,733 530,292 3,733 0 10,531 537,091 2061 3,671 0 3,671 537,091 3,671 0 10,668 544,088 2062 3,671 0 3,671 544,088 3,671 0 10,808 551,225 2063 3,724 0 3,724 551,225 3,724 0 10,950 558,451 2064 3,680 0 3,680 558,451 3,680 0 11,095 565,865 2065 3,671 0 3,671 565,865 3,671 0 11,244 573,438 2066 3,724 0 3,724 573,438 3,724 0 11,394 581,108 2067 3,671 0 3,671 581,108 3,671 0 11,549 588,986 2068 33,520 0 33,520 588,986 33,520 0 11,109 566,575 2069 74,947 0 74,947 566,575 74,947 0 9,833 501,460 2070 107,412 0 107,412 501,460 107,412 0 7,881 401,930 2071 87,194 0 87,194 401,930 87,194 0 6,295 321,030 2072 87,640 0 87,640 321,030 87,640 0 4,668 238,058 2073 51,945 0 51,945 238,058 51,945 0 3,722 189,834 2074 537 0 537 189,834 537 0 3,786 193,084 2075 310 0 310 193,084 310 0 3,855 196,629 728,091 264,875 89,500 903,466 561,615 903,466 538,480 196,629 As can be seen from the information provided in Table I 5-1 the required funding for SAFSTOR decommissioning, $728.09 million, is greater than the NRC formula amount per I 0 CFR 50.75(b) and (c) of $598.65 million, therefore, the site-specific analysis complies with the requirementfrom Regulatory Guide 1.159 section 1.1.1 previously discussed. The cash flows for the years 201 7-2020 reflect completion of the transfer to dry fuel storage in 201 8, contingent upon certain regulatory approvals. The foregoing SAFSTOR analysis shows that when the December 31 2016 DTF balance is escalated at the allowable rate and compared against the

Attachment 15 CNRO-201 7-00009 (Page 5 of 6)

Entergy Nuclear Operations, Inc.

Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2016 10 CFR 50.75(fl(1) annual figures for the SAFSTOR period, that an approximately $1 96.6 million surplus exists at the end of the decommissioning project. Accordingly, the licensee concludes that no further action is required at this time to demonstrate adequate funding assurance for decommissioning Vermont Yankee.

Table 15-1 Definitions:

Column 1: 50.75 License Termination Cost Reflects the Total Annual License Termination Plan cost in 2016 dollars at a 0.0% escalation rate Column 2: 50.54 (bb) Spent Fuel Management Cost Reflects the Total Annual Irradiated Fuel Management Plan cost in 2016 dollars at a 0.0% escalation rate Column 3: Exclude Transfer to Div Fuel Storage Cost Reflects the Transfer to Dry Fuel Storage Cost included in Column 2 that is planned to be funded by external credit facilities, in 2016 dollars at a 0.0%

escalation rate Column 4: License Termination Cost plus Spent Fuel Management Cost less Transfer to Dry Fuel Storage Cost Reflects the Total Annual License Termination Plan cost plus Total Spent Fuel Management Plan cost less Transfer to Dry Fuel Storage cost all in 2016 dollars at a 0.0% escalation rate (Column I + Column 2 Column 3)

Column 5: Beginning of Year Trust Fund Balance Reflects the beginning of year Trust Fund balance in 201 6 dollars at a 0.0%

escalation rate and 2.0% Fund Earnings

Attachment 15 CNRO-201 7-00009 (Page6 of 6)

Entergy Nuclear Operations, Inc.

Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2016 10 CFR 50.75(fl(1)

Column 6: Withdraw Reflects the annual expenditures from the Trust Fund in 2016 dollars at a 0.0%

escalation rate (equals Column 4)

Column 7: Contribute Reflects the annual contributions to the Trust Fund in 2016 dollars at a 0.0%

escalation rate Column 8: Trust Fund Earnings Reflects earnings on funds remaining in the trust. A 2.0% Earnings rate is used over a 0.0% cost escalation rate. The Annual 2.0% earnings are calculated on the beginning balance less I 00% of the projected annual expenditure for each year. (Column 5 100% of Column 6) 2.0%

Column 9: Year Ending Trust Fund Balance Reflects the end of year Trust Fund balance after all projected earnings are added and all projected expenditures are deducted specified at a 0.0%

escalation rate and 2.0% Fund Earnings in 2016 dollars. (Column 5 Column 6

- +

Column 7 + Column 8)

Attachment 16 CNRO-201 7-00009 (Page 1 off)

Entergy Nuclear Operations, Inc.

Minimum Financial Assurance Calculation Worksheets Plant name: Indian Point Energy Center, Unit I Month Day Year YearofBiennial: 12 31 2016 Termination of Operation: 9 28 2013 i!Wi!! I I ECI Base Lx Lx Px Fx I PWR 615 $85,560,000 128.7 2.16 0.65 2.78 1.883 1.854 0.13 1.87 0.22 12471 f

NRC M inimum: $41 0,1 51 ,579 Site Specific: $560,540,912 Licensee: %Owned: Amount of NRC MinimumlSite Specific: Amount in Trust Fund Entergy 100.00% $560,540,912 $442,855,300 Note: See Attachment 14 for adequacy ofthe trust fund.

Attachment 16 CNRO-201 7-00009 (Page 2 off)

Entergy Nuclear Operations, Inc.

Minimum Financial Assurance Calculation Worksheets Plant name: Indian Point Energy Center, Unit 2 Month Day Year Year of Biennial: 12 31 2016 Termination ofOperation: 9 28 2013

!Wi Ed BaseLx Px Fx I PWR I I 3216 f$103,300,800[

I 128.7 I 216 I 0.65 HI2.78 1.883 Ir 1854 0.13 1.87 0.22 12.471 NRC Minimum: $495,196,193 Site Specific:

I Licensee: I  % Owned: I Amount of NRC MinimumlSite Specific: 1Amount n Trust Fund:I r Entergy iOO.OO% $495,196,193 I $564,012,057 Step 1:

Earnings Credit:

Real Rate of Yeats Left Total Real Ttust Fund Balance: Return pet in License Rate of Total Eatnings: I

$564,012,057 2% 0.00 1.00000 $564,012,057 ITotal Earnings = Trust Fund balance x (J+RRR)AYears left in license Step 2:

Accumulation:

Value ofAnnuity pet Real Rate of veat Retutn oet Yeats ofAnnuity: Total Annuity:

$0 2% 0 $0 Step 3:

Decom Period:

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

$564,012,057 2% 7 0.14869 $41,930,255 Total Earnings for Decom = (112) x Total Earnings x [(1+RRR)Decom period - 1]

I Total ofSteps 1 -3:

I $605,942,312 = Total Earnings + Total Earnings for Decom 1 Total Excess(Shortfall) $ 110,746,119 toNRCminimum

$ (6,968,434) Less ISFSI

$ - Parent Co Guaranty

$ 103,777,685 Total Excess Financial Assurance

Attachment 16 CNRO-201 7-00009 (Page 3 of 7)

Entergy Nuclear Operations, Inc.

Minimum Financial Assurance Calculation Worksheets Plant name: Indian Point Energy Center, Unit 3 Month Day Year Year of Biennial: 12 31 2016 Termination of Operation: 12 12 2015

!W!i ECI Base Lx Px Fx Bx PWR 3216 t$103,300,800t 128.7 2.16 0.65 I 2.78 I 1.883 1.854 0.13 1.87 0.22 12.471 NRC Minimum: $495,196,193 Site Specific:

Licensee:  % Owned: Amount of NRC MinimumlSite Specific: Amount in Trust Fund Entergy 100.00% $495,196,193 $719,098,560 Step 1:

Earnings Credit:

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

$719,098,560 2% 0.00 1.00000 $719,098,560 Total Earnings = Tru Fund balance x (1+RRR)AYears left in license Step 2:

Accumulation:

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

$0 2% 0 $0 Step 3:

Decom Period:

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

$719,098,560 2% 7 0.14869 $53,459,825 ITotal Earnings for Decom = (112) x Total Earnings x [(1+RRR)Decom period - 1J Total ofSteps 1 3:

$772,558,385 I Total Total Earnings + Total Earnings for Decom Excess(Shortfall) $ 277,362,192 to NRC minimum

$ (6,968,434) Less ISFSI

$ - Parent Co Guaranty

$ 270,393,758 Total Excess Financial Assurance

Attachment 16 CNRO-201 7-00009 (Page 4 of 7)

Entergy Nuclear Operations, Inc.

Minimum Financial Assurance Calculation Worksheets Plant name: Vermont Yankee Power Station Month Day Year YearofBiennial: 12 31 2016 TerminationofOperation: 12 29 2014

!Wi!:i I I ECI Base Lx Px Fx f x Bx BWR 1912 $121,2O8,OOOf 128.7 2.16 0.65 j 2.78 1.883 1.854 0.13 1.87 0.22 13132 I

NRC Minimum: $598,646,270 Site Specific: $728,090,722 Licensee:  % Owned: Amount of NRC Minimum/Site Specific: Amount in Trust Fund Entergy I 0000% $728,090,722 $561,614,638 Note: See Attachment 15 for adequacy ofthe trust fund.

Attachment 16 CNRO-201 7-00009 (Page 5 of 7)

Entergy Nuclear Operations, Inc.

Minimum Financial Assurance Calculation Worksheets Plant name: Pilgrim Nuclear Generating Station Month Day Year YearofBiennial: 12 31 2016 Termination ofOperation: 5 31 2019 w_p is Ed Base Lx Px Fx I I I I 2028 $122,252,OOO 128.7 2.16 0.65 2.78 1883 1.854 0.13 1.87 13.132 BWR [ 0.22 NRC Minimum: $603,802,586 Site Specific:

Licensee:  % Owned: Amount of NRC MinimumlSite Specific: Amount in Trust Fund:

Entergy 100.00% $603,302,586 $960,300,492 Step 1:

Earnings Credit:

Real Rate of Yeats Left Total Real Twst Fund Balance: Return pet in License Rate of Total Earnings:

$960,300,492 2% 2.42 1.04902 $1,007,374,376 Total Earnings Trust Fund balance x (1+RRR)Years left in license Step 2:

Accum ulation:

Value of Annuity pet Real Rate of yeat Retutn pet Yeats ofAnnuity: Total Annuity:

$0 2% 0 $0 Step 3:

Decom Period:

Real Rate of Decorn Total Real Total Eatnings: Retutn pet Petiod: Rate of Total Eatnings fot Decom:

$1,007,374,376 2% 7 0.14869 $74,891,066 Total Earnings for Decom (112) x Total Earnings x [(1+RRR)Decom period - 11 of Steps 1 3:

I Total I $1,082,265,442 Total Total Earnings + Total Earnings for Decom Excess (Shortfall) $ 478,462,856 to NRC minimum

$ (9,211,348) Less ISFSI

$ - Parent Co Guaranty

$ 469,251,508 Total Excess Financial Assurance

Attachment 16 CNRO-201 7-00009 (Page 6 of 7)

Entergy Nuclear Operations, Inc.

Minimum Financial Assurance Calculation Worksheets Plant name: James A. FitzPatrick Month Day Year YearofBiennial: 12 31 2016 Termination ofOperation: 10 17 2034

!WP Ed BaseLx Px Fx BWR 2536 $126,824OOO[ 128.7 2.16 065 I 2.78 I 1.883 1854 013 1.87 022 13.132

[ [

NRC Minimum: $626,383,692 Site Specific:

Licensee:  % Owned: Amount of NRC MinimumlSite Specific: Amount in Trust Fund:

Entergy 100.00% $626,383,692 $784,667,357 Step 1:

Earnings Credit:

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

$784,667,357 2% 17.79 1.42246 $1,116,157,408 Total Earnings = Trust Fund balance x (J+RRR)Years left in license Step 2:

Accumulation:

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

$0 2% 0 $0 Step 3:

Decom Period:

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

$1 ,1 16,157,408 2% 7 0.14869 $82,978,305 Total Earnings for Decom = (112) x Total Earnings x [(J+RRR)Decom period - 1]

Total ofSteps 1 -3:

$1,199,135,712 Total Total Earnings + Total Earnings for Decom Excess (Shortfall) $ 572,752,020 to NRC minimum

$ (8,383,155) Less ISFSI

$ - Parent Co Guaranty

$ 564,368,865 Total Excess Financial Assurance

Attachment 16 CNRO-201 7-00009 (Page 7 of 7)

Entergy Nuclear Operations, Inc.

Minimum Financial Assurance Calculation Worksheets Plant name: Palisades Nuclear Plant Month Day Year Year of Biennial: 2 28 2017 Termination of Operation: 9 30 2018

.Wi!i ECI BaseLx Lx Px Fx Bx PWR 2565 $97,572,000 I 125.7 2.08 0.65 I 2.61 1.883 1.854 0.13 1.87 0.22 12.471 t

NRC Minimum: $457,246,441 Site Specific:

Licensee:  % Owned: Amount of NRC MinimumlSite Specific: Amount in Trust Fund Entergy 1 00.00% $457,246,441 $425,730,230 Step 1:

Earnings Credit:

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

$425,730,230 2% 1.59 I .03196 $439,337,781 Total Earnings Trust Fund balance x (1+RRR)Years left in license Step 2:

Accumulation:

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

$0 2% 0 $0 Step 3:

Decom Period:

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

$439,337,781 2% 7 0.14869 $32,661,616 ITotal Earnings for Decom = (112) x Total Earnings x [(1+RRR)Decom period - 1]

TotalofSteps 1 -3:

$471,999,396 I Total Total Earnings -I- Total Earnings for Decom Excess (Shortfall) $ 14,752,956 to NRC minimum

$ (7,861,426) Less ISFSI

$ - Parent Co Guaranty

$ 6,$91,530 Total Excess Financial Assurance