View source for CNRO-2016-00010, Entergy Nuclear Operations, Inc. - Decommissioning Funding Status Report, Per 10 CFR 50.75(f)(1) and 10 CFR 50.82(a)(8)(v)

{{Adams
| number = ML16090A355
| issue date = 03/30/2016
| title = Entergy Nuclear Operations, Inc. - Decommissioning Funding Status Report, Per 10 CFR 50.75(f)(1) and 10 CFR 50.82(a)(8)(v)
| author name = Mccann J
| author affiliation = Entergy Nuclear Operations, Inc
| addressee name = 
| addressee affiliation = NRC/Document Control Desk, NRC/NMSS, NRC/NRR
| docket = 05000003, 05000155, 05000247, 05000271, 05000286, 05000293, 05000333
| license number = 
| contact person = 
| case reference number = CNRO-2016-00010
| document type = Decommissioning Funding Plan DKTs 30, 40, 50, 70, Letter type:CNRO
| page count = 33
}}

=Text=
{{#Wiki_filter:Entergy Nuclear Operations, Inc.
1340 Echelon Parkway Jackson, MS 39213 Tel: 601-368-5667 John F. McCann Vice President, Regulatory Assurance CNRO-2016-00010 March 30, 2016 U.S. Nuclear Regulatory Commission Attn: Document Control Desk 11555 Rockville Pike Rockville, MD 20852-2738

==SUBJECT:==
Decommissioning Funding Status Report per 10 CFR &sect;50.75(f)(1) and 10 CFR 50.82(a)(8)(v) -- Entergy Nuclear Operations, Inc.
Big Rock Point                              Indian Point Nuclear Docket No. 50-155                           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 Docket No. 50-271

==REFERENCES:==
: 1.          NUREG-1307, Report on Waste Burial Charges, Revision 15, dated January 2013.
: 2. NRC Regulatory Issue Summary 2001-07, 10 CFR 50.75(f)(1) Reports on the Status of Decommissioning Funds (Due March 31, 2001).
: 3. NRC Regulatory Issue Summary 2014-12, Decommissioning Fund Status Report Calculations.

==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 with certain exception, on the status of its decommissioning funding for each reactor, or share of a reactor, that it owns. 10 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 (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 1 through 11 for the seven licensed facilities addressed by this filing, were prepared in accordance with NUREG-1307 (Reference 1) and NRC Regulatory Issue Summary 2001-07 (Reference 2). Attachments

CNRO-2016-00010 Page 2 of 4 12 and 13 are updated site specific decommissioning cost estimates for Indian Point Unit 1 and Vermont Yankee, respectively. The Minimum Funding Assurance calculation worksheets, derived from LIC-205, Rev. 4, are provided in Attachment 14 for the convenience of the reviewer.
The estimated minimum decommissioning fund values were determined using the NRCs methodology in NUREG-1307, Rev 15. Pursuant to NRC Regulatory Issue Summary 2014-12, Entergy Nuclear Operations, Inc. understands that the NRC has directed licensees to use NUREG-1307, Rev. 15 for this filing.
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, 2015 net of any material current income tax liability on realized gains, interest, dividends and other income of the trusts. The New York Power Authority (NYPA) holds the decommissioning trust funds for Indian Point 3 and FitzPatrick. NYPA is a state agency, and the decommissioning trust funds held by NYPA are not subject to taxes. The trusts for the following plants had estimated balances on their 2015 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               $272 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 11 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, 2015 trust fund balances 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 Mr. Guy Davant, Manager, Fleet Licensing Programs at (601) 368-5756.
Sincerely, JFM / ghd / ljs

CNRO-2016-00010 Page 3 of 4 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
: 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
: 10. Entergy Nuclear Operations, Inc. Calculation of Minimum Amount - James A. Fitzpatrick
: 11. Entergy Nuclear Operations, Inc. Status of Decommissioning Funding - Big Rock Point
: 12. Entergy Nuclear Operations, Inc. IP1 DTF Balance Based on Decommissioning Funding Assurance Plan
: 13. Entergy Nuclear Operations, Inc. Vermont Yankee Annual Cash Flow Analysis
: 14. Entergy Nuclear Operations, Inc. Minimum Financial Assurance Calculation Worksheets cc: See next page

CNRO-2016-00010 Page 4 of 4 cc: Mr. J. A. Aluise (ENT)
Mr. C. Bakken (ECH)
Mr. B. E. Green (TMBR)
Mr. D. J. Mannai (WPO)
Mr. J. F. McCann (WPO)
Mr. T. G. Mitchell (ECH)
Mr. L. Jager Smith (ECH)
Mr. J. A. Ventosa (ECH)
Mr. M. Perito (ECH)
Mr. B. Sullivan (JAF)
Mr. J. Dent (PIL)
Mr. L. Coyle (IPEC)
Mr. A. J. Vitale (PAL)
Mr. C. J. Wamser (VTY)
USNRC Regional Administrator, Region I USNRC Regional Administrator, Region III USNRC Project Manager, Indian Point 1 USNRC Project Manager, Indian Point 2 / 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 / 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 1 CNRO-2016-00010 (Page 1 of 2)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Indian Point 1 For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1) and 10 CFR 50.82(a)(8)(v)
Plant Name: Indian Point Nuclear Generating Unit No. 1 10 CFR 50.75(f)(1)
: 1. Minimum Financial Assurance (MFA)                                       $556.76 million [Note1]
estimated per 10 CFR 50.75(b) and (c) (2015$)
                                                                           $0.64 million [Note2]
: 2. ISFSI Obligation as of 12/31/15
: 3. Decommissioning Trust Fund Total                                        $ 413.92 million as of 12/31/15
: 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 10        None CFR 50.75(e)(1)(v)
: 7. Modifications occurring to a licensee's current method of providing    None 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 that are provided in Attachment 12. (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 1 of March 2016

Attachment 1 CNRO-2016-00010 (Page 2 of 2)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Indian Point 1 For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1) and 10 CFR 50.82(a)(8)(v)
Plant Name: Indian Point Nuclear Generating Unit No. 1 10 CFR 50.82(a)(8)(v)
: 1. Cumulative decommissioning spending                                       $94.28 million [Note1]
: 2. 2015 decommissioning spending                                             $5.66 million [Note1]
: 3. Fund Balance                                                             See above in 10 CFR 50.75 information
: 4. No other financial assurance mechanism is being relied upon, but costs through 12/31/2015 have been funded by operations, and not the decommissioning fund.
: 5. Estimated costs to complete from latest estimate                         $556.76 million [Note2]
: 6. Estimate is based on unrestricted release of the 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: Entergy does not possess records that would permit determination of charges to IP1 prior to its acquisition in September 2001 by Entergy Nuclear Indian Point 2, LLC. The costs presented here represent those costs charged in 2015 and the total costs that have been assigned to IP1 since 2001. Entergy has not fully determined what portion of those costs would be considered decommissioning costs as that term is defined in 10 CFR 50.2. Cumulative and 2015 decommissioning spending only consists of costs related to license termination. In previous filings, cumulative and annual decommissioning costs have included costs related to spent fuel management operations.
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 12. (Calculation of the NRC Minimum Amount is provided in Attachment 4.) This estimate does not include 2015 spending because current costs are being paid out of operating funds.

Attachment 2 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Indian Point 2 For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Plant Name: Indian Point Nuclear Generating Unit No. 2
: 1. Minimum Financial Assurance (MFA)                                       $521.34 million [Note 1]
estimated per 10 CFR 50.75(b) and (c) (2015$)
: 2. ISFSI Obligation as of 12/31/15                                         $6.16 million [Note 2]
: 3. Decommissioning Trust Fund Total as of 12/31/15                                                          $529.05 million [Note 3]
: 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 10        None CFR 50.75(e)(1)(v)
: 7. Modifications occurring to a licensee's 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 10 CFR 50.82(a)(8)(vii) filing for Indian Point 2 of March 2016 Note 3: Includes provisional fund balance of $32.14 million.

Attachment 3 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Indian Point 3 For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Plant Name: Indian Point Nuclear Generating Unit No. 3
: 1. Minimum Financial Assurance (MFA)                                    $521.34 million [Note 1]
estimated per 10 CFR 50.75(b) and (c) (2015$)
: 2. ISFSI Obligation as of 12/31/15                                      $6.79 million [Note 2]
: 3. Decommissioning Trust Fund Total                                     $ 683.84 million as of 12/31/15
: 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 10     None CFR 50.75(e)(1)(v)
: 7. Modifications occurring to a licensee's 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 pursuant to 10 CFR 72.30, December 17, 2015 (Accession No. ML15351A524)

Attachment 4 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Calculation of Minimum Amount - Indian Point For Year Ending December 31, 2015 - 10 CFR 50.75(f)(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 1 Power Level: <3,400 MWt (615 MWt)
Indian Point Unit 1 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 10CFR50.75(c)(2) Escalation Factor Formula:
0.65(L) +0.13(E) +0.22(B)
Factor L=Labor (North)                                    2.711 E=Energy (PWR)                                     1.762 B=Waste Burial-Vendor (PWR)                        13.8853 PWR Escalation Factor:
0.65(L) +0.13(E) +0.22(B)=                         5.04684 1986 PWR Base Year $ Escalated:
Indian Point 1: $85,560,000
* Factor=              $431,807,460 Indian Point 2 & 3: $103,300,800
* Factor=         $521,342,404 1                                                                     th Bureau of Labor Statistics, Series Report ID: CIU2010000000210i (4 Quarter 2015) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2015) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 15, Table 2.1 (2013)

Attachment 5 CNRO-2016-00010 (Page 1 of 2)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding Vermont Yankee For Year Ending December 31, 2015 - 10 CFR 50.75(f)(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)                                        $ 740.52 million [Note 1]
estimated per 10 CFR 50.75(b) and (c) (2015$)
: 2. ISFSI Obligation as of 12/31/15                                          $5.05 million [Note 2]
: 3. Decommissioning Trust Fund Total                                         $ 595.44 million as of 12/31/15
: 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 10         None CFR 50.75(e)(1)(v)
: 7. Modifications occurring to a licensee's 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 13. (Calculation of the NRC Minimum Amount is provided in Attachment 6).
Note 2: From Entergys ISFSI Decommissioning Funding Plans Pursuant to 10 CFR 72.30, December 17, 2015 (Accession No. ML15351A524).
Note 3: Since the last submitted report, Entergy Nuclear Vermont Yankee, LLC canceled a $40 million parent guarantee that previously provided decommissioning financial assurance for Vermont Yankee, based on the establishment of certain lines of credit. In a letter from the NRC to Entergy Nuclear Operations, Inc., and Vermont Yankee Nuclear Power Station dated April 21, 2015, the NRC determined that Entergy Corporation had complied with the general requirements of 10 CFR 30 Appendix A (III)(A) and granted Entergy Corporation the right to cancel the $40 million parent company guarantee for Vermont Yankee (Accession No. ML15107A074).

Attachment 5 CNRO-2016-00010 (Page 2 of 2)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding Vermont Yankee For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1) 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 12/31/2015                   $ 74.35 million [Note1]
: 2. 2015 decommissioning spending                                           $ 59.57 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                        $ 740.52 million
: 6. Estimate is based on unrestricted release of the 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 2015 decommissioning costs. 2014 costs are included in item 1 and have been reimbursed in 2015.

Attachment 6 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Calculation of Minimum Amount - Vermont Yankee For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Entergy Nuclear Vermont Yankee LLC.: 100% 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 10CFR50.75(c)(2) Escalation Factor Formula:
0.65(L) +0.13(E) +0.22(B)
Factor L=Labor (North)                             2.711 E=Energy (BWR)                              1.752 B=Waste Burial-Vendor (BWR)                 14.1603 BWR Escalation Factor:
0.65(L) +0.13(E) +0.22(B)=                  5.10582 1986 BWR Base Year $ Escalated:
    $121,208,000
* Factor=                      $618,866,471 1                                                                     th Bureau of Labor Statistics, Series Report ID: CIU2010000000210i (4 Quarter 2015) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2015) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 15, Table 2.1 (2013)

Attachment 7 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Pilgrim For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Plant Name: Pilgrim Nuclear Power Station
: 1. Minimum Financial Assurance (MFA)                                $ 624.20 million [Note 1]
estimated per 10 CFR 50.75(b) and (c) (2015$)
                                                                     $8.98 million [Note 2]
: 2. ISFSI Obligation as of 12/31/15
: 3. Decommissioning Trust Fund Total                                 $ 895.71 million as of 12/31/15
: 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 10  None CFR 50.75(e)(1)(v)
: 7. Modifications occurring to a licensee's 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 Pursuant to 10 CFR 72.30, December 17, 2015 (Accession No. ML15351A524).

Attachment 8 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Calculation of Minimum Amount - Pilgrim For Year Ending December 31, 2015 - 10 CFR 50.75(f)(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 10CFR50.75(c)(2) Escalation Factor Formula:
0.65(L) +0.13(E) +0.22(B)
Factor L=Labor (North)                             2.711 E=Energy (BWR)                              1.752 B=Waste Burial-Vendor (BWR)                 14.1603 BWR Escalation Factor:
0.65(L) +0.13(E) +0.22(B)=                  5.10582 1986 BWR Base Year $ Escalated:
    $122,252,000
* Factor=                      $624,196,949 1                                                                     th Bureau of Labor Statistics, Series Report ID: CIU2010000000210i (4 Quarter 2015) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2015) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 15, Table 2.1 (2013)

Attachment 9 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - James A. Fitzpatrick For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Plant Name: James A. Fitzpatrick Nuclear Power Plant
: 1. Minimum Financial Assurance (MFA)                               $ 647.54 million [Note 1]
estimated per 10 CFR 50.75(b) and (c) (2015$)
                                                                    $ 8.17 million [Note 2]
: 2. ISFSI Obligation as of 12/31/15
: 3. Decommissioning Trust Fund Total                                $ 746.19 million as of 12/31/15
: 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 licensee's 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 10.
Note 2: From Entergys ISFSI Decommissioning Funding Plans Pursuant to 10 CFR 72.30, December 17, 2015 (Accession No. ML15351A524).

Attachment 10 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Calculation of Minimum Amount - James A. Fitzpatrick For Year Ending December 31, 2015 - 10 CFR 50.75(f)(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 1986$: $126,824,000 Labor Region: North 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 (North)                             2.711 E=Energy (BWR)                              1.752 B=Waste Burial-Vendor (BWR)                 14.1603 BWR Escalation Factor:
0.65(L) +0.13(E) +0.22(B)=                  5.10582 1986 BWR Base Year $ Escalated:
    $126,824,000
* Factor=                      $647,540,768 1                                                                     th Bureau of Labor Statistics, Series Report ID: CIU2010000000210i (4 Quarter 2015) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2015) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 15, Table 2.1 (2013)

Attachment 11 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Big Rock Point For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Plant Name: Big Rock Point ISFSl
: 1. Amount of decommissioning funds required from           $ 2.43 million [Note 1]
most recent estimate (2015 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 licensee's current         None method of providing financial assurance since the last submitted report
: 7. Any material changes to trust agreements                None Note 1: See 10 CFR &sect;72.30 filing for Big Rock Point, dated December 17, 2015, Accession No. ML15351A524.

Attachment 12 CNRO-2016-00010 (Page 1 of 4)
Entergy Nuclear Operations, Inc.
IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
On October 23, 2008, Entergy Nuclear Indian Point 2, LLC (ENIP2) submitted a preliminary decommissioning cost analysis to the NRC in conjunction with its spent fuel management plan under 10 CFR 50.75(f)(3) and 10 CFR 50.54(bb) (Accession No. ML083040378, as supplemented by ENIP2's reply to RAIs on July 15, 2009 (Accession No. ML092050204). The preliminary decommissioning cost analysis contained separate site-specific decommissioning cost estimates for Indian Point 1 and Indian Point 2. The estimates were subsequently found to be reasonable by the NRC on March 17, 2010 (Accession No. ML100280544).
Pursuant to Regulatory Guide 1.159, Revision 2, adjustment to the site-specific cost estimates 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 process in compliance with NRC decommissioning funding assurance rules.
Pursuant to 10 CFR 50.75(e)(1)(i), "A licensee that has prepaid funds based on a site-specific estimate under &sect; 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." 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 decommissioning costs as defined in 10 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 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 1 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 12-1 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 balance is escalated each year by the 2% real growth figure allowed pursuant to 10 CFR 50.75(e)(1)(i).

Attachment 12 CNRO-2016-00010 (Page 2 of 4)
Entergy Nuclear Operations, Inc.
IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Table 12-1 NRC License Termination Cost
($ millions) 2015 $ Unit 1    Ending DTF Radiological       Balance 2015                          413.921 2016            0.951         421.248 2017            3.804         425.869 2018            3.804         430.582 2019            3.815         435.379 2020            3.804         440.282 2021            3.804         445.283 2022            3.804         450.385 2023            3.815         455.578 2024            3.804         460.885 2025            3.804         466.298 2026            3.804         471.820 2027            3.815         477.442 2028            3.804         483.186 2029            3.804         489.045 2030            3.804         495.022 2031            3.815         501.108 2032            3.804         507.326 2033            3.804         513.668 2034            3.804         520.137 2035            3.815         526.725 2036            3.804         533.455 2037            3.804         540.320 2038            3.804         547.322 2039            3.815         554.453 2040            3.804         561.738 2041            3.804         569.169 2042            3.804         576.748 2043            3.815         584.468 2044            3.804         592.353 2045            3.804         600.396 2046            3.804         608.599 2047            3.815         616.957 2048            3.804         625.491 2049            3.804         634.197 2050            3.804         643.076 2051            3.815         652.123

Attachment 12 CNRO-2016-00010 (Page 3 of 4)
Entergy Nuclear Operations, Inc.
IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Table 12-1 NRC License Termination Cost
($ millions) 2015 $ Unit 1    Ending DTF Radiological       Balance 2052            3.804         661.361 2053            3.804         670.784 2054            3.804         680.396 2055            3.815         690.189 2056            3.804         700.188 2057            3.804         710.388 2058            3.804         720.791 2059            3.815         731.392 2060            3.815         742.205 2061            3.804         753.245 2062            3.804         764.506 2063            3.804         775.992 2064            3.815         787.697 2065           28.011         775.440 2066           61.646         729.303 2067         102.982          640.907 2068         109.450          544.275 2069           15.770         539.390 2070           15.792         534.386 2071           15.792         529.282 2072           15.835         524.033 2073            7.788         526.726 Total          556.759

Attachment 12 CNRO-2016-00010 (Page 4 of 4)
Entergy Nuclear Operations, Inc.
IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
As can be seen from the information provided in Table 12-1, the required funding for SAFSTOR decommissioning, $556.76 million, is greater than the NRC formula amount per 10 CFR 50.75(b) and (c) of $431.81 million, therefore, the site-specific analysis complies with the requirement from Regulatory Guide 1.159 section 1.1.1 previously discussed. The foregoing SAFSTOR analysis shows that when the December 31, 2015 DTF balance is escalated at the allowable rate and compared against the annual figures for the SAFSTOR period, that an approximately $526.73 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 1.

Attachment 13 CNRO-2016-00010 (Page 1 of 6)
Entergy Nuclear Operations, Inc.
Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2015 - 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 $595 million as of December 31, 2015. Tables 3.4 and 3.5 of the site-specific decommissioning cost estimate (Reference 1, Attachment 1) 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 13-1.
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 $223 million) 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).
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 10 CFR 50.75(e)(1)(i), "A licensee that has prepaid funds based on a site-specific estimate under &sect; 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 10 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 for justifying 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 2068, at which time the plant will be decommissioned and the site released for alternative use without restriction. Table 13-1 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 pursuant to 10 CFR 50.75(e)(1)(i).

Attachment 13 CNRO-2016-00010 (Page 2 of 6)
Entergy Nuclear Operations, Inc.
Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Thus, considering the fund balance of $595 million, as of December 31, 2015, and projected fund earnings during the SAFSTOR period (assuming an annual 2% growth rate), the trust fund is expected to have an excess of $190.6 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, BVY 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 13-1 Vermont Yankee Nuclear Power Station - SAFSTOR Methodology Annual Cash Flow Analysis - Total License Termination, Spent Fuel Management less Dry Fuel Costs (In Thousands in 2015 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                        ($000s) Fund
($000s)      ($000s)         Cost             Management      ($000s)                                Balance
($000s)         Cost less                                               ($000s)
Dry Fuel Cost
($000s) 2016       48,305        75,778           53,820           70,263         595,443    70,263              10,504  535,683 2017       11,007        49,345           29,882           30,471         535,683    30,471              10,104  515,317 2018       9,704         41,277           19,752           31,229         515,317    31,229              9,682   493,769 2019       8,299         36,929           17,022           28,205         493,769    28,205              9,311   474,875 2020       17,779        27,680           17,625           27,834         474,875    27,834              8,941   455,982 2021       5,303          4,055                             9,358         455,982    9,358               8,932   455,557 2022       5,251          4,055                             9,307         455,557    9,307               8,925   455,176 2023       5,251          4,055                             9,307         455,176    9,307               8,917   454,786 2024       3,676          4,066                             7,742         454,786    7,742               8,941   455,985 2025       3,616          4,055                             7,671         455,985    7,671               8,966   457,280 2026       3,761          4,055                             7,816         457,280    7,816               8,989   458,453 2027       3,812          4,055                             7,867         458,453    7,867               9,012   459,597

Attachment 13 CNRO-2016-00010 (Page 3 of 6)
Entergy Nuclear Operations, Inc.
Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Table 13-1 Vermont Yankee Nuclear Power Station - SAFSTOR Methodology Annual Cash Flow Analysis - Total License Termination, Spent Fuel Management less Dry Fuel Costs (In Thousands in 2015 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                        ($000s) Fund
($000s)      ($000s)         Cost             Management      ($000s)                                Balance
($000s)         Cost less                                               ($000s)
Dry Fuel Cost
($000s) 2028       3,770          4,066                             7,836         459,597    7,836               9,035   460,796 2029       3,761          4,055                             7,816         460,796    7,816               9,060   462,040 2030       3,812          4,055                             7,867         462,040    7,867               9,083   463,256 2031       3,761          4,055                             7,816         463,256    7,816               9,109   464,548 2032       3,770          4,066                             7,836         464,548    7,836               9,134   465,846 2033       3,812          4,055                             7,867         465,846    7,867               9,160   467,139 2034       3,761          4,055                             7,816         467,139    7,816               9,186   468,509 2035       3,761          4,055                             7,816         468,509    7,816               9,214   469,906 2036       3,821          4,066                             7,887         469,906    7,887               9,240   471,259 2037       3,761          4,055                             7,816         471,259    7,816               9,269   472,712 2038       3,761          4,055                             7,816         472,712    7,816               9,298   474,194 2039       3,812          4,055                             7,867         474,194    7,867               9,327   475,653 2040       3,770          4,066                             7,836         475,653    7,836               9,356   477,173 2041       3,761          4,055                             7,816         477,173    7,816               9,387   478,744 2042       3,812          4,055                             7,867         478,744    7,867               9,418   480,294 2043       3,761          4,055                             7,816         480,294    7,816               9,450   481,927 2044       3,770          4,066                             7,836         481,927    7,836               9,482   483,573 2045       3,812          4,055                             7,867         483,573    7,867               9,514   485,220 2046       3,761          4,055                             7,816         485,220    7,816               9,548   486,952 2047       3,761          4,055                             7,816         486,952    7,816               9,583   488,718 2048       3,821          4,066                             7,887         488,718    7,887               9,617   490,447 2049       3,761          4,055                             7,816         490,447    7,816               9,653   492,284 2050       3,761          4,055                             7,816         492,284    7,816               9,689   494,157 2051       3,812          4,055                             7,867         494,157    7,867               9,726   496,015 2052       3,770          4,066                             7,836         496,015    7,836               9,764   497,942 2053       3,608                                            3,608         497,942    3,608               9,887   504,221 2054       3,659                                            3,659         504,221    3,659               10,011  510,574 2055       3,608                                            3,608         510,574    3,608               10,139  517,105

Attachment 13 CNRO-2016-00010 (Page 4 of 6)
Entergy Nuclear Operations, Inc.
Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Table 13-1 Vermont Yankee Nuclear Power Station - SAFSTOR Methodology Annual Cash Flow Analysis - Total License Termination, Spent Fuel Management less Dry Fuel Costs (In Thousands in 2015 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                        ($000s) Fund
($000s)      ($000s)         Cost             Management      ($000s)                                Balance
($000s)         Cost less                                               ($000s)
Dry Fuel Cost
($000s) 2056       3,617                                            3,617         517,105    3,617               10,270  523,758 2057       3,659                                            3,659         523,758    3,659               10,402  530,502 2058       3,608                                            3,608         530,502    3,608               10,538  537,432 2059       3,608                                            3,608         537,432    3,608               10,676  544,500 2060       3,668                                            3,668         544,500    3,668               10,817  551,649 2061       3,608                                            3,608         551,649    3,608               10,961  559,002 2062       3,608                                            3,608         559,002    3,608               11,108  566,502 2063       3,659                                            3,659         566,502    3,659               11,257  574,100 2064       3,617                                            3,617         574,100    3,617               11,410  581,894 2065       3,608                                            3,608         581,894    3,608               11,566  589,851 2066       3,659                                            3,659         589,851    3,659               11,724  597,916 2067       3,608                                            3,608         597,916    3,608               11,886  606,195 2068       43,690                                          43,690         606,195    43,690              11,250  573,755 2069       93,039                                          93,039         573,755    93,039              9,614   490,331 2070      105,681                                          105,681        490,331   105,681              7,693   392,343 2071       85,618                                          85,618         392,343    85,618              6,134   312,859 2072       86,055                                          86,055         312,859    86,055              4,536   231,341 2073       50,949                                          50,949         231,341    50,949              3,608   184,000 2074        523                                              523          184,000     523                3,670   187,147 2075        302                                              302          187,147     302                3,737   190,582 740,517        360,863          138,101          963,280        595,443   963,280             558,418  190,582 As can be seen from the information provided in Table 13-1, the required funding for SAFSTOR decommissioning, $740.52 million, is greater than the NRC formula amount per 10 CFR 50.75(b) and (c) of $618.87 million, therefore, the site-specific analysis complies with the requirement from Regulatory Guide 1.159 section 1.1.1 previously discussed. The foregoing SAFSTOR analysis shows that when the December 31, 2015 DTF balance is escalated at the

Attachment 13 CNRO-2016-00010 (Page 5 of 6)
Entergy Nuclear Operations, Inc.
Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1) allowable rate and compared against the annual figures for the SAFSTOR period, that an approximately $190.6 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 13-1 Definitions:
Column 1:      50.75 License Termination Cost Reflects the Total Annual License Termination Plan cost in 2015 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 2015 dollars at a 0.0% escalation rate Column 3:      Exclude Transfer to Dry 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 2015 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 2015 dollars at a 0.0% escalation rate (Column 1 + Column 2 - Column 3)
Column 5:      Beginning of Year Trust Fund Balance Reflects the beginning of year Trust Fund balance in 2015 dollars at a 0.0%
escalation rate and 2.0% Fund Earnings

Attachment 13 CNRO-2016-00010 (Page 6 of 6)
Entergy Nuclear Operations, Inc.
Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Column 6: Withdraw Reflects the annual expenditures from the Trust Fund in 2015 dollars at a 0.0%
escalation rate (equals Column 4)
Column 7: Contribute Reflects the annual contributions to the Trust Fund in 2015 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 100% 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 2015 dollars. (Column 5 - Column 6 +
Column 7 + Column 8)

Attachment 14 CNRO-2016-00010 (Page 1 of 6)
Entergy Nuclear Operations, Inc.
Minimum Financial Assurance Calculation Worksheets Plant name:                                             Indian Point Energy Center, Unit 1 Month                      Day                         Year Year of Biennial:               12                         31                        2015 Termination of Operation:            9                          28                        2013 MWth    1986$     ECI     Base Lx                           Lx         Px          Fx         Ex         Bx PWR         615 $85,560,000 125.6       2.16             0.65         2.71      1.882        1.590 0.13 1.76 0.22 13.885 NRC Minimum:                      $431,807,460                   Site Specific: $556,759,099 Licensee:     % Owned:    Amount of NRC Minimum/Site Specific:   Amount in Trust Fund:
Entergy       100.00%                 $556,759,099                   $413,920,819 Note: See Attachment 12 for adequacy of the trust fund.

Attachment 14 CNRO-2016-00010 (Page 2 of 6)
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                                  2015 Termination of Operation:                     12                           12                                  2015 MWth      1986$        ECI        Base Lx                                 Lx           Px                 Fx                    Ex                     Bx PWR           3216  $103,300,800   125.6         2.16               0.65              2.71        1.882               1.590       0.13      1.76      0.22        13.885 NRC Minimum:                              $521,342,404                         Site Specific:
Licensee:        % Owned:       Amount of NRC Minimum/Site Specific:           Amount in Trust Fund:
Entergy          100.00%                      $521,342,404                          $683,835,864 Step 1:
Earnings Credit:
Real Rate of Years Left   Total Real Trust Fund Balance:   Return per in License     Rate of             Total Earnings:
     $683,835,864          2%         0.00       1.00000              $683,835,864             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 Step 3:
Decom Period:
Real Rate of  Decom       Total Real Total Earnings:    Return per   Period:      Rate of       Total Earnings for Decom:
     $683,835,864          2%           7        0.14869               $50,838,296             Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]
Total of Steps 1 - 3:
                                                                      $734,674,160             Total = Total Earnings + Total Earnings for Decom Excess (Shortfall)        $                  213,331,756    to NRC minimum
                                                             $                    (6,790,496)   Less ISFSI
                                                             $                            -     Parent Co Guaranty
                                                             $                  206,541,261     Total Excess Financial Assurance

Attachment 14 CNRO-2016-00010 (Page 3 of 6)
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                                 2015 Termination of Operation:                     9                            28                                 2013 MWth      1986$        ECI        Base Lx                                 Lx          Px                  Fx                   Ex                  Bx PWR           3216  $103,300,800   125.6         2.16               0.65              2.71       1.882               1.590       0.13      1.76      0.22     13.885 NRC Minimum:                              $521,342,404                         Site Specific:
Licensee:        % Owned:       Amount of NRC Minimum/Site Specific:           Amount in Trust Fund:
Entergy          100.00%                      $521,342,404                          $529,053,777 Step 1:
Earnings Credit:
Real Rate of Years Left   Total Real Trust Fund Balance:   Return per in License     Rate of             Total Earnings:
     $529,053,777          2%         0.00       1.00000              $529,053,777            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 Step 3:
Decom Period:
Real Rate of  Decom       Total Real Total Earnings:    Return per   Period:      Rate of       Total Earnings for Decom:
     $529,053,777          2%           7        0.14869               $39,331,357            Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]
Total of Steps 1 - 3:
                                                                      $568,385,134            Total = Total Earnings + Total Earnings for Decom Excess (Shortfall)        $                   47,042,730    to NRC minimum
                                                             $                    (6,152,189)  Less ISFSI
                                                             $                            -    Parent Co Guaranty
                                                             $                   40,890,541    Total Excess Financial Assurance

Attachment 14 CNRO-2016-00010 (Page 4 of 6)
Entergy Nuclear Operations, Inc.
Minimum Financial Assurance Calculation Worksheets Plant name:                                                Vermont Yankee Power Station Month                      Day                        Year Year of Biennial:                12                          31                       2015 Termination of Operation:             12                          29                       2014 MWth     1986$      ECI     Base Lx                          Lx         Px          Fx            Ex        Bx BWR        1912 $121,208,000 125.6       2.16             0.65        2.71      1.882        1.590    0.13 1.75 0.22 14.16 NRC Minimum:                        $618,866,471                  Site Specific:        $740,517,165 Licensee:      % Owned:     Amount of NRC Minimum/Site Specific:  Amount in Trust Fund:
Entergy        100.00%                  $740,517,165                  $595,443,076 Note: See Attachment 13 for adequacy of the trust fund.

Attachment 14 CNRO-2016-00010 (Page 5 of 6)
Entergy Nuclear Operations, Inc.
Minimum Financial Assurance Calculation Worksheets Plant name:                                                      Pilgrim Nuclear Generating Station Month                           Day                                 Year Year of Biennial:                       12                           31                                 2015 Termination of Operation:                     5                            31                                 2019 MWth      1986$        ECI        Base Lx                                 Lx          Px                  Fx                   Ex                  Bx BWR           2028  $122,252,000   125.6         2.16               0.65              2.71       1.882               1.590       0.13      1.75      0.22     14.16 NRC Minimum:                              $624,196,949                         Site Specific:
Licensee:        % Owned:       Amount of NRC Minimum/Site Specific:           Amount in Trust Fund:
Entergy          100.00%                      $624,196,949                          $895,714,834 Step 1:
Earnings Credit:
Real Rate of Years Left   Total Real Trust Fund Balance:   Return per in License     Rate of             Total Earnings:
     $895,714,834          2%         3.42       1.07000              $958,415,187            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 Step 3:
Decom Period:
Real Rate of  Decom       Total Real Total Earnings:    Return per   Period:      Rate of       Total Earnings for Decom:
     $958,415,187          2%           7        0.14869               $71,251,301            Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]
Total of Steps 1 - 3:
                                                                     $1,029,666,488           Total = Total Earnings + Total Earnings for Decom Excess (Shortfall)        $                  405,469,538    to NRC minimum
                                                             $                    (8,975,100)  Less ISFSI
                                                             $                            -    Parent Co Guaranty
                                                             $                  396,494,438    Total Excess Financial Assurance

Attachment 14 CNRO-2016-00010 (Page 6 of 6)
Entergy Nuclear Operations, Inc.
Minimum Financial Assurance Calculation Worksheets Plant name:                                                                   James A. FitzPatrick Month                          Day                                  Year Year of Biennial:                       12                           31                                 2015 Termination of Operation:                     1                            27                                 2017 MWth      1986$        ECI        Base Lx                                 Lx          Px                  Fx                   Ex                  Bx BWR           2536  $126,824,000   125.6         2.16               0.65              2.71       1.882               1.590       0.13      1.75      0.22     14.16 NRC Minimum:                              $647,540,768                         Site Specific:
Licensee:        % Owned:       Amount of NRC Minimum/Site Specific:           Amount in Trust Fund:
Entergy          100.00%                      $647,540,768                          $746,189,340 Step 1:
Earnings Credit:
Real Rate of Years Left   Total Real Trust Fund Balance:   Return per in License     Rate of             Total Earnings:
     $746,189,340          2%         1.07       1.02146              $762,204,739            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 Step 3:
Decom Period:
Real Rate of  Decom       Total Real Total Earnings:    Return per   Period:      Rate of       Total Earnings for Decom:
     $762,204,739          2%           7        0.14869               $56,664,460            Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]
Total of Steps 1 - 3:
                                                                      $818,869,200            Total = Total Earnings + Total Earnings for Decom Excess (Shortfall)        $                  171,328,432    to NRC minimum
                                                             $                    (8,171,509)  Less ISFSI
                                                             $                            -    Parent Co Guaranty
                                                             $                  163,156,923    Total Excess Financial Assurance

Entergy Nuclear Operations, Inc.
1340 Echelon Parkway Jackson, MS 39213 Tel: 601-368-5667 John F. McCann Vice President, Regulatory Assurance CNRO-2016-00010 March 30, 2016 U.S. Nuclear Regulatory Commission Attn: Document Control Desk 11555 Rockville Pike Rockville, MD 20852-2738

==SUBJECT:==
Decommissioning Funding Status Report per 10 CFR &sect;50.75(f)(1) and 10 CFR 50.82(a)(8)(v) -- Entergy Nuclear Operations, Inc.
Big Rock Point                              Indian Point Nuclear Docket No. 50-155                           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 Docket No. 50-271

==REFERENCES:==
: 1.          NUREG-1307, Report on Waste Burial Charges, Revision 15, dated January 2013.
: 2. NRC Regulatory Issue Summary 2001-07, 10 CFR 50.75(f)(1) Reports on the Status of Decommissioning Funds (Due March 31, 2001).
: 3. NRC Regulatory Issue Summary 2014-12, Decommissioning Fund Status Report Calculations.

==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 with certain exception, on the status of its decommissioning funding for each reactor, or share of a reactor, that it owns. 10 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 (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 1 through 11 for the seven licensed facilities addressed by this filing, were prepared in accordance with NUREG-1307 (Reference 1) and NRC Regulatory Issue Summary 2001-07 (Reference 2). Attachments

CNRO-2016-00010 Page 2 of 4 12 and 13 are updated site specific decommissioning cost estimates for Indian Point Unit 1 and Vermont Yankee, respectively. The Minimum Funding Assurance calculation worksheets, derived from LIC-205, Rev. 4, are provided in Attachment 14 for the convenience of the reviewer.
The estimated minimum decommissioning fund values were determined using the NRCs methodology in NUREG-1307, Rev 15. Pursuant to NRC Regulatory Issue Summary 2014-12, Entergy Nuclear Operations, Inc. understands that the NRC has directed licensees to use NUREG-1307, Rev. 15 for this filing.
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, 2015 net of any material current income tax liability on realized gains, interest, dividends and other income of the trusts. The New York Power Authority (NYPA) holds the decommissioning trust funds for Indian Point 3 and FitzPatrick. NYPA is a state agency, and the decommissioning trust funds held by NYPA are not subject to taxes. The trusts for the following plants had estimated balances on their 2015 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               $272 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 11 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, 2015 trust fund balances 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 Mr. Guy Davant, Manager, Fleet Licensing Programs at (601) 368-5756.
Sincerely, JFM / ghd / ljs

CNRO-2016-00010 Page 3 of 4 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
: 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
: 10. Entergy Nuclear Operations, Inc. Calculation of Minimum Amount - James A. Fitzpatrick
: 11. Entergy Nuclear Operations, Inc. Status of Decommissioning Funding - Big Rock Point
: 12. Entergy Nuclear Operations, Inc. IP1 DTF Balance Based on Decommissioning Funding Assurance Plan
: 13. Entergy Nuclear Operations, Inc. Vermont Yankee Annual Cash Flow Analysis
: 14. Entergy Nuclear Operations, Inc. Minimum Financial Assurance Calculation Worksheets cc: See next page

CNRO-2016-00010 Page 4 of 4 cc: Mr. J. A. Aluise (ENT)
Mr. C. Bakken (ECH)
Mr. B. E. Green (TMBR)
Mr. D. J. Mannai (WPO)
Mr. J. F. McCann (WPO)
Mr. T. G. Mitchell (ECH)
Mr. L. Jager Smith (ECH)
Mr. J. A. Ventosa (ECH)
Mr. M. Perito (ECH)
Mr. B. Sullivan (JAF)
Mr. J. Dent (PIL)
Mr. L. Coyle (IPEC)
Mr. A. J. Vitale (PAL)
Mr. C. J. Wamser (VTY)
USNRC Regional Administrator, Region I USNRC Regional Administrator, Region III USNRC Project Manager, Indian Point 1 USNRC Project Manager, Indian Point 2 / 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 / 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 1 CNRO-2016-00010 (Page 1 of 2)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Indian Point 1 For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1) and 10 CFR 50.82(a)(8)(v)
Plant Name: Indian Point Nuclear Generating Unit No. 1 10 CFR 50.75(f)(1)
: 1. Minimum Financial Assurance (MFA)                                       $556.76 million [Note1]
estimated per 10 CFR 50.75(b) and (c) (2015$)
                                                                           $0.64 million [Note2]
: 2. ISFSI Obligation as of 12/31/15
: 3. Decommissioning Trust Fund Total                                        $ 413.92 million as of 12/31/15
: 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 10        None CFR 50.75(e)(1)(v)
: 7. Modifications occurring to a licensee's current method of providing    None 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 that are provided in Attachment 12. (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 1 of March 2016

Attachment 1 CNRO-2016-00010 (Page 2 of 2)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Indian Point 1 For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1) and 10 CFR 50.82(a)(8)(v)
Plant Name: Indian Point Nuclear Generating Unit No. 1 10 CFR 50.82(a)(8)(v)
: 1. Cumulative decommissioning spending                                       $94.28 million [Note1]
: 2. 2015 decommissioning spending                                             $5.66 million [Note1]
: 3. Fund Balance                                                             See above in 10 CFR 50.75 information
: 4. No other financial assurance mechanism is being relied upon, but costs through 12/31/2015 have been funded by operations, and not the decommissioning fund.
: 5. Estimated costs to complete from latest estimate                         $556.76 million [Note2]
: 6. Estimate is based on unrestricted release of the 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: Entergy does not possess records that would permit determination of charges to IP1 prior to its acquisition in September 2001 by Entergy Nuclear Indian Point 2, LLC. The costs presented here represent those costs charged in 2015 and the total costs that have been assigned to IP1 since 2001. Entergy has not fully determined what portion of those costs would be considered decommissioning costs as that term is defined in 10 CFR 50.2. Cumulative and 2015 decommissioning spending only consists of costs related to license termination. In previous filings, cumulative and annual decommissioning costs have included costs related to spent fuel management operations.
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 12. (Calculation of the NRC Minimum Amount is provided in Attachment 4.) This estimate does not include 2015 spending because current costs are being paid out of operating funds.

Attachment 2 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Indian Point 2 For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Plant Name: Indian Point Nuclear Generating Unit No. 2
: 1. Minimum Financial Assurance (MFA)                                       $521.34 million [Note 1]
estimated per 10 CFR 50.75(b) and (c) (2015$)
: 2. ISFSI Obligation as of 12/31/15                                         $6.16 million [Note 2]
: 3. Decommissioning Trust Fund Total as of 12/31/15                                                          $529.05 million [Note 3]
: 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 10        None CFR 50.75(e)(1)(v)
: 7. Modifications occurring to a licensee's 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 10 CFR 50.82(a)(8)(vii) filing for Indian Point 2 of March 2016 Note 3: Includes provisional fund balance of $32.14 million.

Attachment 3 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Indian Point 3 For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Plant Name: Indian Point Nuclear Generating Unit No. 3
: 1. Minimum Financial Assurance (MFA)                                    $521.34 million [Note 1]
estimated per 10 CFR 50.75(b) and (c) (2015$)
: 2. ISFSI Obligation as of 12/31/15                                      $6.79 million [Note 2]
: 3. Decommissioning Trust Fund Total                                     $ 683.84 million as of 12/31/15
: 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 10     None CFR 50.75(e)(1)(v)
: 7. Modifications occurring to a licensee's 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 pursuant to 10 CFR 72.30, December 17, 2015 (Accession No. ML15351A524)

Attachment 4 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Calculation of Minimum Amount - Indian Point For Year Ending December 31, 2015 - 10 CFR 50.75(f)(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 1 Power Level: <3,400 MWt (615 MWt)
Indian Point Unit 1 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 10CFR50.75(c)(2) Escalation Factor Formula:
0.65(L) +0.13(E) +0.22(B)
Factor L=Labor (North)                                    2.711 E=Energy (PWR)                                     1.762 B=Waste Burial-Vendor (PWR)                        13.8853 PWR Escalation Factor:
0.65(L) +0.13(E) +0.22(B)=                         5.04684 1986 PWR Base Year $ Escalated:
Indian Point 1: $85,560,000
* Factor=              $431,807,460 Indian Point 2 & 3: $103,300,800
* Factor=         $521,342,404 1                                                                     th Bureau of Labor Statistics, Series Report ID: CIU2010000000210i (4 Quarter 2015) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2015) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 15, Table 2.1 (2013)

Attachment 5 CNRO-2016-00010 (Page 1 of 2)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding Vermont Yankee For Year Ending December 31, 2015 - 10 CFR 50.75(f)(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)                                        $ 740.52 million [Note 1]
estimated per 10 CFR 50.75(b) and (c) (2015$)
: 2. ISFSI Obligation as of 12/31/15                                          $5.05 million [Note 2]
: 3. Decommissioning Trust Fund Total                                         $ 595.44 million as of 12/31/15
: 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 10         None CFR 50.75(e)(1)(v)
: 7. Modifications occurring to a licensee's 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 13. (Calculation of the NRC Minimum Amount is provided in Attachment 6).
Note 2: From Entergys ISFSI Decommissioning Funding Plans Pursuant to 10 CFR 72.30, December 17, 2015 (Accession No. ML15351A524).
Note 3: Since the last submitted report, Entergy Nuclear Vermont Yankee, LLC canceled a $40 million parent guarantee that previously provided decommissioning financial assurance for Vermont Yankee, based on the establishment of certain lines of credit. In a letter from the NRC to Entergy Nuclear Operations, Inc., and Vermont Yankee Nuclear Power Station dated April 21, 2015, the NRC determined that Entergy Corporation had complied with the general requirements of 10 CFR 30 Appendix A (III)(A) and granted Entergy Corporation the right to cancel the $40 million parent company guarantee for Vermont Yankee (Accession No. ML15107A074).

Attachment 5 CNRO-2016-00010 (Page 2 of 2)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding Vermont Yankee For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1) 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 12/31/2015                   $ 74.35 million [Note1]
: 2. 2015 decommissioning spending                                           $ 59.57 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                        $ 740.52 million
: 6. Estimate is based on unrestricted release of the 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 2015 decommissioning costs. 2014 costs are included in item 1 and have been reimbursed in 2015.

Attachment 6 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Calculation of Minimum Amount - Vermont Yankee For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Entergy Nuclear Vermont Yankee LLC.: 100% 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 10CFR50.75(c)(2) Escalation Factor Formula:
0.65(L) +0.13(E) +0.22(B)
Factor L=Labor (North)                             2.711 E=Energy (BWR)                              1.752 B=Waste Burial-Vendor (BWR)                 14.1603 BWR Escalation Factor:
0.65(L) +0.13(E) +0.22(B)=                  5.10582 1986 BWR Base Year $ Escalated:
    $121,208,000
* Factor=                      $618,866,471 1                                                                     th Bureau of Labor Statistics, Series Report ID: CIU2010000000210i (4 Quarter 2015) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2015) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 15, Table 2.1 (2013)

Attachment 7 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Pilgrim For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Plant Name: Pilgrim Nuclear Power Station
: 1. Minimum Financial Assurance (MFA)                                $ 624.20 million [Note 1]
estimated per 10 CFR 50.75(b) and (c) (2015$)
                                                                     $8.98 million [Note 2]
: 2. ISFSI Obligation as of 12/31/15
: 3. Decommissioning Trust Fund Total                                 $ 895.71 million as of 12/31/15
: 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 10  None CFR 50.75(e)(1)(v)
: 7. Modifications occurring to a licensee's 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 Pursuant to 10 CFR 72.30, December 17, 2015 (Accession No. ML15351A524).

Attachment 8 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Calculation of Minimum Amount - Pilgrim For Year Ending December 31, 2015 - 10 CFR 50.75(f)(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 10CFR50.75(c)(2) Escalation Factor Formula:
0.65(L) +0.13(E) +0.22(B)
Factor L=Labor (North)                             2.711 E=Energy (BWR)                              1.752 B=Waste Burial-Vendor (BWR)                 14.1603 BWR Escalation Factor:
0.65(L) +0.13(E) +0.22(B)=                  5.10582 1986 BWR Base Year $ Escalated:
    $122,252,000
* Factor=                      $624,196,949 1                                                                     th Bureau of Labor Statistics, Series Report ID: CIU2010000000210i (4 Quarter 2015) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2015) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 15, Table 2.1 (2013)

Attachment 9 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - James A. Fitzpatrick For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Plant Name: James A. Fitzpatrick Nuclear Power Plant
: 1. Minimum Financial Assurance (MFA)                               $ 647.54 million [Note 1]
estimated per 10 CFR 50.75(b) and (c) (2015$)
                                                                    $ 8.17 million [Note 2]
: 2. ISFSI Obligation as of 12/31/15
: 3. Decommissioning Trust Fund Total                                $ 746.19 million as of 12/31/15
: 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 licensee's 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 10.
Note 2: From Entergys ISFSI Decommissioning Funding Plans Pursuant to 10 CFR 72.30, December 17, 2015 (Accession No. ML15351A524).

Attachment 10 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Calculation of Minimum Amount - James A. Fitzpatrick For Year Ending December 31, 2015 - 10 CFR 50.75(f)(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 1986$: $126,824,000 Labor Region: North 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 (North)                             2.711 E=Energy (BWR)                              1.752 B=Waste Burial-Vendor (BWR)                 14.1603 BWR Escalation Factor:
0.65(L) +0.13(E) +0.22(B)=                  5.10582 1986 BWR Base Year $ Escalated:
    $126,824,000
* Factor=                      $647,540,768 1                                                                     th Bureau of Labor Statistics, Series Report ID: CIU2010000000210i (4 Quarter 2015) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2015) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 15, Table 2.1 (2013)

Attachment 11 CNRO-2016-00010 (Page 1 of 1)
Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Big Rock Point For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Plant Name: Big Rock Point ISFSl
: 1. Amount of decommissioning funds required from           $ 2.43 million [Note 1]
most recent estimate (2015 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 licensee's current         None method of providing financial assurance since the last submitted report
: 7. Any material changes to trust agreements                None Note 1: See 10 CFR &sect;72.30 filing for Big Rock Point, dated December 17, 2015, Accession No. ML15351A524.

Attachment 12 CNRO-2016-00010 (Page 1 of 4)
Entergy Nuclear Operations, Inc.
IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
On October 23, 2008, Entergy Nuclear Indian Point 2, LLC (ENIP2) submitted a preliminary decommissioning cost analysis to the NRC in conjunction with its spent fuel management plan under 10 CFR 50.75(f)(3) and 10 CFR 50.54(bb) (Accession No. ML083040378, as supplemented by ENIP2's reply to RAIs on July 15, 2009 (Accession No. ML092050204). The preliminary decommissioning cost analysis contained separate site-specific decommissioning cost estimates for Indian Point 1 and Indian Point 2. The estimates were subsequently found to be reasonable by the NRC on March 17, 2010 (Accession No. ML100280544).
Pursuant to Regulatory Guide 1.159, Revision 2, adjustment to the site-specific cost estimates 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 process in compliance with NRC decommissioning funding assurance rules.
Pursuant to 10 CFR 50.75(e)(1)(i), "A licensee that has prepaid funds based on a site-specific estimate under &sect; 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." 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 decommissioning costs as defined in 10 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 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 1 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 12-1 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 balance is escalated each year by the 2% real growth figure allowed pursuant to 10 CFR 50.75(e)(1)(i).

Attachment 12 CNRO-2016-00010 (Page 2 of 4)
Entergy Nuclear Operations, Inc.
IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Table 12-1 NRC License Termination Cost
($ millions) 2015 $ Unit 1    Ending DTF Radiological       Balance 2015                          413.921 2016            0.951         421.248 2017            3.804         425.869 2018            3.804         430.582 2019            3.815         435.379 2020            3.804         440.282 2021            3.804         445.283 2022            3.804         450.385 2023            3.815         455.578 2024            3.804         460.885 2025            3.804         466.298 2026            3.804         471.820 2027            3.815         477.442 2028            3.804         483.186 2029            3.804         489.045 2030            3.804         495.022 2031            3.815         501.108 2032            3.804         507.326 2033            3.804         513.668 2034            3.804         520.137 2035            3.815         526.725 2036            3.804         533.455 2037            3.804         540.320 2038            3.804         547.322 2039            3.815         554.453 2040            3.804         561.738 2041            3.804         569.169 2042            3.804         576.748 2043            3.815         584.468 2044            3.804         592.353 2045            3.804         600.396 2046            3.804         608.599 2047            3.815         616.957 2048            3.804         625.491 2049            3.804         634.197 2050            3.804         643.076 2051            3.815         652.123

Attachment 12 CNRO-2016-00010 (Page 3 of 4)
Entergy Nuclear Operations, Inc.
IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Table 12-1 NRC License Termination Cost
($ millions) 2015 $ Unit 1    Ending DTF Radiological       Balance 2052            3.804         661.361 2053            3.804         670.784 2054            3.804         680.396 2055            3.815         690.189 2056            3.804         700.188 2057            3.804         710.388 2058            3.804         720.791 2059            3.815         731.392 2060            3.815         742.205 2061            3.804         753.245 2062            3.804         764.506 2063            3.804         775.992 2064            3.815         787.697 2065           28.011         775.440 2066           61.646         729.303 2067         102.982          640.907 2068         109.450          544.275 2069           15.770         539.390 2070           15.792         534.386 2071           15.792         529.282 2072           15.835         524.033 2073            7.788         526.726 Total          556.759

Attachment 12 CNRO-2016-00010 (Page 4 of 4)
Entergy Nuclear Operations, Inc.
IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
As can be seen from the information provided in Table 12-1, the required funding for SAFSTOR decommissioning, $556.76 million, is greater than the NRC formula amount per 10 CFR 50.75(b) and (c) of $431.81 million, therefore, the site-specific analysis complies with the requirement from Regulatory Guide 1.159 section 1.1.1 previously discussed. The foregoing SAFSTOR analysis shows that when the December 31, 2015 DTF balance is escalated at the allowable rate and compared against the annual figures for the SAFSTOR period, that an approximately $526.73 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 1.

Attachment 13 CNRO-2016-00010 (Page 1 of 6)
Entergy Nuclear Operations, Inc.
Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2015 - 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 $595 million as of December 31, 2015. Tables 3.4 and 3.5 of the site-specific decommissioning cost estimate (Reference 1, Attachment 1) 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 13-1.
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 $223 million) 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).
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 10 CFR 50.75(e)(1)(i), "A licensee that has prepaid funds based on a site-specific estimate under &sect; 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 10 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 for justifying 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 2068, at which time the plant will be decommissioned and the site released for alternative use without restriction. Table 13-1 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 pursuant to 10 CFR 50.75(e)(1)(i).

Attachment 13 CNRO-2016-00010 (Page 2 of 6)
Entergy Nuclear Operations, Inc.
Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Thus, considering the fund balance of $595 million, as of December 31, 2015, and projected fund earnings during the SAFSTOR period (assuming an annual 2% growth rate), the trust fund is expected to have an excess of $190.6 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, BVY 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 13-1 Vermont Yankee Nuclear Power Station - SAFSTOR Methodology Annual Cash Flow Analysis - Total License Termination, Spent Fuel Management less Dry Fuel Costs (In Thousands in 2015 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                        ($000s) Fund
($000s)      ($000s)         Cost             Management      ($000s)                                Balance
($000s)         Cost less                                               ($000s)
Dry Fuel Cost
($000s) 2016       48,305        75,778           53,820           70,263         595,443    70,263              10,504  535,683 2017       11,007        49,345           29,882           30,471         535,683    30,471              10,104  515,317 2018       9,704         41,277           19,752           31,229         515,317    31,229              9,682   493,769 2019       8,299         36,929           17,022           28,205         493,769    28,205              9,311   474,875 2020       17,779        27,680           17,625           27,834         474,875    27,834              8,941   455,982 2021       5,303          4,055                             9,358         455,982    9,358               8,932   455,557 2022       5,251          4,055                             9,307         455,557    9,307               8,925   455,176 2023       5,251          4,055                             9,307         455,176    9,307               8,917   454,786 2024       3,676          4,066                             7,742         454,786    7,742               8,941   455,985 2025       3,616          4,055                             7,671         455,985    7,671               8,966   457,280 2026       3,761          4,055                             7,816         457,280    7,816               8,989   458,453 2027       3,812          4,055                             7,867         458,453    7,867               9,012   459,597

Attachment 13 CNRO-2016-00010 (Page 3 of 6)
Entergy Nuclear Operations, Inc.
Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Table 13-1 Vermont Yankee Nuclear Power Station - SAFSTOR Methodology Annual Cash Flow Analysis - Total License Termination, Spent Fuel Management less Dry Fuel Costs (In Thousands in 2015 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                        ($000s) Fund
($000s)      ($000s)         Cost             Management      ($000s)                                Balance
($000s)         Cost less                                               ($000s)
Dry Fuel Cost
($000s) 2028       3,770          4,066                             7,836         459,597    7,836               9,035   460,796 2029       3,761          4,055                             7,816         460,796    7,816               9,060   462,040 2030       3,812          4,055                             7,867         462,040    7,867               9,083   463,256 2031       3,761          4,055                             7,816         463,256    7,816               9,109   464,548 2032       3,770          4,066                             7,836         464,548    7,836               9,134   465,846 2033       3,812          4,055                             7,867         465,846    7,867               9,160   467,139 2034       3,761          4,055                             7,816         467,139    7,816               9,186   468,509 2035       3,761          4,055                             7,816         468,509    7,816               9,214   469,906 2036       3,821          4,066                             7,887         469,906    7,887               9,240   471,259 2037       3,761          4,055                             7,816         471,259    7,816               9,269   472,712 2038       3,761          4,055                             7,816         472,712    7,816               9,298   474,194 2039       3,812          4,055                             7,867         474,194    7,867               9,327   475,653 2040       3,770          4,066                             7,836         475,653    7,836               9,356   477,173 2041       3,761          4,055                             7,816         477,173    7,816               9,387   478,744 2042       3,812          4,055                             7,867         478,744    7,867               9,418   480,294 2043       3,761          4,055                             7,816         480,294    7,816               9,450   481,927 2044       3,770          4,066                             7,836         481,927    7,836               9,482   483,573 2045       3,812          4,055                             7,867         483,573    7,867               9,514   485,220 2046       3,761          4,055                             7,816         485,220    7,816               9,548   486,952 2047       3,761          4,055                             7,816         486,952    7,816               9,583   488,718 2048       3,821          4,066                             7,887         488,718    7,887               9,617   490,447 2049       3,761          4,055                             7,816         490,447    7,816               9,653   492,284 2050       3,761          4,055                             7,816         492,284    7,816               9,689   494,157 2051       3,812          4,055                             7,867         494,157    7,867               9,726   496,015 2052       3,770          4,066                             7,836         496,015    7,836               9,764   497,942 2053       3,608                                            3,608         497,942    3,608               9,887   504,221 2054       3,659                                            3,659         504,221    3,659               10,011  510,574 2055       3,608                                            3,608         510,574    3,608               10,139  517,105

Attachment 13 CNRO-2016-00010 (Page 4 of 6)
Entergy Nuclear Operations, Inc.
Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Table 13-1 Vermont Yankee Nuclear Power Station - SAFSTOR Methodology Annual Cash Flow Analysis - Total License Termination, Spent Fuel Management less Dry Fuel Costs (In Thousands in 2015 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                        ($000s) Fund
($000s)      ($000s)         Cost             Management      ($000s)                                Balance
($000s)         Cost less                                               ($000s)
Dry Fuel Cost
($000s) 2056       3,617                                            3,617         517,105    3,617               10,270  523,758 2057       3,659                                            3,659         523,758    3,659               10,402  530,502 2058       3,608                                            3,608         530,502    3,608               10,538  537,432 2059       3,608                                            3,608         537,432    3,608               10,676  544,500 2060       3,668                                            3,668         544,500    3,668               10,817  551,649 2061       3,608                                            3,608         551,649    3,608               10,961  559,002 2062       3,608                                            3,608         559,002    3,608               11,108  566,502 2063       3,659                                            3,659         566,502    3,659               11,257  574,100 2064       3,617                                            3,617         574,100    3,617               11,410  581,894 2065       3,608                                            3,608         581,894    3,608               11,566  589,851 2066       3,659                                            3,659         589,851    3,659               11,724  597,916 2067       3,608                                            3,608         597,916    3,608               11,886  606,195 2068       43,690                                          43,690         606,195    43,690              11,250  573,755 2069       93,039                                          93,039         573,755    93,039              9,614   490,331 2070      105,681                                          105,681        490,331   105,681              7,693   392,343 2071       85,618                                          85,618         392,343    85,618              6,134   312,859 2072       86,055                                          86,055         312,859    86,055              4,536   231,341 2073       50,949                                          50,949         231,341    50,949              3,608   184,000 2074        523                                              523          184,000     523                3,670   187,147 2075        302                                              302          187,147     302                3,737   190,582 740,517        360,863          138,101          963,280        595,443   963,280             558,418  190,582 As can be seen from the information provided in Table 13-1, the required funding for SAFSTOR decommissioning, $740.52 million, is greater than the NRC formula amount per 10 CFR 50.75(b) and (c) of $618.87 million, therefore, the site-specific analysis complies with the requirement from Regulatory Guide 1.159 section 1.1.1 previously discussed. The foregoing SAFSTOR analysis shows that when the December 31, 2015 DTF balance is escalated at the

Attachment 13 CNRO-2016-00010 (Page 5 of 6)
Entergy Nuclear Operations, Inc.
Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1) allowable rate and compared against the annual figures for the SAFSTOR period, that an approximately $190.6 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 13-1 Definitions:
Column 1:      50.75 License Termination Cost Reflects the Total Annual License Termination Plan cost in 2015 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 2015 dollars at a 0.0% escalation rate Column 3:      Exclude Transfer to Dry 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 2015 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 2015 dollars at a 0.0% escalation rate (Column 1 + Column 2 - Column 3)
Column 5:      Beginning of Year Trust Fund Balance Reflects the beginning of year Trust Fund balance in 2015 dollars at a 0.0%
escalation rate and 2.0% Fund Earnings

Attachment 13 CNRO-2016-00010 (Page 6 of 6)
Entergy Nuclear Operations, Inc.
Vermont Yankee Annual Cash Flow Analysis For Year Ending December 31, 2015 - 10 CFR 50.75(f)(1)
Column 6: Withdraw Reflects the annual expenditures from the Trust Fund in 2015 dollars at a 0.0%
escalation rate (equals Column 4)
Column 7: Contribute Reflects the annual contributions to the Trust Fund in 2015 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 100% 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 2015 dollars. (Column 5 - Column 6 +
Column 7 + Column 8)

Attachment 14 CNRO-2016-00010 (Page 1 of 6)
Entergy Nuclear Operations, Inc.
Minimum Financial Assurance Calculation Worksheets Plant name:                                             Indian Point Energy Center, Unit 1 Month                      Day                         Year Year of Biennial:               12                         31                        2015 Termination of Operation:            9                          28                        2013 MWth    1986$     ECI     Base Lx                           Lx         Px          Fx         Ex         Bx PWR         615 $85,560,000 125.6       2.16             0.65         2.71      1.882        1.590 0.13 1.76 0.22 13.885 NRC Minimum:                      $431,807,460                   Site Specific: $556,759,099 Licensee:     % Owned:    Amount of NRC Minimum/Site Specific:   Amount in Trust Fund:
Entergy       100.00%                 $556,759,099                   $413,920,819 Note: See Attachment 12 for adequacy of the trust fund.

Attachment 14 CNRO-2016-00010 (Page 2 of 6)
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                                  2015 Termination of Operation:                     12                           12                                  2015 MWth      1986$        ECI        Base Lx                                 Lx           Px                 Fx                    Ex                     Bx PWR           3216  $103,300,800   125.6         2.16               0.65              2.71        1.882               1.590       0.13      1.76      0.22        13.885 NRC Minimum:                              $521,342,404                         Site Specific:
Licensee:        % Owned:       Amount of NRC Minimum/Site Specific:           Amount in Trust Fund:
Entergy          100.00%                      $521,342,404                          $683,835,864 Step 1:
Earnings Credit:
Real Rate of Years Left   Total Real Trust Fund Balance:   Return per in License     Rate of             Total Earnings:
     $683,835,864          2%         0.00       1.00000              $683,835,864             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 Step 3:
Decom Period:
Real Rate of  Decom       Total Real Total Earnings:    Return per   Period:      Rate of       Total Earnings for Decom:
     $683,835,864          2%           7        0.14869               $50,838,296             Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]
Total of Steps 1 - 3:
                                                                      $734,674,160             Total = Total Earnings + Total Earnings for Decom Excess (Shortfall)        $                  213,331,756    to NRC minimum
                                                             $                    (6,790,496)   Less ISFSI
                                                             $                            -     Parent Co Guaranty
                                                             $                  206,541,261     Total Excess Financial Assurance

Attachment 14 CNRO-2016-00010 (Page 3 of 6)
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                                 2015 Termination of Operation:                     9                            28                                 2013 MWth      1986$        ECI        Base Lx                                 Lx          Px                  Fx                   Ex                  Bx PWR           3216  $103,300,800   125.6         2.16               0.65              2.71       1.882               1.590       0.13      1.76      0.22     13.885 NRC Minimum:                              $521,342,404                         Site Specific:
Licensee:        % Owned:       Amount of NRC Minimum/Site Specific:           Amount in Trust Fund:
Entergy          100.00%                      $521,342,404                          $529,053,777 Step 1:
Earnings Credit:
Real Rate of Years Left   Total Real Trust Fund Balance:   Return per in License     Rate of             Total Earnings:
     $529,053,777          2%         0.00       1.00000              $529,053,777            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 Step 3:
Decom Period:
Real Rate of  Decom       Total Real Total Earnings:    Return per   Period:      Rate of       Total Earnings for Decom:
     $529,053,777          2%           7        0.14869               $39,331,357            Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]
Total of Steps 1 - 3:
                                                                      $568,385,134            Total = Total Earnings + Total Earnings for Decom Excess (Shortfall)        $                   47,042,730    to NRC minimum
                                                             $                    (6,152,189)  Less ISFSI
                                                             $                            -    Parent Co Guaranty
                                                             $                   40,890,541    Total Excess Financial Assurance

Attachment 14 CNRO-2016-00010 (Page 4 of 6)
Entergy Nuclear Operations, Inc.
Minimum Financial Assurance Calculation Worksheets Plant name:                                                Vermont Yankee Power Station Month                      Day                        Year Year of Biennial:                12                          31                       2015 Termination of Operation:             12                          29                       2014 MWth     1986$      ECI     Base Lx                          Lx         Px          Fx            Ex        Bx BWR        1912 $121,208,000 125.6       2.16             0.65        2.71      1.882        1.590    0.13 1.75 0.22 14.16 NRC Minimum:                        $618,866,471                  Site Specific:        $740,517,165 Licensee:      % Owned:     Amount of NRC Minimum/Site Specific:  Amount in Trust Fund:
Entergy        100.00%                  $740,517,165                  $595,443,076 Note: See Attachment 13 for adequacy of the trust fund.

Attachment 14 CNRO-2016-00010 (Page 5 of 6)
Entergy Nuclear Operations, Inc.
Minimum Financial Assurance Calculation Worksheets Plant name:                                                      Pilgrim Nuclear Generating Station Month                           Day                                 Year Year of Biennial:                       12                           31                                 2015 Termination of Operation:                     5                            31                                 2019 MWth      1986$        ECI        Base Lx                                 Lx          Px                  Fx                   Ex                  Bx BWR           2028  $122,252,000   125.6         2.16               0.65              2.71       1.882               1.590       0.13      1.75      0.22     14.16 NRC Minimum:                              $624,196,949                         Site Specific:
Licensee:        % Owned:       Amount of NRC Minimum/Site Specific:           Amount in Trust Fund:
Entergy          100.00%                      $624,196,949                          $895,714,834 Step 1:
Earnings Credit:
Real Rate of Years Left   Total Real Trust Fund Balance:   Return per in License     Rate of             Total Earnings:
     $895,714,834          2%         3.42       1.07000              $958,415,187            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 Step 3:
Decom Period:
Real Rate of  Decom       Total Real Total Earnings:    Return per   Period:      Rate of       Total Earnings for Decom:
     $958,415,187          2%           7        0.14869               $71,251,301            Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]
Total of Steps 1 - 3:
                                                                     $1,029,666,488           Total = Total Earnings + Total Earnings for Decom Excess (Shortfall)        $                  405,469,538    to NRC minimum
                                                             $                    (8,975,100)  Less ISFSI
                                                             $                            -    Parent Co Guaranty
                                                             $                  396,494,438    Total Excess Financial Assurance

Attachment 14 CNRO-2016-00010 (Page 6 of 6)
Entergy Nuclear Operations, Inc.
Minimum Financial Assurance Calculation Worksheets Plant name:                                                                   James A. FitzPatrick Month                          Day                                  Year Year of Biennial:                       12                           31                                 2015 Termination of Operation:                     1                            27                                 2017 MWth      1986$        ECI        Base Lx                                 Lx          Px                  Fx                   Ex                  Bx BWR           2536  $126,824,000   125.6         2.16               0.65              2.71       1.882               1.590       0.13      1.75      0.22     14.16 NRC Minimum:                              $647,540,768                         Site Specific:
Licensee:        % Owned:       Amount of NRC Minimum/Site Specific:           Amount in Trust Fund:
Entergy          100.00%                      $647,540,768                          $746,189,340 Step 1:
Earnings Credit:
Real Rate of Years Left   Total Real Trust Fund Balance:   Return per in License     Rate of             Total Earnings:
     $746,189,340          2%         1.07       1.02146              $762,204,739            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 Step 3:
Decom Period:
Real Rate of  Decom       Total Real Total Earnings:    Return per   Period:      Rate of       Total Earnings for Decom:
     $762,204,739          2%           7        0.14869               $56,664,460            Total Earnings for Decom = (1/2) x Total Earnings x [(1+RRR)^Decom period - 1]
Total of Steps 1 - 3:
                                                                      $818,869,200            Total = Total Earnings + Total Earnings for Decom Excess (Shortfall)        $                  171,328,432    to NRC minimum
                                                             $                    (8,171,509)  Less ISFSI
                                                             $                            -    Parent Co Guaranty
                                                             $                  163,156,923    Total Excess Financial Assurance}}