ML12093A382: Difference between revisions

From kanterella
Jump to navigation Jump to search
(Created page by program invented by StriderTol)
(Created page by program invented by StriderTol)
 
(4 intermediate revisions by the same user not shown)
Line 2: Line 2:
| number = ML12093A382
| number = ML12093A382
| issue date = 03/30/2012
| issue date = 03/30/2012
| title = Pilgrim, Status of Decommissioning Funding for Year Ending December 31, 2011
| title = Status of Decommissioning Funding for Year Ending December 31, 2011
| author name = McCann J F
| author name = Mccann J
| author affiliation = Entergy Nuclear Operations, Inc
| author affiliation = Entergy Nuclear Operations, Inc
| addressee name =  
| addressee name =  
Line 16: Line 16:


=Text=
=Text=
{{#Wiki_filter:'Entergy Entergy Nuclear Operations, Inc.440 Hamilton Avenue White Plains, New York 10601 Tel 914-272-3370 John F. McCann Vice President, Nuclear Safety, Emergency Planning and Licensing March 30, 2012 ENOC-1 2-0005 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001
{{#Wiki_filter:'Entergy                                                                         Entergy Nuclear Operations, Inc.
440 Hamilton Avenue White Plains, New York 10601 Tel 914-272-3370 John F. McCann Vice President, Nuclear Safety, Emergency Planning and Licensing March 30, 2012 ENOC-1 2-0005 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001


==SUBJECT:==
==SUBJECT:==
Status of Decommissioning Funding for Plants Operated by Entergy Nuclear Operations, Inc.For Year Ending December 31, 2011 -10 CFR 50.75(f)(1)
Status of Decommissioning Funding for Plants Operated by Entergy Nuclear Operations, Inc.
Entergy Nuclear Operations, Inc.Indian Point Nuclear Generating Stations 1, 2 and 3 Docket Nos. 50-3, 50-247 and 50-286 Pilgrim Nuclear Power Station Docket No. 50-293  
For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)
Entergy Nuclear Operations, Inc.
Indian Point Nuclear Generating Stations 1, 2 and 3 Docket Nos. 50-3, 50-247 and 50-286 Pilgrim Nuclear Power Station Docket No. 50-293


==REFERENCES:==
==REFERENCES:==
: 1. NUREG-1307, "Report on Waste Burial Charges," Revision 14, dated November 2010.2. NRC Regulatory Issue Summary 2001-07, "10 CFR 50.75(f)(1)
: 1. NUREG-1307, "Report on Waste Burial Charges," Revision 14, dated November 2010.
Reports on the Status of Decommissioning Funds (Due March 31, 2001)."  
: 2. NRC Regulatory Issue Summary 2001-07, "10 CFR 50.75(f)(1) Reports on the Status of Decommissioning Funds (Due March 31, 2001)."


==Dear Sir or Madam:==
==Dear Sir or Madam:==
10 CFR 50.75(f)(1) requires each power reactor licensee to report to the NRC by March 31 of each year the status of its decommissioning funding for each reactor or share of a reactor that it owns that is within 5 years of the end of its current operating license or where conditions have changed so that it will close within 5 years. On behalf of Entergy Nuclear Indian Point 2 LLC, Entergy Nuclear Indian Point 3 LLC and Entergy Nuclear Generation Company (Pilgrim Station), 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 6, respectively, were prepared in accordance with NUREG-1307 (Reference  
 
: 1) and NRC Regulatory Issue Summary 2001-07 (Reference 2). Attachments 7 and 8 are updated site specific decommissioning cost estimates for IP 1 and 2. Attachment 9 includes Minimum Funding Assurance calculation worksheets for the plants (derived from LIC-205 Revision 4), provided for the convenience of the reviewer.On March 21, 2011, the Nuclear Regulatory Commission issued a renewed license for the Vermont Yankee Nuclear Power Station (Vermont Yankee), so that the operating license now expires on March 21, 2032. The licensee does not have plans to close Vermont Yankee within 5 years. Accordingly, Entergy Nuclear Operations, Inc. is not including herewith a report pursuant to 10 CFR 50.75(f)(1) for Vermont Yankee.I A ENOC-12-0005 The aforementioned worksheets, using the December 31, 2011 trust fund balances indicate that all of the plants covered by this submittal met or exceeded the NRC's funding requirements.
10 CFR 50.75(f)(1) requires each power reactor licensee to report to the NRC by March 31 of each year the status of its decommissioning funding for each reactor or share of a reactor that it owns that is within 5 years of the end of its current operating license or where conditions have changed so that it will close within 5 years. On behalf of Entergy Nuclear Indian Point 2 LLC, Entergy Nuclear Indian Point 3 LLC and Entergy Nuclear Generation Company (Pilgrim Station), 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 6, respectively, were prepared in accordance with NUREG-1307 (Reference 1) and NRC Regulatory Issue Summary 2001-07 (Reference 2). Attachments 7 and 8 are updated site specific decommissioning cost estimates for IP 1 and 2. Attachment 9 includes Minimum Funding Assurance calculation worksheets for the plants (derived from LIC-205 Revision 4), provided for the convenience of the reviewer.
On March 21, 2011, the Nuclear Regulatory Commission issued a renewed license for the Vermont Yankee Nuclear Power Station (Vermont Yankee), so that the operating license now expires on March 21, 2032. The licensee does not have plans to close Vermont Yankee within 5 years. Accordingly, Entergy Nuclear Operations, Inc. is not including herewith a report pursuant to 10 CFR 50.75(f)(1) for Vermont Yankee.
I A
 
ENOC-12-0005 The aforementioned worksheets, using the December 31, 2011 trust fund balances indicate that all of the plants covered by this submittal met or exceeded the NRC's funding requirements.
There are no new commitments made in this letter. If you have any questions, please contact Mr. Bryan Ford at 601-368-5516.
There are no new commitments made in this letter. If you have any questions, please contact Mr. Bryan Ford at 601-368-5516.
Sincerely, Attachments:
Sincerely, Attachments: As described above cc: See next page.
As described above cc: See next page.2 ENOC-12-0005 cc: All Below with Attachments Mr. J. A. Aluise (ENT)Mr. M. A. Balduzzi (ECH)Ms. W. C. Curry (ECH)Mr. B. E. Green (TMBR)Mr. J. F. McCann (WPO)Mr. J. E. Pollock (IPEC)Mr. L. Jager Smith (ECH)Mr. R. G. Smith (PNP)USNRC Regional Administrator, Region I USNRC Regional Administrator, Region III USNRC Project Manager, Indian Point 1 USNRC Project Manager, Indian Point 2 USNRC Project Manager, Indian Point 3 USNRC Project Manager, Pilgrim USNRC Resident Inspector, Indian Point 2 USNRC Resident Inspector, Indian Point 3 USNRC Resident Inspector, Pilgrim Michigan Department of Environmental Quality Michigan Public Service Commission Ms. Elizabeth Miller, Commissioner VT Department of Public Service 120 State Street -Drawer 20 Montpelier, VT 05602 Ms. Bridget Frymire NYS Department of Public Service 3 Empire State Plaza Albany, NY 12223 Ms. Nancy S. Malmquist Downs Rachlin Martin PLLC PO Box 99 St. Johnsbury, VT 05819-0099 3
2
Attachment 1 ENOC-12-0005 Entergy Nuclear Operations, Inc.Status of Decommissioning Funding -Indian Point 1 For Year Ending December 31, 2011 -10 CFR 50.75(f)(1)
Plant Name: Indian Point Nuclear Generating Unit No. 1 1. Minimum Financial Assurance (MFA)estimated per 10 CFR 50.75(b) and (c) (2011$)2. Decommissioning Trust Fund Total as of 12/31/11 3. A schedule of the annual amounts remaining to be collected 4. Assumptions used in determining rates of escalation in decommissioning costs, rates of earnings on decommissioning funds, and rates of other factors used in funding projections
: 5. Any contracts upon which the licensee is relying pursuant to 10 CFR 50.75(e)(1)(v)
: 6. Modifications occurring to a licensee's current method of providing financial assurance since the last submitted report 7. Any material changes to trust agreements
$ 476.84 million[Note]$ 300.76 million None 2% annual real rate of return per 10 CFR 50.75(e)(1)(i)
None None None Note: 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
: 7. (Calculation of the NRC Minimum Amount is provided in Attachment 4.)1 Attachment 2 ENOC-12-0005 Entergy Nuclear Operations, Inc.Status of Decommissioning Funding -Indian Point 2 For Year Ending December 31, 2011 -10 CFR 50.75(f)(1)
Plant Name: Indian Point Nuclear Generating Unit No. 2 1. Minimum Financial Assurance (MFA)estimated per 10 CFR 50.75(b) and (c) (2011$)2. Decommissioning Trust Fund Total as of 12/31/11 3. A schedule of the annual amounts remaining to be collected 4. Assumptions used in determining rates of escalation in decommissioning costs, rates of earnings on decommissioning funds, and rates of other factors used in funding projections
: 5. Any contracts upon which the licensee is relying pursuant to 10 CFR 50.75(e)(1)(v)
: 6. Modifications occurring to a licensee's current method of providing financial assurance since the last submitted report 7. Any material changes to trust agreements
$ 715.80 million[Note 1]$ 392.37 million[Note 2]None 2% annual real rate of return per 10 CFR 50.75(e)(1)(i)
None None 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
: 8. (Calculation of the NRC Minimum Amount is provided in Attachment 4.)Note 2:lncludes provisional fund balance of $31.05 million.2 Attachment 3 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.Status of Decommissioning Funding -Indian Point 3 For Year Ending December 31, 2011 -10 CFR 50.75(f)(1)
Plant Name: Indian Point Nuclear Generating Unit No. 3 1. Minimum Financial Assurance (MFA)estimated per 10 CFR 50.75(b) and (c) (2011$)2. Decommissioning Trust Fund Total as of 12/31/11 3. A schedule of the annual amounts remaining to be collected 4. Assumptions used in determining rates of escalation in decommissioning costs, rates of earnings on decommissioning funds, and rates of other factors used in funding projections
: 5. Any contracts upon which the licensee is relying pursuant to 10 CFR 50.75(e)(1)(v)
: 6. Modifications occurring to a licensee's current method of providing financial assurance since the last submitted report 7. Any material changes to trust agreements
$ 482.11 million[Note]$ 521.16 million None 2% annual real rate of return per 10 CFR 50.75(e)(1)(i)
None None None Note: Calculation of the NRC Minimum Amount is provided in Attachment


===4.3 Attachment===
ENOC-12-0005 cc: All Below with Attachments Mr. J. A. Aluise (ENT)
Mr. M. A. Balduzzi (ECH)
Ms. W. C. Curry (ECH)
Mr. B. E. Green (TMBR)
Mr. J. F. McCann (WPO)
Mr. J. E. Pollock (IPEC)
Mr. L. Jager Smith (ECH)
Mr. R. G. Smith (PNP)
USNRC Regional Administrator, Region I USNRC Regional Administrator, Region III USNRC Project Manager, Indian Point 1 USNRC Project Manager, Indian Point 2 USNRC Project Manager, Indian Point 3 USNRC Project Manager, Pilgrim USNRC Resident Inspector, Indian Point 2 USNRC Resident Inspector, Indian Point 3 USNRC Resident Inspector, Pilgrim Michigan Department of Environmental Quality Michigan Public Service Commission Ms. Elizabeth Miller, Commissioner VT Department of Public Service 120 State Street - Drawer 20 Montpelier, VT 05602 Ms. Bridget Frymire NYS Department of Public Service 3 Empire State Plaza Albany, NY 12223 Ms. Nancy S. Malmquist Downs Rachlin Martin PLLC PO Box 99 St. Johnsbury, VT 05819-0099 3


4 ENOC-12-0005 Entergy Nuclear Operations, Inc.Calculation of Minimum Amount -Indian Point For Year Endina December 31. 2011 -10 CFR 50.75(f)(1)
Attachment 1 ENOC-12-0005 Entergy Nuclear Operations, Inc.
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:
Status of Decommissioning Funding - Indian Point 1 For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)
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:
Plant Name: Indian Point Nuclear Generating Unit No. 1
Generic Disposal Site 10CFR50.75(c)(2)
: 1. Minimum Financial Assurance (MFA)                                      $ 476.84 million
Escalation Factor Formula: 0.65(L) +0.13(E) +0.22(B)L=Labor (North)E=Energy (PWR)B=Waste Burial-Vendor (PWR)PWR Escalation Factor: 0.65(L) +0.13(E) +0.22(B)=1986 PWR Base Year $ Escalated:
[Note]
estimated per 10 CFR 50.75(b) and (c) (2011$)
: 2. Decommissioning Trust Fund Total                                        $ 300.76 million as of 12/31/11
: 3. A schedule of the annual amounts remaining to be collected            None
: 4. Assumptions used in determining rates of escalation in                2% annual real rate decommissioning costs, rates of earnings on decommissioning        of return per 10 funds, and rates of other factors used in funding projections      CFR 50.75(e)(1)(i)
: 5. Any contracts upon which the licensee is relying pursuant to 10        None CFR 50.75(e)(1)(v)
: 6. Modifications occurring to a licensee's current method of providing    None financial assurance since the last submitted report
: 7. Any material changes to trust agreements                              None Note:  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 7. (Calculation of the NRC Minimum Amount is provided in Attachment 4.)
1
 
Attachment 2 ENOC-12-0005 Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Indian Point 2 For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)
Plant Name: Indian Point Nuclear Generating Unit No. 2
: 1. Minimum Financial Assurance (MFA)                                        $ 715.80 million
[Note 1]
estimated per 10 CFR 50.75(b) and (c) (2011$)
                                                                            $ 392.37 million
: 2. Decommissioning Trust Fund Total as of 12/31/11                                                      [Note 2]
: 3. A schedule of the annual amounts remaining to be collected              None
: 4. Assumptions used in determining rates of escalation in                  2% annual real rate decommissioning costs, rates of earnings on decommissioning        of return per 10 funds, and rates of other factors used in funding projections      CFR 50.75(e)(1)(i)
: 5. Any contracts upon which the licensee is relying pursuant to 10        None CFR 50.75(e)(1)(v)
: 6. Modifications occurring to a licensee's current method of providing    None financial assurance since the last submitted report
: 7. 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 8. (Calculation of the NRC Minimum Amount is provided in Attachment 4.)
Note 2:lncludes provisional fund balance of $31.05 million.
2
 
Attachment 3 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Indian Point 3 For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)
Plant Name: Indian Point Nuclear Generating Unit No. 3
: 1. Minimum Financial Assurance (MFA)                                      $ 482.11 million
[Note]
estimated per 10 CFR 50.75(b) and (c) (2011$)
: 2. Decommissioning Trust Fund Total                                      $ 521.16 million as of 12/31/11
: 3. A schedule of the annual amounts remaining to be collected            None
: 4. Assumptions used in determining rates of escalation in                2% annual real rate decommissioning costs, rates of earnings on decommissioning        of return per 10 funds, and rates of other factors used in funding projections      CFR 50.75(e)(1)(i)
: 5. Any contracts upon which the licensee is relying pursuant to 10      None CFR 50.75(e)(1)(v)
: 6. Modifications occurring to a licensee's current method of providing  None financial assurance since the last submitted report
: 7. Any material changes to trust agreements                              None Note: Calculation of the NRC Minimum Amount is provided in Attachment 4.
3
 
Attachment 4 ENOC-12-0005 Entergy Nuclear Operations, Inc.
Calculation of Minimum Amount - Indian Point For Year Endina December 31. 2011 - 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)                                     2.511 E=Energy (PWR)                                     2.582 B=Waste Burial-Vendor (PWR)                         12.283 PWR Escalation Factor:
0.65(L) +0.13(E) +0.22(B)=                         4.6670889 1986 PWR Base Year $ Escalated:
Indian Point 1: $85,560,000
Indian Point 1: $85,560,000
* Factor=Indian Point 2 & 3: $103,300,800
* Factor=               $399,316,126 Indian Point 2 & 3: $103,300,800
* Factor=Factor 2.511 2.582 12.283 4.6670889$399,316,126
* Factor=         $482,114,017 1
$482,114,017 1 2 3 Bureau of Labor Statistics, Series Report ID: CIU201000000021 0i (4 th Quarter 2011)Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2011)Nuclear Regulatory Commission:
Bureau of Labor Statistics, Series Report ID: CIU201000000021 0i (4 th Quarter 2011) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2011) 3 Nuclear Regulatory Commission: NUREG-1 307 Revision 14, Table 2.1 (2010) 4
NUREG-1 307 Revision 14, Table 2.1 (2010)4 Attachment 5 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.Status of Decommissioning Funding -Pilgrim For Year Ending December 31, 2011 -10 CFR 50.75(f)(1)
Plant Name: Pilgrim Nuclear Power Station 1. Minimum Financial Assurance (MFA)estimated per 10 CFR 50.75(b) and (c) (2011$)2. Decommissioning Trust Fund Total as of 12/31/11 3. A schedule of the annual amounts remaining to be collected 4. Assumptions used in determining rates of escalation in decommissioning costs, rates of earnings on decommissioning funds, and rates of other factors used in funding projections
: 5. Any contracts upon which the licensee is relying pursuant to 10 CFR 50.75(e)(1)(v)
: 6. Modifications occurring to a licensee's current method of providing financial assurance since the last submitted report 7. Any material changes to trust agreements
$ 578.76 million [Note]$ 676.66 million None 2% annual real rate of return per 10 CFR 50.75(e)(1)(i)
None None None Note: Calculation of the NRC Minimum Amount is provided in Attachment


===6.5 Attachment===
Attachment 5 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.
Status of Decommissioning Funding - Pilgrim For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)
Plant Name: Pilgrim Nuclear Power Station
: 1. Minimum Financial Assurance (MFA)                                  $ 578.76 million [Note]
estimated per 10 CFR 50.75(b) and (c) (2011$)
: 2. Decommissioning Trust Fund Total                                    $ 676.66 million as of 12/31/11
: 3. A schedule of the annual amounts remaining to be collected        None
: 4. 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
: 5. Any contracts upon which the licensee is relying pursuant to 10    None CFR 50.75(e)(1)(v)
: 6. Modifications occurring to a licensee's current method of          None providing financial assurance since the last submitted report
: 7. Any material changes to trust agreements                          None Note: Calculation of the NRC Minimum Amount is provided in Attachment 6.
5


6 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.Calculation of Minimum Amount -Pilgrim For Year Endinc December 31. 2011 -10 CFR 50.75(f)(1)
Attachment 6 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.
Entergy Nuclear Generation Co.: 100% ownership interest Plant Location:
Calculation of Minimum Amount - Pilgrim For Year Endinc December 31. 2011 - 10 CFR 50.75(f)(1)
Plymouth, Massachussetts 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:
Entergy Nuclear Generation Co.: 100% ownership interest Plant Location: Plymouth, Massachussetts Reactor Type: Boiling Water Reactor ("BWR")
Generic Disposal Site 10CFR50.75(c)(2)
Power Level: <3,400 MWt (2028 MWt)
Escalation Factor Formula: 0.65(L) +0.13(E) +0.22(B)L=Labor (North)E=Energy (BWR)B=Waste Burial-Vendor (BWR)BWR Escalation Factor: 0.65(L) +0.13(E) +0.22(B)=1986 BWR Base Year $ Escalated:
BWR Base Year 1986$: $122,252,000 Labor Region: North Waste Burial Facility: Generic Disposal Site 10CFR50.75(c)(2) Escalation Factor Formula:
$122,252,000
0.65(L) +0.13(E) +0.22(B)
* Factor=Factor 2.511 2.6562 12.543 4.73412$578,755,570 1 2 3 Bureau of Labor Statistics, Series Report ID: CIU201000000021 Oi (4 th Quarter 2011)Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2011)Nuclear Regulatory Commission:
Factor L=Labor (North)                             2.511 E=Energy (BWR)                             2.6562 B=Waste Burial-Vendor (BWR)                 12.543 BWR Escalation Factor:
NUREG-1307 Revision 14, Table 2.1 (2010)6 Attachment 7 ENOC-12-0005 Entergy Nuclear Operations, Inc.IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31. 2011 -10 CFR 50.75(f)(1)
0.65(L) +0.13(E) +0.22(B)=                 4.73412 1986 BWR Base Year $ Escalated:
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).
    $122,252,000
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. ML1 00280544).
* Factor=                     $578,755,570 1
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 Indian Point 1 site-specific decommissioning cost estimate that was submitted was based on a period of safe storage that is specifically described in the estimate, namely storage until 2066, at which time the plant will be decommissioned and the site released for alternative use without restriction.
Bureau of Labor Statistics, Series Report ID: CIU201000000021 Oi (4 th Quarter 2011) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2011) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 14, Table 2.1 (2010) 6
Table 7 in the Indian Point 1 site-specific estimate (Accession No.ML083040378, page 34 of 36) provides the annual license termination phase expenditures for Indian Point 1 in 2007 dollars. Table 9-1 below escalates those 2007 dollar figures, excluding those costs expended to date and through the 3 rd quarter of 2013 which are funded by operations, to 2011 dollars using escalation values obtained from data provided by IHS Global Insight. 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).
 
7 Attachment 7 ENOC-12-0005 Entergy Nuclear Operations, Inc.1P1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 -10 CFR 50.75(f)(1)
Attachment 7 ENOC-12-0005 Entergy Nuclear Operations, Inc.
Table 9-1 NRC License Termination Cost ($ millions)2007 $ 2011 $ Ending DTF Unit 1 Unit 1 Balance Radiological Radiological 2011 300.761 2012 306.776 2013 1.059 1.150 311.761 2014 4.236 4.600 313.396 2015 4.236 4.600 315.064 2016 2.656 2.888 318.478 2017 2.649 2.880 321.967 2018 2.649 2.880 325.526 2019 2.649 2.880 329.157 2020 2.656 2.888 332.852 2021 2.649 2.880 336.629 2022 2.649 2.880 340.481 2023 2.649 2.880 344.411 2024 2.656 2.888 348.411 2025 2.649 2.880 352.499 2026 2.649 2.880 356.669 2027 2.649 2.880 360.922 2028 2.656 2.888 365.253 2029 2.649 2.880 369.678 2030 2.649 2.880 374.191 2031 2.649 2.880 378.795 2032 2.656 2.888 383.483 2033 2.649 2.880 388.272 2034 2.649 2.880 393.158 2035 2.649 2.880 398.141 2036 2.656 2.888 403.216 2037 2.649 2.880 408.400 2038 2.649 2.880 413.688 2039 2.649 2.880 419.081 2040 2.656 2.888 424.575 2041 2.649 2.880 430.186 2042 2.649 2.880 435.910 2043 2.649 2.880 441.748 8 Attachment 7 ENOC-12-0005 Entergy Nuclear Operations, Inc.IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Endina December 31. 2011 -10 CFR 50.75(f)(1)
IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31. 2011 - 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).
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 Indian Point 1 site-specific decommissioning cost estimate that was submitted was based on a period of safe storage that is specifically described in the estimate, namely storage until 2066, at which time the plant will be decommissioned and the site released for alternative use without restriction. Table 7 in the Indian Point 1 site-specific estimate (Accession No. ML083040378, page 34 of 36) provides the annual license termination phase expenditures for Indian Point 1 in 2007 dollars. Table 9-1 below escalates those 2007 dollar figures, excluding those costs expended to date and through the 3 rd quarter of 2013 which are funded by operations, to 2011 dollars using escalation values obtained from data provided by IHS Global Insight. 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).
7
 
Attachment 7 ENOC-12-0005 Entergy Nuclear Operations, Inc.
1P1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)
Table 9-1 NRC License Termination Cost
($ millions) 2007 $               2011 $       Ending DTF Unit 1               Unit 1         Balance Radiological         Radiological 2011                                                     300.761 2012                                                     306.776 2013                     1.059               1.150       311.761 2014                     4.236               4.600       313.396 2015                     4.236               4.600       315.064 2016                     2.656               2.888       318.478 2017                     2.649               2.880       321.967 2018                     2.649               2.880       325.526 2019                     2.649               2.880       329.157 2020                     2.656               2.888       332.852 2021                     2.649               2.880       336.629 2022                     2.649               2.880       340.481 2023                     2.649               2.880       344.411 2024                     2.656               2.888       348.411 2025                     2.649               2.880       352.499 2026                     2.649               2.880       356.669 2027                     2.649               2.880       360.922 2028                     2.656               2.888       365.253 2029                     2.649               2.880       369.678 2030                     2.649               2.880       374.191 2031                     2.649               2.880       378.795 2032                     2.656               2.888       383.483 2033                     2.649               2.880       388.272 2034                     2.649               2.880       393.158 2035                     2.649               2.880       398.141 2036                     2.656               2.888       403.216 2037                     2.649               2.880       408.400 2038                     2.649               2.880       413.688 2039                     2.649               2.880       419.081 2040                     2.656               2.888       424.575 2041                     2.649               2.880       430.186 2042                     2.649               2.880       435.910 2043                     2.649               2.880       441.748 8
 
Attachment 7 ENOC-12-0005 Entergy Nuclear Operations, Inc.
IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Endina December 31. 2011 - 10 CFR 50.75(f)(1)
Table 9-1 (continued)
Table 9-1 (continued)
NRC License Termination Cost ($ millions)2007$ 2011$Unit 1 Unit 1 Ending DTF Radiological  
NRC License Termination Cost
'Radiological Balance 2044 2.656 2.888 447.695 2045 2.611 2.839 453.810 2046 1.826 1.994 460.892 2047 1.826 1.994 468.116 2048 1.831 2.000 475.478 2049 1.826 1.994 482.994 2050 1.826 1.994 490.659 2051 1.826 1.994 498.478 2052 1.831 2.000 506.448 2053 1.826 1.994 514.583 2054 1.826 1.994 522.880 2055 1.826 1.994 531.343 2056 1.831 2.000 539.970 2057 1.826 1.994 548.776 2058 1.826 1.994 557.757 2059 1.826 1.994 566.918 2060 1.831 2.000 576.256 2061 1.826 1.994 585.787 2062 1.826 1.994 595.509 2063 1.826 1.994 605.425 2064 1.831 2.000 615.533 2065 1.826 1.994 625.850 2066 18.899 20.457 617.909 2067 68.313 73.335 556.933 2068 148.49 159.587 408.484 2069 17.216 18.613 398.042 2070 17.216 18.613 387.390 2071 17.216 18.613 376.525 2072 17.235 18.632 365.423 2073 11.4 12.299 360.432 Total 441.549 476.837 As can be seen from the information provided in Table 9-1, the required funding for SAFSTOR decommissioning, $476.837 million, is greater than the NRC formula amount per 10 CFR 50.75(b) and 1 (c) of $399.316 million, therefore, the site-specific analysis complies with the 9 Attachment 7 ENOC-12-0005 Entergy Nuclear Operations, Inc.IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 -10 CFR 50.75(f)(1) requirement from Regulatory Guide 1.159 section 1.1.1 previously discussed.
($ millions) 2007$                 2011$
The foregoing SAFSTOR analysis shows that when the December 31, 2011 DTF balance is escalated at the allowable rate and compared against the annual figures for the SAFSTOR period, that an approximately  
Unit 1               Unit 1           Ending DTF Radiological         'Radiological           Balance 2044                       2.656                 2.888           447.695 2045                       2.611                 2.839           453.810 2046                       1.826                 1.994           460.892 2047                       1.826                 1.994           468.116 2048                       1.831                 2.000           475.478 2049                       1.826                 1.994           482.994 2050                       1.826                 1.994           490.659 2051                       1.826                 1.994           498.478 2052                       1.831                 2.000           506.448 2053                       1.826                 1.994           514.583 2054                       1.826                 1.994           522.880 2055                       1.826                 1.994           531.343 2056                       1.831                 2.000           539.970 2057                       1.826                 1.994           548.776 2058                       1.826                 1.994           557.757 2059                       1.826                 1.994           566.918 2060                       1.831                 2.000           576.256 2061                       1.826                 1.994           585.787 2062                       1.826                 1.994           595.509 2063                       1.826                 1.994           605.425 2064                       1.831                 2.000           615.533 2065                       1.826                 1.994           625.850 2066                     18.899               20.457           617.909 2067                     68.313               73.335           556.933 2068                     148.49               159.587           408.484 2069                     17.216               18.613           398.042 2070                     17.216               18.613           387.390 2071                     17.216               18.613           376.525 2072                     17.235               18.632           365.423 2073                         11.4               12.299           360.432 Total                   441.549             476.837 As can be seen from the information provided in Table 9-1, the required funding for SAFSTOR decommissioning, $476.837 million, is greater than the NRC formula amount per 10 CFR 50.75(b) and 1(c) of $399.316 million, therefore, the site-specific analysis complies with the 9
$360.432 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 1.10 Attachment 8 ENOC-12-0005 Entergy Nuclear Operations, Inc.IP2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Endinq December 31, 2011 -10 CFR 50.75(f)(1)
 
On August 13, 2009, Entergy Nuclear Indian Point 2, LLC (ENIP2) submitted a decommissioning funding assurance plan for Indian Point Energy Center, Unit 2 (Indian Point 2)(Accession No. ML 092260720).
Attachment 7 ENOC-12-0005 Entergy Nuclear Operations, Inc.
The plan was in response to a projected decommissioning funding shortfall for ENIP2 and the subsequent need to describe how and when the licensee intends to make adjustments to its financial assurance mechanisms.
IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1) requirement from Regulatory Guide 1.159 section 1.1.1 previously discussed. The foregoing SAFSTOR analysis shows that when the December 31, 2011 DTF balance is escalated at the allowable rate and compared against the annual figures for the SAFSTOR period, that an approximately $360.432 million surplus exists at the end of the decommissioning project.
This attachment provides an update to the August 13, 2009 funding plan.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.On October 23, 2008, ENIP2 submitted a site specific decommissioning cost estimate to the NRC in conjunction with its preliminary decommissioning cost estimate, and 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).
Accordingly, ENIP2 concludes that no further action is required at this time to demonstrate adequate funding assurance for decommissioning Indian Point 1.
That submittal contained separate site-specific decommissioning cost estimates for Indian Point 1 and Indian Point 2. The Indian Point 2 site-specific decommissioning cost estimate that was submitted was based on a period of safe storage that is specifically described in the estimate, namely storage until 2064, at which time the plant will be decommissioned and the site released for alternative use without restriction.
10
Table 4 in the Indian Point 2 site-specific estimate (Accession No. ML083040378, page 31 of 38) provides the annual license termination phase expenditures for Indian Point 2 in 2007 dollars.On December 10, 2010, ENIP3 submitted a site specific decommissioning cost estimate to the NRC in conjunction with its preliminary decommissioning cost estimate, and spent fuel management plan under 10 CFR 50.75(f)(3) and 10 CFR 50.54(bb) (Accession Nos.ML103540233 and ML103550608).
 
In the ENIP3 estimate, the off-loading of the Indian Point 3 spent fuel storage pool was predicated on the availability of the Indian Point 2 spent fuel storage pool through the end of year 2023. This pool operating duration is 211/2 years longer than what was assumed in the original 2007 Indian Point 2 estimate.
Attachment 8 ENOC-12-0005 Entergy Nuclear Operations, Inc.
For consistency, the 2007 Indian Point 2 estimate has been revised for the longer pool operating duration.
IP2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Endinq December 31, 2011 - 10 CFR 50.75(f)(1)
This did not impact the 11 Attachment 8 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.IP2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 -10 CFR 50.75(f)(1) overall Indian Point 2 estimate schedule length. The revised cost (in 2007 dollars) accounting for the extended spent fuel pool operation is shown in Table 10-1 along with the original cost.Table 10-1 below escalates the revised 2007 dollar figures to 2011 dollars using escalation values obtained from data provided by IHS Global Insight. 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).
On August 13, 2009, Entergy Nuclear Indian Point 2, LLC (ENIP2) submitted a decommissioning funding assurance plan for Indian Point Energy Center, Unit 2 (Indian Point 2)
Table 10-1 below uses the December 31, 2011 balance and indicates that there is now a$165.028 million surplus in 2073 in decommissioning trust funds at the end of radiological decommissioning of Indian Point 2.12 Attachment 8 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.1P2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 -10 CFR 50.75(f)(1)
(Accession No. ML092260720). The plan was in response to a projected decommissioning funding shortfall for ENIP2 and the subsequent need to describe how and when the licensee intends to make adjustments to its financial assurance mechanisms. This attachment provides an update to the August 13, 2009 funding plan.
Table 10-1 NRC License Termination Cost ($ millions)2007$ 2007$ 2011$ Ending DTF Unit 2 Unit 2 Updated Unit 2 Balance Radiological Radiological Radiological 2011 392.365 2012 400.212 2013 11.164 11.164 12.199 396.018 2014 49.271 49.271 53.677 350.261 2015 25.307 25.307 27.439 329.828 2016 3.711 3.711 4.048 332.376 2017 3.701 3.701 4.037 334.986 2018 3.701 3.701 4.037 337.649 2019 3.701 3.701 4.037 340.365 2020 3.711 3.711 4.048 343.124 2021 3.688 3.701 4.037 345.949 2022 3.676 3.701 4.037 348.831 2023 3.676 3.701 4.037 351.771 2024 3.686 3.686 4.022 354.784 2025 3.676 3.676 4.011 357.869 2026 3.676 3.676 4.011 361.016 2027 3.676 3.676 4.011 364.225 2028 3.686 3.686 4.022 367.488 2029 3.676 3.676 4.011 370.827 2030 3.676 3.676 4.011 374.233 2031 3.676 3.676 4.011 377.707 2032 3.686 3.686 4.022 381.239 2033 3.676 3.676 4.011 384.853 2034 3.676 3.676 4.011 388.539 2035 3.676 3.676 4.011 392.299 2036 3.686 3.686 4.022 396.124 2037 3.676 3.676 4.011 400.035 2038 3.676 3.676 4.011 404.025 2039 3.676 3.676 4.011 408.095 2040 3.686 3.686 4.022 412.235 2041 3.676 3.676 4.011 416.469 2042 3.676 3.676 4.011 420.788 2043 3.676 3.676 4.011 425.192 2044 3.686 3.686 4.022 429.675 2045 3.675 3.676 4.011 434.257 2046 3.668 3.676 4.011 438.932 2047 3.668 3.675 4.010 443.700 2048 3.678 3.678 4.014 448.560 13 Attachment 8 ENOC-12-0005 Entergy Nuclear Operations, Inc.IP2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 -10 CFR 50.75(f)(1)
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.
On October 23, 2008, ENIP2 submitted a site specific decommissioning cost estimate to the NRC in conjunction with its preliminary decommissioning cost estimate, and 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). That submittal contained separate site-specific decommissioning cost estimates for Indian Point 1 and Indian Point 2. The Indian Point 2 site-specific decommissioning cost estimate that was submitted was based on a period of safe storage that is specifically described in the estimate, namely storage until 2064, at which time the plant will be decommissioned and the site released for alternative use without restriction. Table 4 in the Indian Point 2 site-specific estimate (Accession No. ML083040378, page 31 of 38) provides the annual license termination phase expenditures for Indian Point 2 in 2007 dollars.
On December 10, 2010, ENIP3 submitted a site specific decommissioning cost estimate to the NRC in conjunction with its preliminary decommissioning cost estimate, and spent fuel management plan under 10 CFR 50.75(f)(3) and 10 CFR 50.54(bb) (Accession Nos.
ML103540233 and ML103550608). In the ENIP3 estimate, the off-loading of the Indian Point 3 spent fuel storage pool was predicated on the availability of the Indian Point 2 spent fuel storage pool through the end of year 2023. This pool operating duration is 211/2 years longer than what was assumed in the original 2007 Indian Point 2 estimate. For consistency, the 2007 Indian Point 2 estimate has been revised for the longer pool operating duration. This did not impact the 11
 
Attachment 8 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.
IP2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1) overall Indian Point 2 estimate schedule length. The revised cost (in 2007 dollars) accounting for the extended spent fuel pool operation is shown in Table 10-1 along with the original cost.
Table 10-1 below escalates the revised 2007 dollar figures to 2011 dollars using escalation values obtained from data provided by IHS Global Insight. 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).
Table 10-1 below uses the December 31, 2011 balance and indicates that there is now a
$165.028 million surplus in 2073 in decommissioning trust funds at the end of radiological decommissioning of Indian Point 2.
12
 
Attachment 8 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.
1P2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)
Table 10-1 NRC License Termination Cost
($ millions) 2007$               2007$             2011$         Ending DTF Unit 2         Unit 2 Updated         Unit 2         Balance Radiological       Radiological       Radiological 2011                                                                         392.365 2012                                                                         400.212 2013                     11.164             11.164             12.199       396.018 2014                   49.271             49.271             53.677       350.261 2015                     25.307             25.307             27.439       329.828 2016                     3.711             3.711               4.048       332.376 2017                     3.701             3.701               4.037       334.986 2018                     3.701             3.701               4.037       337.649 2019                     3.701             3.701               4.037       340.365 2020                     3.711             3.711               4.048       343.124 2021                     3.688             3.701               4.037       345.949 2022                     3.676             3.701               4.037       348.831 2023                     3.676             3.701               4.037       351.771 2024                     3.686             3.686               4.022       354.784 2025                     3.676             3.676               4.011       357.869 2026                     3.676             3.676               4.011       361.016 2027                     3.676             3.676               4.011       364.225 2028                     3.686             3.686               4.022       367.488 2029                     3.676             3.676               4.011       370.827 2030                     3.676             3.676               4.011       374.233 2031                     3.676             3.676               4.011       377.707 2032                     3.686             3.686               4.022       381.239 2033                     3.676             3.676               4.011       384.853 2034                     3.676             3.676               4.011       388.539 2035                     3.676             3.676               4.011       392.299 2036                     3.686             3.686               4.022       396.124 2037                     3.676             3.676               4.011       400.035 2038                     3.676             3.676               4.011       404.025 2039                     3.676             3.676               4.011       408.095 2040                     3.686             3.686               4.022       412.235 2041                     3.676             3.676               4.011       416.469 2042                     3.676             3.676               4.011       420.788 2043                     3.676             3.676               4.011       425.192 2044                     3.686             3.686               4.022       429.675 2045                     3.675             3.676               4.011       434.257 2046                     3.668             3.676               4.011       438.932 2047                     3.668             3.675               4.010       443.700 2048                     3.678             3.678               4.014       448.560 13
 
Attachment 8 ENOC-12-0005 Entergy Nuclear Operations, Inc.
IP2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)
Table 10-1 (continued)
Table 10-1 (continued)
NRC License Termination Cost ($ millions)2007$ 2007$ 2011 $Unit 2 Unit 2 Updated Unit 2 Ending DTF Radiological Radiological Radiological Balance 2049 3.668 3.668 4.003 453.529 2050 3.668 3.668 4.003 458.597 2051 3.668 3.668 4.003 463.766 2052 3.678 3.678 4.014 469.028 2053 3.668 3.668 4.003 474.406 2054 3.668 3.668 4.003 479.891 2055 3.668 3.668 4.003 485.486 2056 3.678 3.678 4.014 491.182 2057 3.668 3.668 4.003 497.003 2058 3.668 3.668 4.003 502.941 2059 3.668 3.668 4.003 508.997 2060 3.678 3.678 4.014 515.163 2061 3.668 3.668 4.003 521.464 2062 3.668 3.668 4.003 527.890 2063 3.668 3.668 4.003 534.446 2064 24.751 24.751 27.041 518.094 2065 55.625 55.625 60.490 467.966 2066 168.560 168.560 181.862 295.463 2067 71.834 71.834 77.860 223.512 2068 25.113 25.113 27.237 200.745 2069 6.046 6.046 6.526 198.234 2070 6.046 6.046 6.526 195.673 2071 6.046 6.046 6.526 193.060 2072 6.547 6.547 7.067 189.855 2073 26.485 26.485 28.624 165.028 Total 659.351 659.430 715.803 1 14 Attachment 8 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.1P2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 -10 CFR 50.75(f)(1)
NRC License Termination Cost
As can be seen from the information provided in Table 10-1, the required funding for SAFSTOR decommissioning, $715.803 million, is greater than the NRC formula amount per 10 CFR 50.75(b) and 1(c) of $482.1 million, therefore, the site-specific analysis complies with the requirement from Regulatory Guide 1.159 section 1.1.1 previously discussed.
($ millions) 2007$                 2007$           2011 $
The foregoing SAFSTOR analysis shows that when the December 31, 2011 DTF balance is escalated at the allowable rate and compared against the annual figures for the SAFSTOR period, that an approximately  
Unit 2           Unit 2 Updated         Unit 2         Ending DTF Radiological         Radiological     Radiological       Balance 2049                     3.668               3.668             4.003         453.529 2050                     3.668               3.668             4.003         458.597 2051                     3.668               3.668             4.003         463.766 2052                     3.678               3.678             4.014         469.028 2053                     3.668               3.668             4.003         474.406 2054                     3.668               3.668             4.003         479.891 2055                     3.668               3.668             4.003         485.486 2056                     3.678               3.678             4.014         491.182 2057                     3.668               3.668             4.003         497.003 2058                     3.668               3.668             4.003         502.941 2059                     3.668               3.668             4.003         508.997 2060                     3.678               3.678             4.014         515.163 2061                     3.668               3.668             4.003         521.464 2062                     3.668               3.668             4.003         527.890 2063                     3.668               3.668             4.003         534.446 2064                     24.751               24.751             27.041         518.094 2065                     55.625               55.625             60.490         467.966 2066                   168.560               168.560           181.862         295.463 2067                     71.834               71.834             77.860         223.512 2068                     25.113               25.113             27.237         200.745 2069                     6.046               6.046             6.526         198.234 2070                     6.046               6.046             6.526         195.673 2071                     6.046               6.046             6.526         193.060 2072                     6.547               6.547             7.067         189.855 2073                     26.485               26.485             28.624         165.028 Total                 659.351               659.430           715.803 1 14
$165.028 million surplus exists at the end of the decommissioning project.Accordingly, ENIP2 concludes that no further action is required at this time to demonstrate adequate funding assurance for decommissioning Indian Point 2.15 Attachment 9 ENOC-12-0005 Entergy Nuclear Operations, Inc.Minimum Financial Assurance Calculation Worksheets Plant name: Indian Point, Unit 1 Day Year Year of Biennial: rermination of Operation Month 1 9 1 28 2012 2066 SAFSTOR Site Specific MWth 1986$ ECI BaseLxI I Px PWR 615 r $85,560,000 r 116.1 2.16 0.65 2.51 r 1.786 r 3.677 0.13 r 2.580 0.22 12.28 NRC Minimum:$399,316,126 Site Specific:$476,837,000 Amount of NRC Minimum/Site Licensee:  
 
% Owned: Specific:
Attachment 8 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.
Amount in Trust Fund: Entergy 100.00% 1 $476,837,000  
1P2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)
$300,760,655 Note: See Attachment 7 for adequacy of the trust fund 16 Attachment 9 ENOC-12-0005 Entergy Nuclear Operations, Inc.Minimum Financial Assurance Calculation Worksheets Plant name: Indian Point, Unit 2 Month Day Year Year of Biennial:
As can be seen from the information provided in Table 10-1, the required funding for SAFSTOR decommissioning, $715.803 million, is greater than the NRC formula amount per 10 CFR 50.75(b) and 1(c) of $482.1 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, 2011 DTF balance is escalated at the allowable rate and compared against the annual figures for the SAFSTOR period, that an approximately $165.028 million surplus exists at the end of the decommissioning project.
1 1 2012 rermination of Operation 9 28 2064 SAFSTOR Site Specific MWth j 1986$ ECI IBase Lx Li Px Fx Ex Bx PWR 3216 r$103,300,800 r 116.1 2.16 0.65 2.51 r 1.786 r 3.677 0.13 r 2.580 0.22 12.28 NRC Minimum: $482,114,017 Site Specific:  
Accordingly, ENIP2 concludes that no further action is required at this time to demonstrate adequate funding assurance for decommissioning Indian Point 2.
$715,803,Q000 Amount of NRC Minimum/Site Licensee:  
15
%Owned: Specific:
 
Amount in Trust Fund: Entergy 100.00% $715,803,000  
Attachment 9 ENOC-12-0005 Entergy Nuclear Operations, Inc.
$392,365,123 Note: See Attachment 8 for adequacy of the trust fund 17 Attachment 9 ENOC-12-0005 Entergy Nuclear Operations, Inc.Minimum Financial Assurance Calculation Worksheets Plant name: Year of Biennial: rermination of Operation Month 1 12 Day 1 12 Indian Point, Unit 3 Year 2012 2015 PW R MWth 1986$ ECI 3216 r$103,300,800?
Minimum Financial Assurance Calculation Worksheets Plant name:                                                     Indian Point, Unit 1 Month                Day               Year Year of Biennial:                   1                    1              2012 rermination of Operation                 9                   28               2066       SAFSTOR Site Specific MWth   1986$         ECI     BaseLxI                         Px                                I PWR         615 r $85,560,000 r 116.1       2.16       0.65     2.51 r 1.786 r 3.677     0.13 r 2.580 0.22   12.28 NRC Minimum:                     $399,316,126             Site Specific:         $476,837,000 Amount of NRC Minimum/Site Licensee:     % Owned:               Specific:               Amount in Trust Fund:
116.1 I Base Lx I Lx lI Px I Fx 1.786 3.677 1I I Ex 0.13 2.580 4-1 0.22 1 1x.I IL I 2.16 I 0.65 [2.51 r NRC Minimum:$482,114,017 Site Specific: I Licensee:  
Entergy         100.00%   1         $476,837,000                 $300,760,655 Note: See Attachment 7 for adequacy of the trust fund 16
%Owned: I Entergy 100.00% 1 Amount of NRC Minimum/Site Specific:$482,114,017 I Amount in Trust Fund:$521,161,624 I Step 1: Earnings Credit: Trust Fund Balance:$521,161,624 Real Rate of Return per 2%Years Leftl in Licensel 3.95 1 Total Real Rate of 1.08129 Total Eamings:$563,528,154
 
]Total Earnings = Trust Fund balance x (1+RRR)AYears left in license Step 2: Accumulation:
Attachment 9 ENOC-12-0005 Entergy Nuclear Operations, Inc.
Value of Annuity per year Real Rate of Return per 2%I.Years of Annuity: 0-A Total Annuity:$0 d Step 3: Decom Period: I Total Earnings:$563,528,154 t Real Rate of Return per 2%I Decom Period: 7 I Total Real Rate of 0.14869 Total Eamings for Decom:1$41,894,280 Total Earnings for Decom = (1/2) x Total Earnings x [(l+RRR)^Decom period -1]Total of Steps 1 -3: 1$605,422,433[Total  
Minimum Financial Assurance Calculation Worksheets Plant name:                                                     Indian Point, Unit 2 Month                 Day               Year Year of Biennial:                   1                     1                 2012 rermination of Operation                 9                   28                 2064         SAFSTOR Site Specific MWth j   1986$       ECI   IBase Lx                   Li       Px       Fx               Ex         Bx PWR       3216 r$103,300,800 r 116.1     2.16         0.65     2.51   r 1.786 r 3.677     0.13 r 2.580 0.22   12.28 NRC Minimum:                     $482,114,017             Site Specific:           $715,803,Q000 Amount of NRC Minimum/Site Licensee:       %Owned:               Specific:               Amount in Trust Fund:
= Total Earnings + Total Earnings for Decom lExcess (Shortfall)  
Entergy         100.00%             $715,803,000                   $392,365,123 Note: See Attachment 8 for adequacy of the trust fund 17
$123,308,417 to NRC minimum 18 Attachment 9 ENOC-12-0005 Entergy Nuclear Operations, Inc.Minimum Financial Assurance Calculation Worksheets Plant name: Year of Biennial: Fermination of Operation Pilgrim Month 1 6 Day 1 8 Year 2012 2012 BWR MWth 1 1986$2028 [$122,252,000r ECI Base Lx 116.1 2.16 Px I Fx I I Ex I I Ex l I I I-I 0.65 r 1.786 r 3.677 0.13 r 2.656 I 0.22 1 12.54 I NRC Minimum: Licensee:
 
% Owned: Entergy 100.00%$578,755,570 Site Specific: I.Amount of NRC Minimum/Site Specific:$578,755,570
Attachment 9 ENOC-12-0005 Entergy Nuclear Operations, Inc.
*I Step 1: Earnings Credit: Amount in Trust Fund:$676,657,808 H Total Earnings = Trust Fund balance x (1+RRR)AYears left in license Trust Fund Balance: I$676,657,808 1 Real Rate of Return per 2%Years Left in Licensel 0.44 1 Total Real Rate of 1.00867 I Total Earnings:$682,523,230 Step 2: Accumulation:
Minimum Financial Assurance Calculation Worksheets Plant name:                                                                         Indian Point, Unit 3 Month                        Day                        Year Year of Biennial:                           1                          1                        2012 rermination of Operation                       12                         12                         2015 LxlI PW R MWth 3216 1986$
Value of Annuity per year$0 Real Rate of Return per 2%Years of Annuity: 0 I1--Total Annuity:$0-d Step 3: Decom Period: Real Rate of Total Earnings:
r$103,300,800?
Return per$682,523,230 1 2%I Decorn Period: 7-p Total Real Rate of 0.14869 I Total Earnings for Decom:$50,740,711 ITotal Earnings for Decom = (1/2) x Total Earnings x [(l+RRR)ADecom period -1]Total of Steps 1 -3: 1$733,263,941 Total = Total Earnings + Total Earnings for Decom Excess (Shortfall) 154,508,371 to NRC minimum 19}}
ECI 116.1 I
I I
Base Lx 2.16 I
IL I     0.65      [  2.51  r Px 1.786 I  Fx 3.677 1I 4- 0.13 I  Ex 2.580       0.22 1
1 1x.
NRC Minimum:                            $482,114,017                         Site Specific:
I Amount of NRC Minimum/Site I
I    Licensee:
Entergy
                        %Owned:
100.00%    1 Specific:
                                                    $482,114,017 Amount in Trust Fund:
                                                                                              $521,161,624             I Step 1:
Earnings Credit:
Real Rate of Years Leftl Total Real Trust Fund Balance:     Return per in Licensel      Rate of          Total Eamings:
    $521,161,624             2%         3.95 1 1.08129               $563,528,154     ]Total Earnings = Trust Fund balance x (1+RRR)AYears left in license Step 2:
Accumulation:
Value of Annuity per year Step 3:
Real Rate of Return per 2%     I. Years of Annuity:
0           -A     Total Annuity:
                                                                            $0         d Decom Period:
t I I Real Rate of  Decom      Total Real I Total Earnings:
    $563,528,154 Return per 2%
Period:
7 Rate of 0.14869 Total Eamings for Decom:1
                                                                      $41,894,280         Total Earnings for Decom = (1/2) x Total Earnings x [(l+RRR)^Decom period - 1]
Total of Steps 1 - 3: 1
                                                                      $605,422,433[Total = Total Earnings + Total Earnings for Decom lExcess (Shortfall)         $123,308,417 to NRC minimum 18
 
Attachment 9 ENOC-12-0005 Entergy Nuclear Operations, Inc.
Minimum Financial Assurance Calculation Worksheets Plant name:                                                                                 Pilgrim Month                            Day                            Year Year of Biennial:                         1                              1                            2012 Fermination of Operation                       6                             8                           2012 BWR MWth 2028 1   1986$
[$122,252,000r ECI 116.1 Base Lx 2.16               0.65         r Px 1.786 I
r Fx 3.677 I
I Ex II 0.13 I r 2.656 II Exl -I 0.22 1 12.54 I I
NRC Minimum:                               $578,755,570                             Site Specific:
I. Licensee:
Entergy Step 1:
                        % Owned:
100.00%
Amount of NRC Minimum/Site Specific:
                                                      $578,755,570                   *I Amount in Trust Fund:
                                                                                              $676,657,808 Earnings Credit:
I Real Rate of Years Left Total Real I
Trust Fund Balance:
    $676,657,808     1 Return per in Licensel 2%
Rate of 0.44 1 1.00867 Total Earnings:
                                                                        $682,523,230    H      Total Earnings = Trust Fund balance x (1+RRR)AYears left in license Step 2:
Accumulation:
Value of Annuity per  Real Rate of year
          $0 Return per 2%
Years of Annuity:
0 I1--
Total Annuity:
                                                                              $0        -d Step 3:
Decom Period:
Real Rate of
                                              -p I                                            ITotal Decorn      Total Real I Total Earnings:
    $682,523,230     1 Return per 2%
Period:
7 Rate of 0.14869 Total Earnings for Decom:
                                                                          $50,740,711                 Earnings for Decom = (1/2) x Total Earnings x [(l+RRR)ADecom period -1]
Total of Steps 1 - 3:     1
                                                                        $733,263,941           Total = Total Earnings + Total Earnings for Decom Excess (Shortfall)                 154,508,371           to NRC minimum 19}}

Latest revision as of 17:29, 6 February 2020

Status of Decommissioning Funding for Year Ending December 31, 2011
ML12093A382
Person / Time
Site: Indian Point, Pilgrim  Entergy icon.png
Issue date: 03/30/2012
From: Mccann J
Entergy Nuclear Operations
To:
Document Control Desk, NRC/FSME
References
ENOC-12-0005, FOIA/PA-2013-0151
Download: ML12093A382 (22)
v • d • e


Text

'Entergy Entergy Nuclear Operations, Inc.

440 Hamilton Avenue White Plains, New York 10601 Tel 914-272-3370 John F. McCann Vice President, Nuclear Safety, Emergency Planning and Licensing March 30, 2012 ENOC-1 2-0005 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001

SUBJECT:

Status of Decommissioning Funding for Plants Operated by Entergy Nuclear Operations, Inc.

For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)

Entergy Nuclear Operations, Inc.

Indian Point Nuclear Generating Stations 1, 2 and 3 Docket Nos. 50-3, 50-247 and 50-286 Pilgrim Nuclear Power Station Docket No. 50-293

REFERENCES:

1. NUREG-1307, "Report on Waste Burial Charges," Revision 14, dated November 2010.
2. NRC Regulatory Issue Summary 2001-07, "10 CFR 50.75(f)(1) Reports on the Status of Decommissioning Funds (Due March 31, 2001)."

Dear Sir or Madam:

10 CFR 50.75(f)(1) requires each power reactor licensee to report to the NRC by March 31 of each year the status of its decommissioning funding for each reactor or share of a reactor that it owns that is within 5 years of the end of its current operating license or where conditions have changed so that it will close within 5 years. On behalf of Entergy Nuclear Indian Point 2 LLC, Entergy Nuclear Indian Point 3 LLC and Entergy Nuclear Generation Company (Pilgrim Station), 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 6, respectively, were prepared in accordance with NUREG-1307 (Reference 1) and NRC Regulatory Issue Summary 2001-07 (Reference 2). Attachments 7 and 8 are updated site specific decommissioning cost estimates for IP 1 and 2. Attachment 9 includes Minimum Funding Assurance calculation worksheets for the plants (derived from LIC-205 Revision 4), provided for the convenience of the reviewer.

On March 21, 2011, the Nuclear Regulatory Commission issued a renewed license for the Vermont Yankee Nuclear Power Station (Vermont Yankee), so that the operating license now expires on March 21, 2032. The licensee does not have plans to close Vermont Yankee within 5 years. Accordingly, Entergy Nuclear Operations, Inc. is not including herewith a report pursuant to 10 CFR 50.75(f)(1) for Vermont Yankee.

I A

ENOC-12-0005 The aforementioned worksheets, using the December 31, 2011 trust fund balances indicate that all of the plants covered by this submittal met or exceeded the NRC's funding requirements.

There are no new commitments made in this letter. If you have any questions, please contact Mr. Bryan Ford at 601-368-5516.

Sincerely, Attachments: As described above cc: See next page.

2

ENOC-12-0005 cc: All Below with Attachments Mr. J. A. Aluise (ENT)

Mr. M. A. Balduzzi (ECH)

Ms. W. C. Curry (ECH)

Mr. B. E. Green (TMBR)

Mr. J. F. McCann (WPO)

Mr. J. E. Pollock (IPEC)

Mr. L. Jager Smith (ECH)

Mr. R. G. Smith (PNP)

USNRC Regional Administrator, Region I USNRC Regional Administrator, Region III USNRC Project Manager, Indian Point 1 USNRC Project Manager, Indian Point 2 USNRC Project Manager, Indian Point 3 USNRC Project Manager, Pilgrim USNRC Resident Inspector, Indian Point 2 USNRC Resident Inspector, Indian Point 3 USNRC Resident Inspector, Pilgrim Michigan Department of Environmental Quality Michigan Public Service Commission Ms. Elizabeth Miller, Commissioner VT Department of Public Service 120 State Street - Drawer 20 Montpelier, VT 05602 Ms. Bridget Frymire NYS Department of Public Service 3 Empire State Plaza Albany, NY 12223 Ms. Nancy S. Malmquist Downs Rachlin Martin PLLC PO Box 99 St. Johnsbury, VT 05819-0099 3

Attachment 1 ENOC-12-0005 Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding - Indian Point 1 For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)

Plant Name: Indian Point Nuclear Generating Unit No. 1

1. Minimum Financial Assurance (MFA) $ 476.84 million

[Note]

estimated per 10 CFR 50.75(b) and (c) (2011$)

2. Decommissioning Trust Fund Total $ 300.76 million as of 12/31/11
3. A schedule of the annual amounts remaining to be collected None
4. Assumptions used in determining rates of escalation in 2% annual real rate decommissioning costs, rates of earnings on decommissioning of return per 10 funds, and rates of other factors used in funding projections CFR 50.75(e)(1)(i)
5. Any contracts upon which the licensee is relying pursuant to 10 None CFR 50.75(e)(1)(v)
6. Modifications occurring to a licensee's current method of providing None financial assurance since the last submitted report
7. Any material changes to trust agreements None Note: 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 7. (Calculation of the NRC Minimum Amount is provided in Attachment 4.)

1

Attachment 2 ENOC-12-0005 Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding - Indian Point 2 For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)

Plant Name: Indian Point Nuclear Generating Unit No. 2

1. Minimum Financial Assurance (MFA) $ 715.80 million

[Note 1]

estimated per 10 CFR 50.75(b) and (c) (2011$)

$ 392.37 million

2. Decommissioning Trust Fund Total as of 12/31/11 [Note 2]
3. A schedule of the annual amounts remaining to be collected None
4. Assumptions used in determining rates of escalation in 2% annual real rate decommissioning costs, rates of earnings on decommissioning of return per 10 funds, and rates of other factors used in funding projections CFR 50.75(e)(1)(i)
5. Any contracts upon which the licensee is relying pursuant to 10 None CFR 50.75(e)(1)(v)
6. Modifications occurring to a licensee's current method of providing None financial assurance since the last submitted report
7. 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 8. (Calculation of the NRC Minimum Amount is provided in Attachment 4.)

Note 2:lncludes provisional fund balance of $31.05 million.

2

Attachment 3 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding - Indian Point 3 For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)

Plant Name: Indian Point Nuclear Generating Unit No. 3

1. Minimum Financial Assurance (MFA) $ 482.11 million

[Note]

estimated per 10 CFR 50.75(b) and (c) (2011$)

2. Decommissioning Trust Fund Total $ 521.16 million as of 12/31/11
3. A schedule of the annual amounts remaining to be collected None
4. Assumptions used in determining rates of escalation in 2% annual real rate decommissioning costs, rates of earnings on decommissioning of return per 10 funds, and rates of other factors used in funding projections CFR 50.75(e)(1)(i)
5. Any contracts upon which the licensee is relying pursuant to 10 None CFR 50.75(e)(1)(v)
6. Modifications occurring to a licensee's current method of providing None financial assurance since the last submitted report
7. Any material changes to trust agreements None Note: Calculation of the NRC Minimum Amount is provided in Attachment 4.

3

Attachment 4 ENOC-12-0005 Entergy Nuclear Operations, Inc.

Calculation of Minimum Amount - Indian Point For Year Endina December 31. 2011 - 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) 2.511 E=Energy (PWR) 2.582 B=Waste Burial-Vendor (PWR) 12.283 PWR Escalation Factor:

0.65(L) +0.13(E) +0.22(B)= 4.6670889 1986 PWR Base Year $ Escalated:

Indian Point 1: $85,560,000

  • Factor= $399,316,126 Indian Point 2 & 3: $103,300,800
  • Factor= $482,114,017 1

Bureau of Labor Statistics, Series Report ID: CIU201000000021 0i (4 th Quarter 2011) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2011) 3 Nuclear Regulatory Commission: NUREG-1 307 Revision 14, Table 2.1 (2010) 4

Attachment 5 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.

Status of Decommissioning Funding - Pilgrim For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)

Plant Name: Pilgrim Nuclear Power Station

1. Minimum Financial Assurance (MFA) $ 578.76 million [Note]

estimated per 10 CFR 50.75(b) and (c) (2011$)

2. Decommissioning Trust Fund Total $ 676.66 million as of 12/31/11
3. A schedule of the annual amounts remaining to be collected None
4. 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
5. Any contracts upon which the licensee is relying pursuant to 10 None CFR 50.75(e)(1)(v)
6. Modifications occurring to a licensee's current method of None providing financial assurance since the last submitted report
7. Any material changes to trust agreements None Note: Calculation of the NRC Minimum Amount is provided in Attachment 6.

5

Attachment 6 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.

Calculation of Minimum Amount - Pilgrim For Year Endinc December 31. 2011 - 10 CFR 50.75(f)(1)

Entergy Nuclear Generation Co.: 100% ownership interest Plant Location: Plymouth, Massachussetts 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) 2.511 E=Energy (BWR) 2.6562 B=Waste Burial-Vendor (BWR) 12.543 BWR Escalation Factor:

0.65(L) +0.13(E) +0.22(B)= 4.73412 1986 BWR Base Year $ Escalated:

$122,252,000

  • Factor= $578,755,570 1

Bureau of Labor Statistics, Series Report ID: CIU201000000021 Oi (4 th Quarter 2011) 2 Bureau of Labor Statistics, Series Report ID: wpu0543 and wpu0573 (December 2011) 3 Nuclear Regulatory Commission: NUREG-1307 Revision 14, Table 2.1 (2010) 6

Attachment 7 ENOC-12-0005 Entergy Nuclear Operations, Inc.

IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31. 2011 - 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).

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 § 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 Indian Point 1 site-specific decommissioning cost estimate that was submitted was based on a period of safe storage that is specifically described in the estimate, namely storage until 2066, at which time the plant will be decommissioned and the site released for alternative use without restriction. Table 7 in the Indian Point 1 site-specific estimate (Accession No. ML083040378, page 34 of 36) provides the annual license termination phase expenditures for Indian Point 1 in 2007 dollars. Table 9-1 below escalates those 2007 dollar figures, excluding those costs expended to date and through the 3 rd quarter of 2013 which are funded by operations, to 2011 dollars using escalation values obtained from data provided by IHS Global Insight. 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).

7

Attachment 7 ENOC-12-0005 Entergy Nuclear Operations, Inc.

1P1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)

Table 9-1 NRC License Termination Cost

($ millions) 2007 $ 2011 $ Ending DTF Unit 1 Unit 1 Balance Radiological Radiological 2011 300.761 2012 306.776 2013 1.059 1.150 311.761 2014 4.236 4.600 313.396 2015 4.236 4.600 315.064 2016 2.656 2.888 318.478 2017 2.649 2.880 321.967 2018 2.649 2.880 325.526 2019 2.649 2.880 329.157 2020 2.656 2.888 332.852 2021 2.649 2.880 336.629 2022 2.649 2.880 340.481 2023 2.649 2.880 344.411 2024 2.656 2.888 348.411 2025 2.649 2.880 352.499 2026 2.649 2.880 356.669 2027 2.649 2.880 360.922 2028 2.656 2.888 365.253 2029 2.649 2.880 369.678 2030 2.649 2.880 374.191 2031 2.649 2.880 378.795 2032 2.656 2.888 383.483 2033 2.649 2.880 388.272 2034 2.649 2.880 393.158 2035 2.649 2.880 398.141 2036 2.656 2.888 403.216 2037 2.649 2.880 408.400 2038 2.649 2.880 413.688 2039 2.649 2.880 419.081 2040 2.656 2.888 424.575 2041 2.649 2.880 430.186 2042 2.649 2.880 435.910 2043 2.649 2.880 441.748 8

Attachment 7 ENOC-12-0005 Entergy Nuclear Operations, Inc.

IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Endina December 31. 2011 - 10 CFR 50.75(f)(1)

Table 9-1 (continued)

NRC License Termination Cost

($ millions) 2007$ 2011$

Unit 1 Unit 1 Ending DTF Radiological 'Radiological Balance 2044 2.656 2.888 447.695 2045 2.611 2.839 453.810 2046 1.826 1.994 460.892 2047 1.826 1.994 468.116 2048 1.831 2.000 475.478 2049 1.826 1.994 482.994 2050 1.826 1.994 490.659 2051 1.826 1.994 498.478 2052 1.831 2.000 506.448 2053 1.826 1.994 514.583 2054 1.826 1.994 522.880 2055 1.826 1.994 531.343 2056 1.831 2.000 539.970 2057 1.826 1.994 548.776 2058 1.826 1.994 557.757 2059 1.826 1.994 566.918 2060 1.831 2.000 576.256 2061 1.826 1.994 585.787 2062 1.826 1.994 595.509 2063 1.826 1.994 605.425 2064 1.831 2.000 615.533 2065 1.826 1.994 625.850 2066 18.899 20.457 617.909 2067 68.313 73.335 556.933 2068 148.49 159.587 408.484 2069 17.216 18.613 398.042 2070 17.216 18.613 387.390 2071 17.216 18.613 376.525 2072 17.235 18.632 365.423 2073 11.4 12.299 360.432 Total 441.549 476.837 As can be seen from the information provided in Table 9-1, the required funding for SAFSTOR decommissioning, $476.837 million, is greater than the NRC formula amount per 10 CFR 50.75(b) and 1(c) of $399.316 million, therefore, the site-specific analysis complies with the 9

Attachment 7 ENOC-12-0005 Entergy Nuclear Operations, Inc.

IP1 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1) requirement from Regulatory Guide 1.159 section 1.1.1 previously discussed. The foregoing SAFSTOR analysis shows that when the December 31, 2011 DTF balance is escalated at the allowable rate and compared against the annual figures for the SAFSTOR period, that an approximately $360.432 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.

10

Attachment 8 ENOC-12-0005 Entergy Nuclear Operations, Inc.

IP2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Endinq December 31, 2011 - 10 CFR 50.75(f)(1)

On August 13, 2009, Entergy Nuclear Indian Point 2, LLC (ENIP2) submitted a decommissioning funding assurance plan for Indian Point Energy Center, Unit 2 (Indian Point 2)

(Accession No. ML092260720). The plan was in response to a projected decommissioning funding shortfall for ENIP2 and the subsequent need to describe how and when the licensee intends to make adjustments to its financial assurance mechanisms. This attachment provides an update to the August 13, 2009 funding plan.

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 § 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.

On October 23, 2008, ENIP2 submitted a site specific decommissioning cost estimate to the NRC in conjunction with its preliminary decommissioning cost estimate, and 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). That submittal contained separate site-specific decommissioning cost estimates for Indian Point 1 and Indian Point 2. The Indian Point 2 site-specific decommissioning cost estimate that was submitted was based on a period of safe storage that is specifically described in the estimate, namely storage until 2064, at which time the plant will be decommissioned and the site released for alternative use without restriction. Table 4 in the Indian Point 2 site-specific estimate (Accession No. ML083040378, page 31 of 38) provides the annual license termination phase expenditures for Indian Point 2 in 2007 dollars.

On December 10, 2010, ENIP3 submitted a site specific decommissioning cost estimate to the NRC in conjunction with its preliminary decommissioning cost estimate, and spent fuel management plan under 10 CFR 50.75(f)(3) and 10 CFR 50.54(bb) (Accession Nos.

ML103540233 and ML103550608). In the ENIP3 estimate, the off-loading of the Indian Point 3 spent fuel storage pool was predicated on the availability of the Indian Point 2 spent fuel storage pool through the end of year 2023. This pool operating duration is 211/2 years longer than what was assumed in the original 2007 Indian Point 2 estimate. For consistency, the 2007 Indian Point 2 estimate has been revised for the longer pool operating duration. This did not impact the 11

Attachment 8 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.

IP2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1) overall Indian Point 2 estimate schedule length. The revised cost (in 2007 dollars) accounting for the extended spent fuel pool operation is shown in Table 10-1 along with the original cost.

Table 10-1 below escalates the revised 2007 dollar figures to 2011 dollars using escalation values obtained from data provided by IHS Global Insight. 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).

Table 10-1 below uses the December 31, 2011 balance and indicates that there is now a

$165.028 million surplus in 2073 in decommissioning trust funds at the end of radiological decommissioning of Indian Point 2.

12

Attachment 8 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.

1P2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)

Table 10-1 NRC License Termination Cost

($ millions) 2007$ 2007$ 2011$ Ending DTF Unit 2 Unit 2 Updated Unit 2 Balance Radiological Radiological Radiological 2011 392.365 2012 400.212 2013 11.164 11.164 12.199 396.018 2014 49.271 49.271 53.677 350.261 2015 25.307 25.307 27.439 329.828 2016 3.711 3.711 4.048 332.376 2017 3.701 3.701 4.037 334.986 2018 3.701 3.701 4.037 337.649 2019 3.701 3.701 4.037 340.365 2020 3.711 3.711 4.048 343.124 2021 3.688 3.701 4.037 345.949 2022 3.676 3.701 4.037 348.831 2023 3.676 3.701 4.037 351.771 2024 3.686 3.686 4.022 354.784 2025 3.676 3.676 4.011 357.869 2026 3.676 3.676 4.011 361.016 2027 3.676 3.676 4.011 364.225 2028 3.686 3.686 4.022 367.488 2029 3.676 3.676 4.011 370.827 2030 3.676 3.676 4.011 374.233 2031 3.676 3.676 4.011 377.707 2032 3.686 3.686 4.022 381.239 2033 3.676 3.676 4.011 384.853 2034 3.676 3.676 4.011 388.539 2035 3.676 3.676 4.011 392.299 2036 3.686 3.686 4.022 396.124 2037 3.676 3.676 4.011 400.035 2038 3.676 3.676 4.011 404.025 2039 3.676 3.676 4.011 408.095 2040 3.686 3.686 4.022 412.235 2041 3.676 3.676 4.011 416.469 2042 3.676 3.676 4.011 420.788 2043 3.676 3.676 4.011 425.192 2044 3.686 3.686 4.022 429.675 2045 3.675 3.676 4.011 434.257 2046 3.668 3.676 4.011 438.932 2047 3.668 3.675 4.010 443.700 2048 3.678 3.678 4.014 448.560 13

Attachment 8 ENOC-12-0005 Entergy Nuclear Operations, Inc.

IP2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)

Table 10-1 (continued)

NRC License Termination Cost

($ millions) 2007$ 2007$ 2011 $

Unit 2 Unit 2 Updated Unit 2 Ending DTF Radiological Radiological Radiological Balance 2049 3.668 3.668 4.003 453.529 2050 3.668 3.668 4.003 458.597 2051 3.668 3.668 4.003 463.766 2052 3.678 3.678 4.014 469.028 2053 3.668 3.668 4.003 474.406 2054 3.668 3.668 4.003 479.891 2055 3.668 3.668 4.003 485.486 2056 3.678 3.678 4.014 491.182 2057 3.668 3.668 4.003 497.003 2058 3.668 3.668 4.003 502.941 2059 3.668 3.668 4.003 508.997 2060 3.678 3.678 4.014 515.163 2061 3.668 3.668 4.003 521.464 2062 3.668 3.668 4.003 527.890 2063 3.668 3.668 4.003 534.446 2064 24.751 24.751 27.041 518.094 2065 55.625 55.625 60.490 467.966 2066 168.560 168.560 181.862 295.463 2067 71.834 71.834 77.860 223.512 2068 25.113 25.113 27.237 200.745 2069 6.046 6.046 6.526 198.234 2070 6.046 6.046 6.526 195.673 2071 6.046 6.046 6.526 193.060 2072 6.547 6.547 7.067 189.855 2073 26.485 26.485 28.624 165.028 Total 659.351 659.430 715.803 1 14

Attachment 8 ENOC-1 2-0005 Entergy Nuclear Operations, Inc.

1P2 DTF Balance Based on Decommissioning Funding Assurance Plan For Year Ending December 31, 2011 - 10 CFR 50.75(f)(1)

As can be seen from the information provided in Table 10-1, the required funding for SAFSTOR decommissioning, $715.803 million, is greater than the NRC formula amount per 10 CFR 50.75(b) and 1(c) of $482.1 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, 2011 DTF balance is escalated at the allowable rate and compared against the annual figures for the SAFSTOR period, that an approximately $165.028 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 2.

15

Attachment 9 ENOC-12-0005 Entergy Nuclear Operations, Inc.

Minimum Financial Assurance Calculation Worksheets Plant name: Indian Point, Unit 1 Month Day Year Year of Biennial: 1 1 2012 rermination of Operation 9 28 2066 SAFSTOR Site Specific MWth 1986$ ECI BaseLxI Px I PWR 615 r $85,560,000 r 116.1 2.16 0.65 2.51 r 1.786 r 3.677 0.13 r 2.580 0.22 12.28 NRC Minimum: $399,316,126 Site Specific: $476,837,000 Amount of NRC Minimum/Site Licensee:  % Owned: Specific: Amount in Trust Fund:

Entergy 100.00% 1 $476,837,000 $300,760,655 Note: See Attachment 7 for adequacy of the trust fund 16

Attachment 9 ENOC-12-0005 Entergy Nuclear Operations, Inc.

Minimum Financial Assurance Calculation Worksheets Plant name: Indian Point, Unit 2 Month Day Year Year of Biennial: 1 1 2012 rermination of Operation 9 28 2064 SAFSTOR Site Specific MWth j 1986$ ECI IBase Lx Li Px Fx Ex Bx PWR 3216 r$103,300,800 r 116.1 2.16 0.65 2.51 r 1.786 r 3.677 0.13 r 2.580 0.22 12.28 NRC Minimum: $482,114,017 Site Specific: $715,803,Q000 Amount of NRC Minimum/Site Licensee: %Owned: Specific: Amount in Trust Fund:

Entergy 100.00% $715,803,000 $392,365,123 Note: See Attachment 8 for adequacy of the trust fund 17

Attachment 9 ENOC-12-0005 Entergy Nuclear Operations, Inc.

Minimum Financial Assurance Calculation Worksheets Plant name: Indian Point, Unit 3 Month Day Year Year of Biennial: 1 1 2012 rermination of Operation 12 12 2015 LxlI PW R MWth 3216 1986$

r$103,300,800?

ECI 116.1 I

I I

Base Lx 2.16 I

IL I 0.65 [ 2.51 r Px 1.786 I Fx 3.677 1I 4- 0.13 I Ex 2.580 0.22 1

1 1x.

NRC Minimum: $482,114,017 Site Specific:

I Amount of NRC Minimum/Site I

I Licensee:

Entergy

%Owned:

100.00% 1 Specific:

$482,114,017 Amount in Trust Fund:

$521,161,624 I Step 1:

Earnings Credit:

Real Rate of Years Leftl Total Real Trust Fund Balance: Return per in Licensel Rate of Total Eamings:

$521,161,624 2% 3.95 1 1.08129 $563,528,154 ]Total Earnings = Trust Fund balance x (1+RRR)AYears left in license Step 2:

Accumulation:

Value of Annuity per year Step 3:

Real Rate of Return per 2% I. Years of Annuity:

0 -A Total Annuity:

$0 d Decom Period:

t I I Real Rate of Decom Total Real I Total Earnings:

$563,528,154 Return per 2%

Period:

7 Rate of 0.14869 Total Eamings for Decom:1

$41,894,280 Total Earnings for Decom = (1/2) x Total Earnings x [(l+RRR)^Decom period - 1]

Total of Steps 1 - 3: 1

$605,422,433[Total = Total Earnings + Total Earnings for Decom lExcess (Shortfall) $123,308,417 to NRC minimum 18

Attachment 9 ENOC-12-0005 Entergy Nuclear Operations, Inc.

Minimum Financial Assurance Calculation Worksheets Plant name: Pilgrim Month Day Year Year of Biennial: 1 1 2012 Fermination of Operation 6 8 2012 BWR MWth 2028 1 1986$

[$122,252,000r ECI 116.1 Base Lx 2.16 0.65 r Px 1.786 I

r Fx 3.677 I

I Ex II 0.13 I r 2.656 II Exl -I 0.22 1 12.54 I I

NRC Minimum: $578,755,570 Site Specific:

I. Licensee:

Entergy Step 1:

% Owned:

100.00%

Amount of NRC Minimum/Site Specific:

$578,755,570 *I Amount in Trust Fund:

$676,657,808 Earnings Credit:

I Real Rate of Years Left Total Real I

Trust Fund Balance:

$676,657,808 1 Return per in Licensel 2%

Rate of 0.44 1 1.00867 Total Earnings:

$682,523,230 H Total Earnings = Trust Fund balance x (1+RRR)AYears left in license Step 2:

Accumulation:

Value of Annuity per Real Rate of year

$0 Return per 2%

Years of Annuity:

0 I1--

Total Annuity:

$0 -d Step 3:

Decom Period:

Real Rate of

-p I ITotal Decorn Total Real I Total Earnings:

$682,523,230 1 Return per 2%

Period:

7 Rate of 0.14869 Total Earnings for Decom:

$50,740,711 Earnings for Decom = (1/2) x Total Earnings x [(l+RRR)ADecom period -1]

Total of Steps 1 - 3: 1

$733,263,941 Total = Total Earnings + Total Earnings for Decom Excess (Shortfall) 154,508,371 to NRC minimum 19

Retrieved from "https://kanterella.com/w/index.php?title=ML12093A382&oldid=2463224"