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| | number = ML092120165 | | | number = ML092220037 |
| | issue date = 07/29/2009 | | | issue date = 07/29/2009 |
| | title = Decommissioning Funding Assurance Plan | | | title = Decommissioning Funding Assurance Plan |
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| {{#Wiki_filter:Exelon Nuclear www.exeloncorp.co m 4300 Winfield Road Warrenville, f L 60555 RS-09-095 July 29, 2009 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Braidwood Station, Units 1 and 2 Facility Operating License Nos. NPF-72 and NPF-77 NRC Docket Nos. STN 50-456 and STN 50-457 Byron Station, Units 1 and 2 Facility Operating License Nos. NPF-37 and NPF-66 NRC Docket Nos. STN 50-454 and STN 50-455 Clinton Power Station Facility Operating License No. NPF-62 NRC Docket No. 50-461 LaSalle County Station, Units 1 and 2 Facility Operating License Nos. NPF-11 and NPF-18 NRC Docket Nos. 50-373 and 50-374 | | {{#Wiki_filter:Exel' n Exelon Nuclear www.exeloncorp.com Nuclear 4300 Winfield Road Warrenville, IL 60555 10 CFR 50.75(f)(1) |
| | RS-09-095 July 29, 2009 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Braidwood Station, Units 1 and 2 Facility Operating License Nos. NPF-72 and NPF-77 NRC Docket Nos. STN 50-456 and STN 50-457 Byron Station, Units 1 and 2 Facility Operating License Nos. NPF-37 and NPF-66 NRC Docket Nos. STN 50-454 and STN 50-455 Clinton Power Station Facility Operating License No. NPF-62 NRC Docket No. 50-461 LaSalle County Station, Units 1 and 2 Facility Operating License Nos. NPF-11 and NPF-18 NRC Docket Nos. 50-373 and 50-374 |
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| ==Subject:== | | ==Subject:== |
| Decommissioning Funding Assurance Plan References | | Decommissioning Funding Assurance Plan |
| : See Attachment 1 Exelon. Nuclear 10 CFR 50.75(f)(1)
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| In References 1 through 7, the NRC stated that they believe additional information is needed to demonstrate decommissioning funding assurance for Braidwood Station, Units 1 and 2, Byron Station, Units 1 and 2, Clinton Power Station, and LaSalle County Station, Units 1 and 2. The NBC's position was based on an internal review using the generic decommissioning funding assurance formula from 10 CFR 50.75(c), and the decommissioning trust fund values as of December 31, 2008, as reported by Exelon Generation Company, LLC (EGC) in Reference | | ==References:== |
| : 8. As requested in References 1 through 7, and a subsequent conference call between EGC and the NRC on July 1, 2009, EGC agreed to submit a plan by July 31, 2009, to show adequate decommissioning funding assurance. The plan to show adequate decommissioning July 29, 2009 U.S. Nuclear Regulatory Commission Page 2 funding assurance is described below. The actions detailed in the plan are summarized in Attachment | | |
| : 2. Braidwood Station, Units 1 and 2, Bvron Station, Units 1 and 2 On March 31, 2009 (Reference 8), EGC submitted the amount of funds required for radiological decommissioning based on a site-specific SAFSTOR estimate for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, as allowed by 10 CFR 50.75(e)(1)(i). These site-specific estimates were submitted to the NRC by EGC on December 18, 2006 (Reference 9). The decommissioning funding assurance illustrated by these site-specific estimates was accepted by the NRC on April 24, 2007 (Reference 10). Based on these site-specific cost estimates, and the decommissioning trust fund values as of December 31, 2008, for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, there was a difference in the amount required for decommissioning funding assurance and the trust fund values. EGC calculated the difference as of December 31, 2008 as $53.5M for Braidwood Station Unit 1, $35.1 M for Braidwood Station Unit 2, $41.3M for Byron Station Unit 1, and $40.5M for Byron Station Unit 2. The determinations herein of decommissioning funding assurance differences reflect the difference between fund values as of a specified date and the funding levels determined for NRC decommissioning funding assurance consistent with 10 CFR 50.75(e)(1)(i). As part of EGC's normal, 5-year cycle for updating decommissioning cost estimates, as specified in Regulatory Guide 1.159, Revision 1, Section 1.4.3, EGC is updating the site-specific cost estimate for both Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, in 2009. EGC expects a reduction in the site-specific SAFSTOR radiological decommissioning costs, based on the results of other EGC estimates completed during this cycle. This reduction is expected mainly due to a reduction in the waste disposal costs for Class A waste, which will now be sent to the EnergySolutions site in Clive, Utah, per EGC's contract with EnergySolutions. EGC will submit the new site-specific SAFSTOR decommissioning cost estimates to the NRC. Based on the schedule for completing these site-specific cost estimates, the NRC submittals will occur by November 20, 2009, for Byron Station, Units 1 and 2, and by January 15, 2010, for Braidwood Station, Units 1 and 2. If the site-specific cost estimates for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, coupled with trust fund values, do not illustrate adequate decommissioning funding assurance, EGC will establish additional decommissioning funding assurance using a guarantee method, as allowed by NRC regulations, on or before April 1, 2010, and upon approval by the EGC Board of Directors. The additional funding assurance will be calculated based on the funds required for radiological decommissioning considering the site-specific SAFSTOR estimates and the decommissioning trust fund values as of December 31, 2009. As stated above, the initial amount of any additional decommissioning funding assurance will be calculated as of December 31, 2009. Any additional funding assurance not in the form of cash contributions directly into the decommissioning trust July 29, 2009 U.S. Nuclear Regulatory Commission Page 3 funds (10 CFR 50.75(e)(1)(i)), will be provided in the form of a guarantee (10 CFR 50.75(e)(1)(iii))
| | See Attachment 1 In References 1 through 7, the NRC stated that they believe additional information is needed to demonstrate decommissioning funding assurance for Braidwood Station, Units 1 and 2, Byron Station, Units 1 and 2, Clinton Power Station, and LaSalle County Station, Units 1 and 2. The NRC's position was based on an internal review using the generic decommissioning funding assurance formula from 10 CFR 50.75(c), and the decommissioning trust fund values as of December 31, 2008, as reported by Exelon Generation Company, LLC (EGC) in Reference |
| to be recalculated on an annual basis (as of December 31). The value of the guarantee will be adjusted, if necessary, in accordance with those calculations by April 1 of the following year. Consistent with 10 CFR 30, Appendix A, any financial tests required for the guarantee will also be re-verified on an annual basis, and the form of the guarantee will continue to meet all NRC regulations. As such, decommissioning funding assurance will be provided through a combination of acceptable funding methods. Also, it is important to note that the value of the decommissioning trust funds has increased to a value of $177.2M for Braidwood Station Unit 1, $196.3M for Braidwood Station Unit 2, $199.1 M for Byron Station Unit 1, and $193.OM for Byron Station Unit 2, as of June 30, 2009, providing additional decommissioning funding assurance margin. Clinton Power Station On March 31, 2009 (Reference 8), EGC submitted the amount of funds required for radiological decommissioning based on a site-specific SAFSTOR estimate for Clinton Power Station, as allowed by 10 CFR 50.75(e)(1)(i). Based on this site-specific cost estimate and the decommissioning trust fund value as of December 31, 2008, for Clinton Power Station, there was a very small difference in the amount required for decommissioning funding assurance. Further, in conjunction with the Clinton Power Station license transfer from AmerGen Energy Company, LLC to EGC, EGC established a Parental Guarantee from Exelon Corporation in the amount of $151,758.34. A copy of this Parental Guarantee is included as Attachment | | : 8. As requested in References 1 through 7, and a subsequent conference call between EGC and the NRC on July 1, 2009, EGC agreed to submit a plan by July 31, 2009, to show adequate decommissioning funding assurance. |
| : 3. The site-specific estimate and Parental Guarantee show adequate decommissioning funding assurance exists for Clinton Power Station. EGC will submit the Clinton Power Station site-specific SAFSTOR decommissioning cost estimate to the NRC by August 28, 2009. EGC concludes that no other action is required to show adequate decommissioning funding assurance for Clinton Power Station. Furthermore, based on the Clinton Power Station trust fund value as of June 30, 2009, of $303.2M, the Parental Guarantee is no longer required to show adequate decommissioning funding assurance. Therefore, this letter also serves as notice to the NRC that Exelon intends to cancel the Parental Guarantee. This cancellation will not occur until after 120 days of this notice, as specified by 10 CFR 30, Appendix A. LaSalle County Station Units 1 and 2 On March 31, 2009 (Reference 8), EGC submitted the amount of funds required for radiological decommissioning based on a site-specific SAFSTOR estimate for LaSalle County Station, Units 1 and 2, as allowed by 10 CFR 50.75(e)(1)(i). This site-specific estimate was submitted to the NRC by EGC on December 18, 2006 (Reference 9). The decommissioning funding assurance illustrated by this site-specific estimate was accepted by the NRC on April 24, 2007 (Reference 10). Based on this site-specific cost estimate and the decommissioning trust fund value as of December 31, 2008, for July 29, 2009 U.S. Nuclear Regulatory Commission Page 4 LaSalle County Station, Units 1 and 2, there was a small difference in the amount required for decommissioning funding assurance and the trust funds values. EGC calculated the difference as of December 31, 2008 as $9.5M for LaSalle County Station Unit 1, and $3.8M for LaSalle County Station Unit 2. As part of the normal, 5-year cycle for updating decommissioning cost estimates, as specified in Regulatory Guide 1.159, Revision 1, Section 1.4.3, EGC is updating the site-specific cost estimate for LaSalle County Station, Units 1 and 2 in 2009. This cost estimate was completed in June 2009, and shows a reduction in the overall SAFSTOR decommissioning costs. This reduction is mainly due to a reduction in the waste disposal costs for Class A waste, which will now be sent to the EnergySolutions site in Clive Utah, per EGC's contract with EnergySolutions. The new site-specific estimate provides adequate decommissioning funding assurance for LaSalle County Station, Units 1 and 2. Therefore, EGC will submit the new LaSalle County Station, Units 1 and 2, site-specific SAFSTOR decommissioning cost estimate to the NRC by August 28, 2009. EGC concludes that no other action is required to show adequate decommissioning funding assurance for LaSalle County Station, Units 1 and 2. Also, it is important to note that the value of the decommissioning trust funds has increased to a value of $276.8M for LaSalle County Station, Unit 1, and $269.4M for LaSalle County Station, Unit 2, as of June 30, 2009, providing additional decommissioning funding assurance margin. In summary, EGC's plan is to put the above actions in place to meet NRC minimum funding assurance requirements. EGC remains confident that sufficient funds will be available to decommission all EGC sites when required. For these sites, the current license expiration dates are at least 13 years away. Further, up to an additional 60 years can be used to safely decommission these sites. This additional time allows for the accumulation of earnings on the funds, as permitted by NRC regulations, such that adequate decommissioning funding assurance is provided for each of the above plants. Furthermore, EGC intends to pursue a 20-year license extension for all of these sites, allowing yet an additional 20 years of fund returns before decommissioning commences; thereby, providing further decommissioning funding assurance. Regulatory commitments are contained in Attachment 2 of this letter. If you have any questions about this letter, please contact Patrick Simpson at (630) 657-2823. Keith R. Jury j Vice President - Licensing and Regulatory Affairs Exelon Generation Company, LLC Attachments ATTACHMENT 1 REFERENCES
| | The plan to show adequate decommissioning July 29, 2009 U.S. Nuclear Regulatory Commission Page 2 funding assurance is described below. The actions detailed in the plan are summarized in Attachment 2.Braidwood Station, Units 1 and 2, Byron Station, Units 1 and 2 On March 31, 2009 (Reference 8), EGC submitted the amount of funds required for radiological decommissioning based on a site-specific SAFSTOR estimate for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, as allowed by 10 CFR 50.75(e)(1)(i). |
| : 1. Letter from Marshall J. David (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Braidwood Station, Unit 1," dated June 18, 2009 2. Letter from Marshall J. David (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Braidwood Station, Unit 2," dated June 18, 2009 3. Letter from Marshall J. David (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Byron Station, Unit 1," dated June 18, 2009 4. Letter from Marshall J. David (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Byron Station, Unit 2," dated June 18, 2009 5. Letter from Stephen P. Sands (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Clinton Power Station, Unit 1," dated June 18, 2009 6. Letter from Stephen P. Sands (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for LaSalle County Station, Unit 1," dated June 18, 2009 7. Letter from Stephen P. Sands (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for LaSalle County Station, Unit 2," dated June 18, 2009 8. Letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U.S. NRC, "Report of Status of Decommissioning Funding for Reactors," dated March 31, 2009 9. Letter from Kenneth A. Ainger (Exelon Generation Company, LLC) to U.S. NRC, "Site-specific Decommissioning Cost Estimates," dated December 18, 2006 10. Letter from Christopher Gratton (U.S. NRC) to Christopher M. Crane (Exelon Generation Company, LLC), "Braidwood Station, Units 1 and 2; Byron Station, Units 1 and 2; and LaSalle County Station, Units 1 and 2 - Review of Site-Specific Decommissioning Cost Estimates," dated April 24, 2007 ATTACHMENT 2 Regulatory Commitments The following list identifies those actions committed to by Exelon Generation Company, LLC, (EGC) in this submittal. Any other actions discussed in the submittal represent intended or planned actions by EGC, are described only for information, and are not regulatory commitments. COMMITMENT TYPE COMMITMENT COMMITTED DATE ONE-TIME PROGRAM- OR "OUTAGE" ACTION MATIC (YES/NO) (YES/NO) Provide site-specific SAFSTOR August 28, 2009 Yes No decommissioning cost estimate for Clinton Power Station Provide site-specific SAFSTOR August 28, 2009 Yes No decommissioning cost estimates for LaSalle County Station, Units 1 and 2 Provide site-specific SAFSTOR November 20, 2009 Yes No decommissioning cost estimates for B ron Station, Units 1 and 2 Provide site-specific SAFSTOR January 15, 2010 Yes No decommissioning cost estimates for Braidwood Station, Units 1 and 2 Obtain approval from EGC Board First Quarter 2010 Yes No of Directors of any required additional guarantee in the amount necessary to provide adequate funding assurance for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, based on site-specific SAFSTOR decommissioning cost estimates and decommissioning trust fund values as of December 31, 2009 Establish guarantee, as allowed April 1, 2010 Yes No by NRC regulations, for any difference in funding assurance for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, based on site-specific SAFSTOR decommissioning cost estimates and decommissioning trust fund values as of December 31, 2009 COMMITMENT TYPE COMMITMENT COMMITTED DATE ONE-TIME PROGRAM- OR "OUTAGE" ACTION MATIC (YES/NO) (YES/NO) Any additional funding assurance Ongoing No Yes for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, provided in response to commitments in letter RS-09-095, not in the form of cash contributions directly into the decommissioning trust funds (10 CFR 50.75(e)(1)(i)), will be provided in the form of a guarantee (10 CFR 50.75(e)(1)(iii)) | | These site-specific estimates were submitted to the NRC by EGC on December 18, 2006 (Reference 9). The decommissioning funding assurance illustrated by these site-specific estimates was accepted by the NRC on April 24, 2007 (Reference 10). Based on these site-specific cost estimates, and the decommissioning trust fund values as of December 31, 2008, for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, there was a difference in the amount required for decommissioning funding assurance and the trust fund values. EGC calculated the difference as of December 31, 2008 as $53.5M for Braidwood Station Unit 1, $35.1 M for Braidwood Station Unit 2, $41.3M for Byron Station Unit 1, and $40.5M for Byron Station Unit 2. The determinations herein of decommissioning funding assurance differences reflect the difference between fund values as of a specified date and the funding levels determined for NRC decommissioning funding assurance consistent with 10 CFR 50.75(e)(1)(i). |
| to be recalculated on an annual basis (as of December 31). The value of the guarantee will be adjusted, if necessary, in accordance with those calculations by April 1 of the following year. | | As part of EGC's normal, 5-year cycle for updating decommissioning cost estimates, as specified in Regulatory Guide 1.159, Revision 1, Section 1.4.3, EGC is updating the site-specific cost estimate for both Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, in 2009. EGC expects a reduction in the site-specific SAFSTOR radiological decommissioning costs, based on the results of other EGC estimates completed during this cycle. This reduction is expected mainly due to a reduction in the waste disposal costs for Class A waste, which will now be sent to the EnergySolutions site in Clive, Utah, per EGC's contract with EnergySolutions. |
| ATTACHMENT 3 PARENTAL GUARANTEE FOR CLINTON POWER STATION Guarantee made this January 8, 2009 by Exelon Corporation, a corporation organized under the laws of the Commonwealth of Pennsylvania, herein referred to as "guarantor," to the U.S. Nuclear Regulatory Commission (NRC), on behalf of our subsidiary Exelon Generation Company, LLC (ExGen) of 300 Exelon Way, Kennett Square, PA 19348, obligee. Recitals PARENT GUARANTEE NRC DECOMMISSIONING FUNDING ASSURANCE | | EGC will submit the new site-specific SAFSTOR decommissioning cost estimates to the NRC. Based on the schedule for completing these site-specific cost estimates, the NRC submittals will occur by November 20, 2009, for Byron Station, Units 1 and 2, and by January 15, 2010, for Braidwood Station, Units 1 and 2.If the site-specific cost estimates for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, coupled with trust fund values, do not illustrate adequate decommissioning funding assurance, EGC will establish additional decommissioning funding assurance using a guarantee method, as allowed by NRC regulations, on or before April 1, 2010, and upon approval by the EGC Board of Directors. |
| : 1. The guarantor has full authority and capacity to enter into this guarantee pursuant to its bylaws, articles of incorporation, and the laws of Pennsylvania, its State of incorporation. Guarantor has approval from its Board of Directors to enter into this guarantee. 2. This guarantee is being issued so that ExGen will be in compliance with regulations issued by the NRC, an agency of the U.S. Government, pursuant to the Atomic Energy Act of 1954, as amended and the Energy Reorganization Act of 1974. The NRC has promulgated regulations in Title 10, Chapter T of the Code of Federal Regulations, Part 50, which require that a holder of, or an applicant for, a license issued pursuant to 10 CFR Part 50 provide assurance that funds will be available when needed for require decommissioning activities. 3. This guarantee is issued to provide financial assurance for a portion of the costs of decommissioning activities for Clinton Power Station as required by 10 CFR Part 50. The decommissioning costs for which the guarantee is issued are: $151,758.34. 4. The guarantor meets or exceeds the financial test criteria as stated in NRC 10 CFR 30 Appendix A Section 11, and will comply with the notification requirements as specified in 10 CFR Part 50 and Appendix A to Part 30.
| | The additional funding assurance will be calculated based on the funds required for radiological decommissioning considering the site-specific SAFSTOR estimates and the decommissioning trust fund values as of December 31, 2009.As stated above, the initial amount of any additional decommissioning funding assurance will be calculated as of December 31, 2009. Any additional funding assurance not in the form of cash contributions directly into the decommissioning trust July 29, 2009 U.S. Nuclear Regulatory Commission Page 3 funds (10 CFR 50.75(e)(1)(i)), will be provided in the form of a guarantee (10 CFR 50.75(e)(1)(iii)) |
| : 5. The guarantor is the sole member of Exelon Generation Company, LLC, the holder of NRC License No. NPF-62 for Clinton Power Station, V-852, RR3, Box 228, Clinton, IL 61727. 6. Decommissioning activities as used below refers to the activities required by 10 CFR Part 50 for decommissioning of the facility(ies) identified above. 7. For value received, and pursuant to the authority delegated to the officers of guarantor by its Board of Directors, the guarantor guarantees to the NRC that if the licensee fails to perform the required decommissioning activities, as required by License No. NPF-62 , due to lack of funds, the guarantor shall either, as the guarantor shall determine: a. carry out the required activities, or b. provide all funds necessary, up to the amount of this guarantee specified in Section 3, to carry out the required activities, or c. set up a trust fund in favor of ExGen in the amount of these current cost estimates or guarantee amount for these activities. 8. The guarantor shall assure that its independent accountant submit revised financial statements, financial test data, and will perform the review specified in NRC 10 CFR 30 Appendix A Section II, B and C, and notify the NRC as required by these sections. 9. The guarantor and the licensee agree that if the guarantor fails to meet the financial test criteria at any time after this guarantee is established, the guarantor and licensee shall send, within 90 days of the end of the fiscal year in which the guarantor fails to meet the financial test criteria, by certified mail, notice to the NRC. If ExGen fails to provide alternative financial assurance as specified in 10 CFR Part 50, as applicable, and obtain written approval of such assurance from the NRC within 180 days of the end of such fiscal year, the guarantor shall provide such alternative financial assurance in the name of ExGen or make full payment under the guarantee to a standby trust established by ExGen. | | to be recalculated on an annual basis (as of December 31). The value of the guarantee will be adjusted, if necessary, in accordance with those calculations by April 1 of the following year. Consistent with 10 CFR 30, Appendix A, any financial tests required for the guarantee will also be re-verified on an annual basis, and the form of the guarantee will continue to meet all NRC regulations. |
| : 10. Independent of any notification under paragraph S above, if the NRC determines for any reason that the guarantor no longer meets the financial test criteria or that it is disallowed from continuing as guarantor for the facility under License No. NPF-62 , the guarantor agrees that within 90 days after being notified by the NRC of such determination, an alternative financial assurance mechanism as specified in 10 CFR Part 50 as applicable, shall be established by the guarantor in the name of ExGen unless ExGen has done so. 11. The guarantor as well as its successors and assigns agree to remain bound jointly and severally under this guarantee notwithstanding any or all of the following: amendment or notification of license or NRC-approved decommissioning funding plan for that facility, the extension or reduction of the time of performance of required activities, or any other modification or alteration of an obligation of the licensee pursuant to 10 CFR Part 50. 12. The guarantor agrees that it will be liable for all litigation costs incurred by ExGen or the NRC in any successful effort to enforce the agreement against the guarantor. 13. The guarantor agrees to remain bound under this guarantee for as long as ExGen must comply with the applicable financial assurance requirements of 10 CFR Part 50, for the previously listed facility(ies) except that the guarantor may cancel this guarantee by sending certified mail to the NRC and to ExGen, such cancellation to become effective no earlier than 120 days after receipt of such notice by both the NRC and ExGen as evidenced by the return receipts. If the licensee fails to provide alternative financial assurance as specified in 10 CFR Part 50, as applicable, and obtain written approval of such assurance within 120 days after the sending of the above notice by the guarantor, the guarantor shall provide such alternative financial assurance. 14. The guarantor expressly waives notice of acceptance of this guarantee by the NRC or by ExGen. The guarantor also expressly waives notice of amendments or modification of the decommissioning requirements and of amendments or modifications of the license. | | As such, decommissioning funding assurance will be provided through a combination of acceptable funding methods.Also, it is important to note that the value of the decommissioning trust funds has increased to a value of $177.2M for Braidwood Station Unit 1, $196.3M for Braidwood Station Unit 2, $199.1 M for Byron Station Unit 1, and $193.OM for Byron Station Unit 2, as of June 30, 2009, providing additional decommissioning funding assurance margin.Clinton Power Station On March 31, 2009 (Reference 8), EGC submitted the amount of funds required for radiological decommissioning based on a site-specific SAFSTOR estimate for Clinton Power Station, as allowed by 10 CFR 50.75(e)(1)(i). |
| : 15. If the guarantor files annual financial reports with the U.S. Securities and Exchange Commission, then it shall promptly submit them to the NRC during each year in which this guarantee is in effect. I herby certify that this guarantee is true and correct to the best of my knowledge. Effective date: 11 R )oq Signature of witness or notary: 'yt,-c"t~ OFFICIAL SEAL Maria Dolores Munguia Notary Public, State of Illinois Commission Expires 04/04/2012 Exelon Generation Company, LLC President and Chief Operating Officer Signature of witness or notary: 4 A-~ vJ o/~ OFFICIAL SEAL. Maria Dolores Munguia Notary Public, State of Illinois Comminfun Expiroe 04/04/2012}} | | Based on this site-specific cost estimate and the decommissioning trust fund value as of December 31, 2008, for Clinton Power Station, there was a very small difference in the amount required for decommissioning funding assurance. |
| | Further, in conjunction with the Clinton Power Station license transfer from AmerGen Energy Company, LLC to EGC, EGC established a Parental Guarantee from Exelon Corporation in the amount of $151,758.34. |
| | A copy of this Parental Guarantee is included as Attachment 3.The site-specific estimate and Parental Guarantee show adequate decommissioning funding assurance exists for Clinton Power Station. EGC will submit the Clinton Power Station site-specific SAFSTOR decommissioning cost estimate to the NRC by August 28, 2009. EGC concludes that no other action is required to show adequate decommissioning funding assurance for Clinton Power Station.Furthermore, based on the Clinton Power Station trust fund value as of June 30, 2009, of $303.2M, the Parental Guarantee is no longer required to show adequate decommissioning funding assurance. |
| | Therefore, this letter also serves as notice to the NRC that Exelon intends to cancel the Parental Guarantee. |
| | This cancellation will not occur until after 120 days of this notice, as specified by 10 CFR 30, Appendix A.LaSalle County Station, Units 1 and 2 On March 31, 2009 (Reference 8), EGC submitted the amount of funds required for radiological decommissioning based on a site-specific SAFSTOR estimate for LaSalle County Station, Units 1 and 2, as allowed by 10 CFR 50.75(e)(1)(i). |
| | This site-specific estimate was submitted to the NRC by EGC on December 18, 2006 (Reference 9). The decommissioning funding assurance illustrated by this site-specific estimate was accepted by the NRC on April 24, 2007 (Reference 10). Based on this site-specific cost estimate and the decommissioning trust fund value as of December 31, 2008, for July 29, 2009 U.S. Nuclear Regulatory Commission Page 4 LaSalle County Station, Units 1 and 2, there was a small difference in the amount required for decommissioning funding assurance and the trust funds values. EGC calculated the difference as of December 31, 2008 as $9.5M for LaSalle County Station Unit 1, and $3.8M for LaSalle County Station Unit 2.As part of the normal, 5-year cycle for updating decommissioning cost estimates, as specified in Regulatory Guide 1.159, Revision 1, Section 1.4.3, EGC is updating the site-specific cost estimate for LaSalle County Station, Units 1 and 2 in 2009. This cost estimate was completed in June 2009, and shows a reduction in the overall SAFSTOR decommissioning costs. This reduction is mainly due to a reduction in the waste disposal costs for Class A waste, which will now be sent to the EnergySolutions site in Clive Utah, per EGC's contract with EnergySolutions. |
| | The new site-specific estimate provides adequate decommissioning funding assurance for LaSalle County Station, Units 1 and 2. Therefore, EGC will submit the new LaSalle County Station, Units 1 and 2, site-specific SAFSTOR decommissioning cost estimate to the NRC by August 28, 2009. EGC concludes that no other action is required to show adequate decommissioning funding assurance for LaSalle County Station, Units 1 and 2.Also, it is important to note that the value of the decommissioning trust funds has increased to a value of $276.8M for LaSalle County Station, Unit 1, and $269.4M for LaSalle County Station, Unit 2, as of June 30, 2009, providing additional decommissioning funding assurance margin.In summary, EGC's plan is to put the above actions in place to meet NRC minimum funding assurance requirements. |
| | EGC remains confident that sufficient funds will be available to decommission all EGC sites when required. |
| | For these sites, the current license expiration dates are at least 13 years away. Further, up to an additional 60 years can be used to safely decommission these sites. This additional time allows for the accumulation of earnings on the funds, as permitted by NRC regulations, such that adequate decommissioning funding assurance is provided for each of the above plants.Furthermore, EGC intends to pursue a 20-year license extension for all of these sites, allowing yet an additional 20 years of fund returns before decommissioning commences; thereby, providing further decommissioning funding assurance. |
| | Regulatory commitments are contained in Attachment 2 of this letter.If you have any questions about this letter, please contact Patrick Simpson at (630) 657-2823.Res~cfully, Keith R. Jury Vice President |
| | -Licensing and Regulatory Affairs Exelon Generation Company, LLC Attachments ATTACHMENT 1 REFERENCES |
| | : 1. Letter from Marshall J. David (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Braidwood Station, Unit 1 ," dated June 18, 2009 2. Letter from Marshall J. David (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Braidwood Station, Unit 2," dated June 18, 2009 3. Letter from Marshall J. David (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Byron Station, Unit 1 ," dated June 18, 2009 4. Letter from Marshall J. David (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Byron Station, Unit 2," dated June 18, 2009 5. Letter from Stephen P. Sands (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Clinton Power Station, Unit 1," dated June 18, 2009 6. Letter from Stephen P. Sands (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for LaSalle County Station, Unit 1 ," dated June 18, 2009 7. Letter from Stephen P. Sands (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for LaSalle County Station, Unit 2," dated June 18, 2009 8. Letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U.S. NRC,"Report of Status of Decommissioning Funding for Reactors," dated March 31, 2009 9. Letter from Kenneth A. Ainger (Exelon Generation Company, LLC) to U.S. NRC,"Site-specific Decommissioning Cost Estimates," dated December 18, 2006 10. Letter from Christopher Gratton (U.S. NRC) to Christopher M. Crane (Exelon Generation Company, LLC), "Braidwood Station, Units 1 and 2; Byron Station, Units 1 and 2; and LaSalle County Station, Units 1 and 2 -Review of Site-Specific Decommissioning Cost Estimates," dated April 24, 2007 ATTACHMENT 2 Regulatory Commitments The following list identifies those actions committed to by Exelon Generation Company, LLC, (EGC) in this submittal. |
| | Any other actions discussed in the submittal represent intended or planned actions by EGO, are described only for information, and are not regulatory commitments. |
| | COMMITMENT TYPE COMMITMENT COMMITTED DATE ONE-TIME PROGRAM-OR "OUTAGE" ACTION MATIC (YES/NO) (YES/NO)Provide site-specific SAFSTOR August 28, 2009 Yes No decommissioning cost estimate for Clinton Power Station Provide site-specific SAFSTOR decommissioning cost estimates August 28, 2009 Yes No for LaSalle County Station, Units 1 and 2 Provide site-specific SAFSTOR decommissioning cost estimates for Byron Station, Units 1 and 2 Provide site-specific SAFSTOR January 15, 2010 Yes No decommissioning cost estimates for Braidwood Station, Units 1 and 2 Obtain approval from EGC Board First Quarter 2010 Yes No of Directors of any required additional guarantee in the amount necessary to provide adequate funding assurance for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, based on site-specific SAFSTOR decommissioning cost estimates and decommissioning trust fund values as of December 31, 2009 Establish guarantee, as allowed April 1 2010 Yes No by NRC regulations, for any difference in funding assurance for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, based on site-specific SAFSTOR decommissioning cost estimates and decommissioning trust fund values as of December 31, 2009 COMMITMENT TYPE COMMITMENT COMMITTED DATE ONE-TIME PROGRAM-OR "OUTAGE" ACTION MATIC (YES/NO) (YES/NO)Any additional funding assurance Ongoing No Yes for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, provided in response to commitments in letter RS-09-095, not in the form of cash contributions directly into the decommissioning trust funds (10 CFR 50.75(e)(1)(i)), will be provided in the form of a guarantee (10 CFR 50.75(e)(1)(iii)) |
| | to be recalculated on an annual basis (as of December 31). The value of the guarantee will be adjusted, if necessary, in accordance with those calculations by April 1 of the followina year. |
| | ATTACHMENT 3 PARENTAL GUARANTEE FOR CLINTON POWER STATION PARENT GUARANTEE NRC DECOMMISSIONING FUNDING ASSURANCE Guarantee made this January 8, 2009 by Exelon Corporation, a corporation organized under the laws of the Commonwealth of Pennsylvania, herein referred to as "guarantor," to the U.S.Nuclear Regulatory Commission (NRC), on behalf of our subsidiary Exelon Generation Company, LLC (ExGen) of 300 Exelon Way, Kennett Square, PA 19348, obligee.Recitals 1. The guarantor has full authority and capacity to enter into this guarantee pursuant to its bylaws, articles of incorporation, and the laws of Pennsylvania, its State of incorporation. |
| | Guarantor has approval from its Board of Directors to enter into this guarantee. |
| | : 2. This guarantee is being issued so that ExGen will be in compliance with regulations issued by the NRC, an agency of the U.S. Government, pursuant to the Atomic Energy Act of 1954, as amended and the Energy Reorganization Act of 1974. The NRC has promulgated regulations in Title 10, Chapter I of the Code of Federal Regulations, Part 50, which require that a holder of, or. an applicant for, a license issued pursuant to 10 CFR Part 50 provide assurance that funds will be available when needed for require decommissioning activities. |
| | : 3. This guarantee is issued to provide financial assurance for a portion of the costs of decommissioning activities for Clinton Power Station as required by 10 CFR Part 50. The decommissioning costs for which the guarantee is issued are: $151,758.34. |
| | : 4. The guarantor meets or exceeds the financial test criteria as stated in NRC 10 CFR 30 Appendix A Section II, and will comply with the notification requirements as specified in 10 CFR Part 50 and Appendix A to Part 30. |
| | : 5. The guarantor is the sole member of Exelon Generation Company, LLC, the holder of NRC License No. NPF-62 for Clinton Power Station, V-852, RR3, Box 228, Clinton, IL 61727.6. Decommissioning activities as used below refers to the activities required by 10 CFR Part 50 for decommissioning of the facility(ies) identified above.7. For value received, and pursuant to the authority delegated to the officers of guarantor by its Board of Directors, the guarantor guarantees to the NRC that if the licensee fails to perform the required decommissioning activities, as required by License No. NPF-62, due to lack of funds, the guarantor shall either, as the guarantor shall determine: |
| | : a. carry out the required activities, or b. provide all funds necessary, up to the amount of this guarantee specified in Section 3, to carry out the required activities, or c. set up a trust fund in favor of ExGen in the amount of these current cost estimates or guarantee amount for these activities. |
| | : 8. The guarantor shall assure that its independent accountant submit revised financial statements, financial test data, and will perform the review specified in NRC 10 CFR 30 Appendix A Section II, B and C, and notify the NRC as required by these sections.9. The guarantor and the licensee agree that if the guarantor fails to meet the financial test criteria at any time after this guarantee is established, the guarantor and licensee shall send, within 90 days of the end of the fiscal year in which the guarantor fails to meet the financial test criteria, by certified mail, notice to the NRC. If ExGen fails to provide alternative financial assurance as specified in 10 CFR Part 50, as applicable, and obtain written approval of such assurance from the NRC within 180 days of the end of such fiscal year, the guarantor shall provide such alternative financial assurance in the name of ExGen or make full payment under the guarantee to a standby trust established by ExGen. |
| | : 10. Independent of any notification under paragraph 8 above, if the NRC determines for any reason that the guarantor no longer meets the financial test criteria or that it is disallowed from continuing as guarantor for the facility under License No. NPF-62, the guarantor agrees that within 90 days after being notified by the NRC of such determination, an alternative financial assurance mechanism as specified in 10 CFR Part 50 as applicable, shall be established by the guarantor in the name of ExGen unless ExGen has done so.11. The guarantor as well as its successors and assigns agree to remain bound jointly and severally under this guarantee notwithstanding any or all of the following: |
| | amendment or notification of license or NRC-approved decommissioning funding plan for that facility, the extension or reduction of the time of performance of required activities, or any other modification or alteration of an obligation of the licensee pursuant to 10 CFR Part 50.12. The guarantor agrees that it will be liable for all litigation costs incurred by ExGen or the NRC in any successful effort to enforce the agreement against the guarantor. |
| | : 13. The guarantor agrees to remain bound under this guarantee for as long as ExGen must comply with the applicable financial assurance requirements of 10 CFR Part 50, for the previously listed facility(ies) except that the guarantor may cancel this guarantee by sending certified mail to the NRC and to ExGen, such cancellation to become effective no earlier than 120 days after receipt of such notice by both the NRC and ExGen as evidenced by the return receipts. |
| | If the licensee fails to provide alternative financial assurance as specified in 10 CFR Part 50, as applicable, and obtain written approval of such assurance within 120 days after the sending of the above notice by the guarantor, the guarantor shall provide such alternative financial assurance. |
| | : 14. The guarantor expressly waives notice of acceptance of this guarantee by the NRC or by ExGen. The guarantor also expressly waives notice of amendments or modification of the decommissioning requirements and of amendments or modifications of the license. |
| | : 15. If the guarantor files annual financial reports with the U.S. Securities and Exchange Commission, then it shall promptly submit them to the NRC during each year in which this guarantee is in effect.I herby certify that this guarantee is true and correct to the best of my knowledge. |
| | Effective date: ,AIL~~JQj.k Signature of witness or notary: Exelon Generation Company, L OFFICIAL SEAL Maria Dolores Munguia Notary Public, State of Illinois Commission Expires 04/04/2012"jnstopher M Crane President and Chief Operating Officer Signature of witness or notary: ,4 , i,-OFFICIAL SEAL Maria Dolores Munguia Notary Public, State of Illinois Commission Expires 04/04/2012}} |
Letter Sequence Request |
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MONTHYEARML0916003362009-06-18018 June 2009 Company, Llc'S Status of Decommissioning Funding Assurance Project stage: Other ML0916003562009-06-18018 June 2009 Company, Llc'S Status of Decommissioning Funding Assurance Project stage: Other ML0916002402009-06-18018 June 2009 Company, Llc'S Status of Decommissioning Funding Assurance Project stage: Other ML0916001942009-06-18018 June 2009 Company, Llc'S Status of Decommissioning Funding Assurance Project stage: Other ML0918700662009-07-0707 July 2009 Summary of July 1, 2009, Conference Call with Exelon Generation Company, LLC, on Decommission Funding Assurance Project stage: Other RS-09-095, Decommissioning Funding Assurance Plan2009-07-29029 July 2009 Decommissioning Funding Assurance Plan Project stage: Request RS-09-111, Submittal of Clinton Power Station Site-Specific Safstor Decommissioning Cost Estimate2009-08-27027 August 2009 Submittal of Clinton Power Station Site-Specific Safstor Decommissioning Cost Estimate Project stage: Request ML0927304962009-10-0202 October 2009 RAI Decommissioning Financial Assurance Plans Project stage: RAI RS-09-145, Units 1 & 2 - Response to Request for Additional Information Regarding Decommissioning Financial Assurance Plans2009-10-27027 October 2009 Units 1 & 2 - Response to Request for Additional Information Regarding Decommissioning Financial Assurance Plans Project stage: Response to RAI RS-09-157, Submittal of Site-Specific Safstor Decommissioning Cost Estimate2009-11-16016 November 2009 Submittal of Site-Specific Safstor Decommissioning Cost Estimate Project stage: Request ML1000601672010-01-0707 January 2010 Request for Additional Information Decommissioning Financial Assurance Plans Project stage: RAI ML1001202412010-01-11011 January 2010 Submittal of Braidwood Station Site-Specific Safstor Decommissioning Cost Estimate Project stage: Request ML1001207712010-01-13013 January 2010 Correction - Braidwood Station, Units 1 and 2; Byron Station, Unit Nos. 1 and 2 - Request for Additional Information Decommissioning Financial Assurance Plans Project stage: RAI RS-10-034, Response to Request for Additional Information Regarding Decommissioning Financial Assurance Plans2010-02-15015 February 2010 Response to Request for Additional Information Regarding Decommissioning Financial Assurance Plans Project stage: Response to RAI RS-10-051, Submittal of Decommissioning Funding Assurance Calculations2010-03-10010 March 2010 Submittal of Decommissioning Funding Assurance Calculations Project stage: Request ML1011003382010-04-20020 April 2010 Request for Additional Information Regarding to Decommissioning Financial Assurance Plans (Tac Nos. ME0489, ME0490, ME0496, and ME0497) Project stage: RAI ML1014403232010-05-26026 May 2010 Request for Additional Information Regarding the Decommissioning Financial Assurance Plans Project stage: RAI ML1016803572010-06-28028 June 2010 June 2, 2010, Summary of a Telephone Conference Held with Exelon Generation Company, LLC, Regarding Decommissioning Funding Shortfalls Project stage: Other 2010-01-11
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Category:Decommissioning Funding Plan DKTs 30
MONTHYEARRS-23-049, Constellation Energy Generation, LLC, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2023-03-23023 March 2023 Constellation Energy Generation, LLC, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations RS-22-055, Submittal of Preliminary Decommissioning Cost Estimate and Spent Fuel Management Plan2022-04-18018 April 2022 Submittal of Preliminary Decommissioning Cost Estimate and Spent Fuel Management Plan RS-21-030, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2021-02-24024 February 2021 Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations NMP1L3371, Summary of Changes, Quality Assurance Topical Report, NO-AA-10 & Decommissioning Quality Assurance Program, NO-DC-102021-02-10010 February 2021 Summary of Changes, Quality Assurance Topical Report, NO-AA-10 & Decommissioning Quality Assurance Program, NO-DC-10 RS-19-045, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2019-04-0101 April 2019 Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations RS-16-040, Report on Status of Decommissioning Funding2016-02-0404 February 2016 Report on Status of Decommissioning Funding ML16008A1172016-01-20020 January 2016 U.S. Nuclear Regulatory Commission Analysis of Excelon Generation'S Decommissioning Funding Status Report RS-15-094, (EGC) - Submittal of Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2015-03-31031 March 2015 (EGC) - Submittal of Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations RS-15-077, Submittal of Updated Site Specific Safstor Decommissioning Cost Estimates for Braidwood, Byron and LaSalle Stations2015-02-19019 February 2015 Submittal of Updated Site Specific Safstor Decommissioning Cost Estimates for Braidwood, Byron and LaSalle Stations RS-13-106, (EGC) Amended 2011 Report on Status of Decommissioning Funding for Reactors and Correction to July 27, 2011 RAI Response2013-04-12012 April 2013 (EGC) Amended 2011 Report on Status of Decommissioning Funding for Reactors and Correction to July 27, 2011 RAI Response RS-13-100, Report on Status of Decommissioning Funding for Reactors2013-04-0101 April 2013 Report on Status of Decommissioning Funding for Reactors RS-13-064, Submittal of Updated Clinton Power Station Site-Specific Safstor Decommissioning Cost Estimate2013-03-0101 March 2013 Submittal of Updated Clinton Power Station Site-Specific Safstor Decommissioning Cost Estimate ML1001202412010-01-11011 January 2010 Submittal of Braidwood Station Site-Specific Safstor Decommissioning Cost Estimate RS-09-114, Site-Specific Safstor Decommissioning Cost Estimate2009-08-27027 August 2009 Site-Specific Safstor Decommissioning Cost Estimate RS-09-095, Decommissioning Funding Assurance Plan2009-07-29029 July 2009 Decommissioning Funding Assurance Plan ML0921201652009-07-29029 July 2009 Decommissioning Funding Assurance Plan RS-09-041, Submittal of Exelon Generation Company, LLC, Report on Status of Decommissioning Funding for Reactors Owned by EGC2009-03-31031 March 2009 Submittal of Exelon Generation Company, LLC, Report on Status of Decommissioning Funding for Reactors Owned by EGC RS-06-176, Site-Specific Decommissioning Cost Estimates2006-12-18018 December 2006 Site-Specific Decommissioning Cost Estimates 2023-03-23
[Table view] Category:40
MONTHYEARRS-23-049, Constellation Energy Generation, LLC, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2023-03-23023 March 2023 Constellation Energy Generation, LLC, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations RS-22-055, Submittal of Preliminary Decommissioning Cost Estimate and Spent Fuel Management Plan2022-04-18018 April 2022 Submittal of Preliminary Decommissioning Cost Estimate and Spent Fuel Management Plan RS-22-014, Application to Adopt TSTF-246, RTS Instrumentation, 3.3.1 Condition F Completion Time2022-03-24024 March 2022 Application to Adopt TSTF-246, RTS Instrumentation, 3.3.1 Condition F Completion Time RS-21-063, Application to Adopt TSTF-554, Revision 1, Revise Reactor Coolant Leakage Requirements2021-06-30030 June 2021 Application to Adopt TSTF-554, Revision 1, Revise Reactor Coolant Leakage Requirements RS-21-032, Amended Decommissioning Trust Agreements2021-02-25025 February 2021 Amended Decommissioning Trust Agreements RS-21-030, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2021-02-24024 February 2021 Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations NMP1L3371, Summary of Changes, Quality Assurance Topical Report, NO-AA-10 & Decommissioning Quality Assurance Program, NO-DC-102021-02-10010 February 2021 Summary of Changes, Quality Assurance Topical Report, NO-AA-10 & Decommissioning Quality Assurance Program, NO-DC-10 RS-21-005, Request for License Amendment to Revise Degraded Voltage Relay Allowable Values2021-01-20020 January 2021 Request for License Amendment to Revise Degraded Voltage Relay Allowable Values RS-20-052, Application to Revise Technical Specifications to Adopt Risk Informed Completion Times TSTF-505, Revision 2, Provide Risk-Informed Extended Completion Extended Completed Times-RITSTF Initiative 4b2020-04-30030 April 2020 Application to Revise Technical Specifications to Adopt Risk Informed Completion Times TSTF-505, Revision 2, Provide Risk-Informed Extended Completion Extended Completed Times-RITSTF Initiative 4b RS-20-016, County, Nine Mile Point, Peach Bottom Atomic and Quad Cities - Application to Revise Technical Specifications to Adopt TSTF-566, Revise Actions for Inoperable RHR Shutdown Cooling Systems2020-04-13013 April 2020 County, Nine Mile Point, Peach Bottom Atomic and Quad Cities - Application to Revise Technical Specifications to Adopt TSTF-566, Revise Actions for Inoperable RHR Shutdown Cooling Systems RS-19-045, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2019-04-0101 April 2019 Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations RS-19-022, License Amendment Request - Clarifying Changes for Certain Emergency Action Levels Based on Emergency Preparedness Program Frequently Asked Questions (Epfaqs)2019-03-0101 March 2019 License Amendment Request - Clarifying Changes for Certain Emergency Action Levels Based on Emergency Preparedness Program Frequently Asked Questions (Epfaqs) RS-16-197, License Amendment Request for a One-Time Extension of the Essential Service Water (SX) Train Completion Time to Support 2A SX Pump Repair2016-09-30030 September 2016 License Amendment Request for a One-Time Extension of the Essential Service Water (SX) Train Completion Time to Support 2A SX Pump Repair RS-16-040, Report on Status of Decommissioning Funding2016-02-0404 February 2016 Report on Status of Decommissioning Funding ML16008A1172016-01-20020 January 2016 U.S. Nuclear Regulatory Commission Analysis of Excelon Generation'S Decommissioning Funding Status Report RS-15-094, (EGC) - Submittal of Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2015-03-31031 March 2015 (EGC) - Submittal of Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations RS-15-077, Submittal of Updated Site Specific Safstor Decommissioning Cost Estimates for Braidwood, Byron and LaSalle Stations2015-02-19019 February 2015 Submittal of Updated Site Specific Safstor Decommissioning Cost Estimates for Braidwood, Byron and LaSalle Stations ML13161A2232013-06-0303 June 2013 Byron and Braidwood, Units 1 and 2 - License Renewal Application RS-13-106, (EGC) Amended 2011 Report on Status of Decommissioning Funding for Reactors and Correction to July 27, 2011 RAI Response2013-04-12012 April 2013 (EGC) Amended 2011 Report on Status of Decommissioning Funding for Reactors and Correction to July 27, 2011 RAI Response RS-13-100, Report on Status of Decommissioning Funding for Reactors2013-04-0101 April 2013 Report on Status of Decommissioning Funding for Reactors RS-13-064, Submittal of Updated Clinton Power Station Site-Specific Safstor Decommissioning Cost Estimate2013-03-0101 March 2013 Submittal of Updated Clinton Power Station Site-Specific Safstor Decommissioning Cost Estimate ML1206604942012-03-30030 March 2012 Issuance of Amendments Revision of Technical Specifications (TS) 3.3.1, Reactor Trip System Instrumentation, and TS 3.3.2, Engineered Safety Feature Actuation System Instrumentation (TAC ME5836... ML1001202412010-01-11011 January 2010 Submittal of Braidwood Station Site-Specific Safstor Decommissioning Cost Estimate RS-09-157, Submittal of Site-Specific Safstor Decommissioning Cost Estimate2009-11-16016 November 2009 Submittal of Site-Specific Safstor Decommissioning Cost Estimate RS-09-114, Site-Specific Safstor Decommissioning Cost Estimate2009-08-27027 August 2009 Site-Specific Safstor Decommissioning Cost Estimate ML0921201652009-07-29029 July 2009 Decommissioning Funding Assurance Plan RS-09-095, Decommissioning Funding Assurance Plan2009-07-29029 July 2009 Decommissioning Funding Assurance Plan RS-09-041, Submittal of Exelon Generation Company, LLC, Report on Status of Decommissioning Funding for Reactors Owned by EGC2009-03-31031 March 2009 Submittal of Exelon Generation Company, LLC, Report on Status of Decommissioning Funding for Reactors Owned by EGC RS-08-036, License Amendment Request to Revise Containment Tendon Surveillance Program2008-04-0909 April 2008 License Amendment Request to Revise Containment Tendon Surveillance Program RS-06-176, Site-Specific Decommissioning Cost Estimates2006-12-18018 December 2006 Site-Specific Decommissioning Cost Estimates RS-03-106, Supplement to Request for Amendment to TS Surveillance Requirement 3.6.1.3.82003-06-10010 June 2003 Supplement to Request for Amendment to TS Surveillance Requirement 3.6.1.3.8 RS-02-045, Request for License Amendment for Technical Specifications Surveillance Requirement for Containment Spray Nozzles2002-04-19019 April 2002 Request for License Amendment for Technical Specifications Surveillance Requirement for Containment Spray Nozzles ML0208801152002-03-19019 March 2002 Request for a License Amendment to Modify the Method of Controlling Unfavorable Exposure Time Related to an Anticipated Transient Without Scram Event for Byron and Braidwood Station 2023-03-23
[Table view] Category:50
MONTHYEARRS-23-049, Constellation Energy Generation, LLC, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2023-03-23023 March 2023 Constellation Energy Generation, LLC, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations RS-22-055, Submittal of Preliminary Decommissioning Cost Estimate and Spent Fuel Management Plan2022-04-18018 April 2022 Submittal of Preliminary Decommissioning Cost Estimate and Spent Fuel Management Plan RS-21-032, Amended Decommissioning Trust Agreements2021-02-25025 February 2021 Amended Decommissioning Trust Agreements RS-21-030, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2021-02-24024 February 2021 Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations NMP1L3371, Summary of Changes, Quality Assurance Topical Report, NO-AA-10 & Decommissioning Quality Assurance Program, NO-DC-102021-02-10010 February 2021 Summary of Changes, Quality Assurance Topical Report, NO-AA-10 & Decommissioning Quality Assurance Program, NO-DC-10 RS-19-045, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2019-04-0101 April 2019 Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations RS-16-040, Report on Status of Decommissioning Funding2016-02-0404 February 2016 Report on Status of Decommissioning Funding ML16008A1172016-01-20020 January 2016 U.S. Nuclear Regulatory Commission Analysis of Excelon Generation'S Decommissioning Funding Status Report RS-15-094, (EGC) - Submittal of Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2015-03-31031 March 2015 (EGC) - Submittal of Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations RS-15-077, Submittal of Updated Site Specific Safstor Decommissioning Cost Estimates for Braidwood, Byron and LaSalle Stations2015-02-19019 February 2015 Submittal of Updated Site Specific Safstor Decommissioning Cost Estimates for Braidwood, Byron and LaSalle Stations RS-13-106, (EGC) Amended 2011 Report on Status of Decommissioning Funding for Reactors and Correction to July 27, 2011 RAI Response2013-04-12012 April 2013 (EGC) Amended 2011 Report on Status of Decommissioning Funding for Reactors and Correction to July 27, 2011 RAI Response RS-13-100, Report on Status of Decommissioning Funding for Reactors2013-04-0101 April 2013 Report on Status of Decommissioning Funding for Reactors RS-13-064, Submittal of Updated Clinton Power Station Site-Specific Safstor Decommissioning Cost Estimate2013-03-0101 March 2013 Submittal of Updated Clinton Power Station Site-Specific Safstor Decommissioning Cost Estimate ML1001202412010-01-11011 January 2010 Submittal of Braidwood Station Site-Specific Safstor Decommissioning Cost Estimate RS-09-157, Submittal of Site-Specific Safstor Decommissioning Cost Estimate2009-11-16016 November 2009 Submittal of Site-Specific Safstor Decommissioning Cost Estimate RS-09-114, Site-Specific Safstor Decommissioning Cost Estimate2009-08-27027 August 2009 Site-Specific Safstor Decommissioning Cost Estimate RS-09-095, Decommissioning Funding Assurance Plan2009-07-29029 July 2009 Decommissioning Funding Assurance Plan ML0921201652009-07-29029 July 2009 Decommissioning Funding Assurance Plan RS-09-041, Submittal of Exelon Generation Company, LLC, Report on Status of Decommissioning Funding for Reactors Owned by EGC2009-03-31031 March 2009 Submittal of Exelon Generation Company, LLC, Report on Status of Decommissioning Funding for Reactors Owned by EGC RS-06-176, Site-Specific Decommissioning Cost Estimates2006-12-18018 December 2006 Site-Specific Decommissioning Cost Estimates 2023-03-23
[Table view] Category:70
MONTHYEARRS-23-049, Constellation Energy Generation, LLC, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2023-03-23023 March 2023 Constellation Energy Generation, LLC, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations RS-22-055, Submittal of Preliminary Decommissioning Cost Estimate and Spent Fuel Management Plan2022-04-18018 April 2022 Submittal of Preliminary Decommissioning Cost Estimate and Spent Fuel Management Plan RS-22-014, Application to Adopt TSTF-246, RTS Instrumentation, 3.3.1 Condition F Completion Time2022-03-24024 March 2022 Application to Adopt TSTF-246, RTS Instrumentation, 3.3.1 Condition F Completion Time RS-21-063, Application to Adopt TSTF-554, Revision 1, Revise Reactor Coolant Leakage Requirements2021-06-30030 June 2021 Application to Adopt TSTF-554, Revision 1, Revise Reactor Coolant Leakage Requirements RS-21-032, Amended Decommissioning Trust Agreements2021-02-25025 February 2021 Amended Decommissioning Trust Agreements RS-21-030, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2021-02-24024 February 2021 Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations NMP1L3371, Summary of Changes, Quality Assurance Topical Report, NO-AA-10 & Decommissioning Quality Assurance Program, NO-DC-102021-02-10010 February 2021 Summary of Changes, Quality Assurance Topical Report, NO-AA-10 & Decommissioning Quality Assurance Program, NO-DC-10 RS-21-005, Request for License Amendment to Revise Degraded Voltage Relay Allowable Values2021-01-20020 January 2021 Request for License Amendment to Revise Degraded Voltage Relay Allowable Values RS-20-052, Application to Revise Technical Specifications to Adopt Risk Informed Completion Times TSTF-505, Revision 2, Provide Risk-Informed Extended Completion Extended Completed Times-RITSTF Initiative 4b2020-04-30030 April 2020 Application to Revise Technical Specifications to Adopt Risk Informed Completion Times TSTF-505, Revision 2, Provide Risk-Informed Extended Completion Extended Completed Times-RITSTF Initiative 4b RS-20-016, County, Nine Mile Point, Peach Bottom Atomic and Quad Cities - Application to Revise Technical Specifications to Adopt TSTF-566, Revise Actions for Inoperable RHR Shutdown Cooling Systems2020-04-13013 April 2020 County, Nine Mile Point, Peach Bottom Atomic and Quad Cities - Application to Revise Technical Specifications to Adopt TSTF-566, Revise Actions for Inoperable RHR Shutdown Cooling Systems RS-19-045, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2019-04-0101 April 2019 Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations RS-19-022, License Amendment Request - Clarifying Changes for Certain Emergency Action Levels Based on Emergency Preparedness Program Frequently Asked Questions (Epfaqs)2019-03-0101 March 2019 License Amendment Request - Clarifying Changes for Certain Emergency Action Levels Based on Emergency Preparedness Program Frequently Asked Questions (Epfaqs) RS-16-197, License Amendment Request for a One-Time Extension of the Essential Service Water (SX) Train Completion Time to Support 2A SX Pump Repair2016-09-30030 September 2016 License Amendment Request for a One-Time Extension of the Essential Service Water (SX) Train Completion Time to Support 2A SX Pump Repair RS-16-040, Report on Status of Decommissioning Funding2016-02-0404 February 2016 Report on Status of Decommissioning Funding ML16008A1172016-01-20020 January 2016 U.S. Nuclear Regulatory Commission Analysis of Excelon Generation'S Decommissioning Funding Status Report RS-15-094, (EGC) - Submittal of Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2015-03-31031 March 2015 (EGC) - Submittal of Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations RS-15-077, Submittal of Updated Site Specific Safstor Decommissioning Cost Estimates for Braidwood, Byron and LaSalle Stations2015-02-19019 February 2015 Submittal of Updated Site Specific Safstor Decommissioning Cost Estimates for Braidwood, Byron and LaSalle Stations ML13161A2232013-06-0303 June 2013 Byron and Braidwood, Units 1 and 2 - License Renewal Application RS-13-106, (EGC) Amended 2011 Report on Status of Decommissioning Funding for Reactors and Correction to July 27, 2011 RAI Response2013-04-12012 April 2013 (EGC) Amended 2011 Report on Status of Decommissioning Funding for Reactors and Correction to July 27, 2011 RAI Response RS-13-100, Report on Status of Decommissioning Funding for Reactors2013-04-0101 April 2013 Report on Status of Decommissioning Funding for Reactors RS-13-064, Submittal of Updated Clinton Power Station Site-Specific Safstor Decommissioning Cost Estimate2013-03-0101 March 2013 Submittal of Updated Clinton Power Station Site-Specific Safstor Decommissioning Cost Estimate ML1206604942012-03-30030 March 2012 Issuance of Amendments Revision of Technical Specifications (TS) 3.3.1, Reactor Trip System Instrumentation, and TS 3.3.2, Engineered Safety Feature Actuation System Instrumentation (TAC ME5836... ML1001202412010-01-11011 January 2010 Submittal of Braidwood Station Site-Specific Safstor Decommissioning Cost Estimate RS-09-157, Submittal of Site-Specific Safstor Decommissioning Cost Estimate2009-11-16016 November 2009 Submittal of Site-Specific Safstor Decommissioning Cost Estimate RS-09-114, Site-Specific Safstor Decommissioning Cost Estimate2009-08-27027 August 2009 Site-Specific Safstor Decommissioning Cost Estimate ML0921201652009-07-29029 July 2009 Decommissioning Funding Assurance Plan RS-09-095, Decommissioning Funding Assurance Plan2009-07-29029 July 2009 Decommissioning Funding Assurance Plan RS-09-041, Submittal of Exelon Generation Company, LLC, Report on Status of Decommissioning Funding for Reactors Owned by EGC2009-03-31031 March 2009 Submittal of Exelon Generation Company, LLC, Report on Status of Decommissioning Funding for Reactors Owned by EGC RS-08-036, License Amendment Request to Revise Containment Tendon Surveillance Program2008-04-0909 April 2008 License Amendment Request to Revise Containment Tendon Surveillance Program RS-06-176, Site-Specific Decommissioning Cost Estimates2006-12-18018 December 2006 Site-Specific Decommissioning Cost Estimates RS-03-106, Supplement to Request for Amendment to TS Surveillance Requirement 3.6.1.3.82003-06-10010 June 2003 Supplement to Request for Amendment to TS Surveillance Requirement 3.6.1.3.8 RS-02-045, Request for License Amendment for Technical Specifications Surveillance Requirement for Containment Spray Nozzles2002-04-19019 April 2002 Request for License Amendment for Technical Specifications Surveillance Requirement for Containment Spray Nozzles ML0208801152002-03-19019 March 2002 Request for a License Amendment to Modify the Method of Controlling Unfavorable Exposure Time Related to an Anticipated Transient Without Scram Event for Byron and Braidwood Station 2023-03-23
[Table view] Category:Letter type:RS
MONTHYEARRS-24-064, Nuclear Radiological Emergency Plan Document Revisions2024-06-28028 June 2024 Nuclear Radiological Emergency Plan Document Revisions RS-24-066, Inservice Testing Interval Extension for Essential Service Water Valves Due to Required Use of Containment Chiller2024-06-25025 June 2024 Inservice Testing Interval Extension for Essential Service Water Valves Due to Required Use of Containment Chiller RS-24-061, Constellation Energy Generation, LLC, Response to NRC Regulatory Issue Summary 2024-01, Preparation and Scheduling of Operator Licensing Examinations2024-06-14014 June 2024 Constellation Energy Generation, LLC, Response to NRC Regulatory Issue Summary 2024-01, Preparation and Scheduling of Operator Licensing Examinations RS-24-057, License Amendment to Technical Specification 3.7.9, Ultimate Heat Sink2024-06-0404 June 2024 License Amendment to Technical Specification 3.7.9, Ultimate Heat Sink RS-24-044, License Amendment to Transition to Framatome Gaia Fuel and Exemptions to 10 CFR 50.46 and 10 CFR 50 Appendix K. Attachments 1 to 11 Enclosed2024-05-28028 May 2024 License Amendment to Transition to Framatome Gaia Fuel and Exemptions to 10 CFR 50.46 and 10 CFR 50 Appendix K. Attachments 1 to 11 Enclosed RS-24-043, Application to Remove Power Distribution Monitoring System (Pdms) Details from Technical Specifications2024-05-24024 May 2024 Application to Remove Power Distribution Monitoring System (Pdms) Details from Technical Specifications RS-24-055, 2023 Corporate Regulatory Commitment Change Summary Report2024-05-17017 May 2024 2023 Corporate Regulatory Commitment Change Summary Report RS-24-050, Additional Information Supporting Request for License Amendment to Revise Technical Specifications Related to Reactor Water Cleanup Isolation Instrumentation2024-05-0909 May 2024 Additional Information Supporting Request for License Amendment to Revise Technical Specifications Related to Reactor Water Cleanup Isolation Instrumentation RS-24-038, Relief Request Concerning Extension of Permanent Relief from Ultrasonic Examination of Reactor Pressure Vessel Circumferential Shell Welds2024-05-0202 May 2024 Relief Request Concerning Extension of Permanent Relief from Ultrasonic Examination of Reactor Pressure Vessel Circumferential Shell Welds RS-24-041, Alternative Request to Utilize Code Case OMN-32, Alternative Requirements for Range and Accuracy of Pressure, Flow, and Differential Pressure Instruments Used in Pump Tests2024-04-30030 April 2024 Alternative Request to Utilize Code Case OMN-32, Alternative Requirements for Range and Accuracy of Pressure, Flow, and Differential Pressure Instruments Used in Pump Tests RS-24-026, License Amendment to Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, Technical Specifications 5.6.5, Core Operating Limits Report (COLR)2024-04-25025 April 2024 License Amendment to Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, Technical Specifications 5.6.5, Core Operating Limits Report (COLR) RS-24-004, Proposed Alternative to the Distribution Requirements of ASME Code Table IWC-2411-1 for the Steam Generators2024-01-11011 January 2024 Proposed Alternative to the Distribution Requirements of ASME Code Table IWC-2411-1 for the Steam Generators RS-23-120, Supplemental Information Letter for Part 73 Exemption Request - Responses to Request for Confirmatory Information2023-11-10010 November 2023 Supplemental Information Letter for Part 73 Exemption Request - Responses to Request for Confirmatory Information RS-23-118, Supplemental Information Letter for Part 73 Exemption Request - Responses to Request for Confirmatory Information2023-11-10010 November 2023 Supplemental Information Letter for Part 73 Exemption Request - Responses to Request for Confirmatory Information RS-23-117, Supplemental Information Letter for Part 73 Exemption Request - Responses to Request for Confirmatory Information2023-11-10010 November 2023 Supplemental Information Letter for Part 73 Exemption Request - Responses to Request for Confirmatory Information RS-23-114, Proposed Alternative for Examination of Pressurizer Circumferential and Longitudinal Shell-to-Head Welds and Nozzle-to-Vessel Welds2023-11-0101 November 2023 Proposed Alternative for Examination of Pressurizer Circumferential and Longitudinal Shell-to-Head Welds and Nozzle-to-Vessel Welds RS-23-100, Request for Exemption from Enhanced Weapons, Firearms Background Checks, and Security Event Notifications Implementation2023-10-13013 October 2023 Request for Exemption from Enhanced Weapons, Firearms Background Checks, and Security Event Notifications Implementation RS-23-103, Request for Exemption from Enhanced Weapons, Firearms Background Checks, and Security Event Notifications Implementation2023-10-13013 October 2023 Request for Exemption from Enhanced Weapons, Firearms Background Checks, and Security Event Notifications Implementation RS-23-097, Constellation Energy Generation, LLC, Advisement of Leadership Changes and Submittal of Updated Standard Practice Procedures Plans2023-10-12012 October 2023 Constellation Energy Generation, LLC, Advisement of Leadership Changes and Submittal of Updated Standard Practice Procedures Plans RS-23-108, Proposed Alternative for Examinations of Examination Categories B-B, B-D, and C-A Steam Generator Pressure Retaining Welds and Full Penetration Welded Nozzles2023-10-11011 October 2023 Proposed Alternative for Examinations of Examination Categories B-B, B-D, and C-A Steam Generator Pressure Retaining Welds and Full Penetration Welded Nozzles RS-23-105, Proposed Alternative for Examinations of Examination Category C-B Steam Generator Nozzle-to-Shell Welds and Nozzle Inside Radius Sections2023-10-10010 October 2023 Proposed Alternative for Examinations of Examination Category C-B Steam Generator Nozzle-to-Shell Welds and Nozzle Inside Radius Sections RS-23-093, License Amendment to Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, Technical Specifications 3.7.15, Spent Fuel Pool Boron Concentration, 3.7.16, Spent Fuel.2023-09-29029 September 2023 License Amendment to Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, Technical Specifications 3.7.15, Spent Fuel Pool Boron Concentration, 3.7.16, Spent Fuel. RS-23-094, Relief Request I4R-24, Alternative for Post-Peening Reexamination Frequency for Reactor Pressure Vessel Head Penetration Nozzle Number 752023-09-29029 September 2023 Relief Request I4R-24, Alternative for Post-Peening Reexamination Frequency for Reactor Pressure Vessel Head Penetration Nozzle Number 75 RS-23-091, Relief Request I4R-25, Alternative Requirements for Reactor Pressure Vessel Inservice Inspection Intervals2023-09-26026 September 2023 Relief Request I4R-25, Alternative Requirements for Reactor Pressure Vessel Inservice Inspection Intervals RS-23-090, Annual Report of Emergency Core Cooling System Evaluation Model Changes and Errors for Clinton Power Station2023-09-0707 September 2023 Annual Report of Emergency Core Cooling System Evaluation Model Changes and Errors for Clinton Power Station RS-23-080, Constellation Energy Generation, LLC, Application to Revise Technical Specifications to Adopt TSTF-264-A, Revision 0, 3.3.9 and 3.3.10 - Delete Flux Monitors Specific Overlap Requirement SRs2023-08-30030 August 2023 Constellation Energy Generation, LLC, Application to Revise Technical Specifications to Adopt TSTF-264-A, Revision 0, 3.3.9 and 3.3.10 - Delete Flux Monitors Specific Overlap Requirement SRs RS-23-081, Request for License Amendment to Revise Technical Specifications Related to Reactor Water Cleanup Isolation Instrumentation2023-08-21021 August 2023 Request for License Amendment to Revise Technical Specifications Related to Reactor Water Cleanup Isolation Instrumentation RS-23-087, Revision to Approved Alternatives Associated with the Use of the BWRVIP Guidelines in Lieu of Specific ASME Code Requirements on Reactor2023-08-0404 August 2023 Revision to Approved Alternatives Associated with the Use of the BWRVIP Guidelines in Lieu of Specific ASME Code Requirements on Reactor RS-23-085, Supplemental Information Related to Request for Partial Site Release2023-08-0303 August 2023 Supplemental Information Related to Request for Partial Site Release RS-23-084, Response to Request for Additional Information Regarding the Application to Revise Design Basis to Allow Use of Plastic Section Properties in Lower Downcomer Braces Analysis2023-07-24024 July 2023 Response to Request for Additional Information Regarding the Application to Revise Design Basis to Allow Use of Plastic Section Properties in Lower Downcomer Braces Analysis RS-23-083, Withdrawal - Proposed Alternatives Related to the Steam Generators2023-06-27027 June 2023 Withdrawal - Proposed Alternatives Related to the Steam Generators RS-23-077, Response to NRC Regulatory Issue Summary 2023-01, Preparation and Scheduling of Operator Licensing Examinations2023-06-16016 June 2023 Response to NRC Regulatory Issue Summary 2023-01, Preparation and Scheduling of Operator Licensing Examinations RS-23-074, Supplement to Application for License Amendment to Braidwood Station, Units 1 and 2, Technical Specification 3.7.9, Ultimate Heat Sink2023-06-0909 June 2023 Supplement to Application for License Amendment to Braidwood Station, Units 1 and 2, Technical Specification 3.7.9, Ultimate Heat Sink RS-23-073, Request for Partial Site Release2023-06-0707 June 2023 Request for Partial Site Release RS-23-075, Application for Technical Specification Improvement to Extend the Completion Time for Condition B of Technical Specification 3.5.1, Accumulators, Using the Consolidated Line Item Improvement Process2023-06-0707 June 2023 Application for Technical Specification Improvement to Extend the Completion Time for Condition B of Technical Specification 3.5.1, Accumulators, Using the Consolidated Line Item Improvement Process RS-23-042, Application to Revise Technical Specifications to Adopt TSTF-580, Provide Exception from Entering Mode 4 with No Operable RHR Shutdown Cooling2023-05-25025 May 2023 Application to Revise Technical Specifications to Adopt TSTF-580, Provide Exception from Entering Mode 4 with No Operable RHR Shutdown Cooling RS-23-050, Supplement to Application to Revise Technical Specifications to Adopt TSTF-577, Revised Frequencies for Steam Generator Tube.2023-05-22022 May 2023 Supplement to Application to Revise Technical Specifications to Adopt TSTF-577, Revised Frequencies for Steam Generator Tube. RS-23-056, Response to Request for Additional Information to Braidwood Station, Unit 1, and Byron Station, Unit 1, for Steam Generator License Renewal Response to Commitment 102023-04-20020 April 2023 Response to Request for Additional Information to Braidwood Station, Unit 1, and Byron Station, Unit 1, for Steam Generator License Renewal Response to Commitment 10 RS-23-055, Annual 10 CFR 50.46 Report of Emergency Core Cooling System Evaluation Model Changes and Errors2023-04-10010 April 2023 Annual 10 CFR 50.46 Report of Emergency Core Cooling System Evaluation Model Changes and Errors RS-23-052, License Amendment to Braidwood Station, Units 1 and 2, Technical Specification 3.7.9, Ultimate Heat Sink2023-03-24024 March 2023 License Amendment to Braidwood Station, Units 1 and 2, Technical Specification 3.7.9, Ultimate Heat Sink RS-23-049, Constellation Energy Generation, LLC, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations2023-03-23023 March 2023 Constellation Energy Generation, LLC, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations RS-23-048, Exigent Amendment Request to Revise Design Basis Related to Seismic Requirements2023-03-0707 March 2023 Exigent Amendment Request to Revise Design Basis Related to Seismic Requirements RS-23-039, Request for License Amendment to Revise Technical Specifications Section 3.8.3, Diesel Fuel Oil, Lube Oil, and Starting Air2023-03-0101 March 2023 Request for License Amendment to Revise Technical Specifications Section 3.8.3, Diesel Fuel Oil, Lube Oil, and Starting Air RS-23-045, Constellation Energy Generation, LLC Submittal of Fitness for Duty Performance Data Reports for 2022 Per 10 CFR 26.717(c) & 10 CFR 26.2032023-02-28028 February 2023 Constellation Energy Generation, LLC Submittal of Fitness for Duty Performance Data Reports for 2022 Per 10 CFR 26.717(c) & 10 CFR 26.203 RS-23-038, Response to Request for Additional Information for the Byron Proposal to Reinsert an Accident Tolerant Fuel Lead Test Assembly2023-02-27027 February 2023 Response to Request for Additional Information for the Byron Proposal to Reinsert an Accident Tolerant Fuel Lead Test Assembly RS-23-037, Annual 10 CFR 50.46 Report of Emergency Core Cooling System Evaluation Model Changes and Errors for LaSalle County Station2023-02-22022 February 2023 Annual 10 CFR 50.46 Report of Emergency Core Cooling System Evaluation Model Changes and Errors for LaSalle County Station RS-23-040, Constellation Energy Generation, LLC, Supplemental Information - Proposed Alternatives Related to the Steam Generators2023-02-21021 February 2023 Constellation Energy Generation, LLC, Supplemental Information - Proposed Alternatives Related to the Steam Generators RS-23-003, Constellation Energy Generation, LLC, Summary of Changes to Quality Assurance Topical Report, NO-AA-10, and Decommissioning Quality Assurance Program, NO-DC-102023-01-31031 January 2023 Constellation Energy Generation, LLC, Summary of Changes to Quality Assurance Topical Report, NO-AA-10, and Decommissioning Quality Assurance Program, NO-DC-10 RS-23-002, Application to Adopt TSTF-332, ECCS Response Time Testing2023-01-13013 January 2023 Application to Adopt TSTF-332, ECCS Response Time Testing RS-22-085, Application to Revise Design Basis to Allow Use of Plastic Section Properties in Lower Downcomer Braces Analysis2023-01-12012 January 2023 Application to Revise Design Basis to Allow Use of Plastic Section Properties in Lower Downcomer Braces Analysis 2024-06-04
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Text
Exel' n Exelon Nuclear www.exeloncorp.com Nuclear 4300 Winfield Road Warrenville, IL 60555 10 CFR 50.75(f)(1)
RS-09-095 July 29, 2009 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Braidwood Station, Units 1 and 2 Facility Operating License Nos. NPF-72 and NPF-77 NRC Docket Nos. STN 50-456 and STN 50-457 Byron Station, Units 1 and 2 Facility Operating License Nos. NPF-37 and NPF-66 NRC Docket Nos. STN 50-454 and STN 50-455 Clinton Power Station Facility Operating License No. NPF-62 NRC Docket No. 50-461 LaSalle County Station, Units 1 and 2 Facility Operating License Nos. NPF-11 and NPF-18 NRC Docket Nos. 50-373 and 50-374
Subject:
Decommissioning Funding Assurance Plan
References:
See Attachment 1 In References 1 through 7, the NRC stated that they believe additional information is needed to demonstrate decommissioning funding assurance for Braidwood Station, Units 1 and 2, Byron Station, Units 1 and 2, Clinton Power Station, and LaSalle County Station, Units 1 and 2. The NRC's position was based on an internal review using the generic decommissioning funding assurance formula from 10 CFR 50.75(c), and the decommissioning trust fund values as of December 31, 2008, as reported by Exelon Generation Company, LLC (EGC) in Reference
- 8. As requested in References 1 through 7, and a subsequent conference call between EGC and the NRC on July 1, 2009, EGC agreed to submit a plan by July 31, 2009, to show adequate decommissioning funding assurance.
The plan to show adequate decommissioning July 29, 2009 U.S. Nuclear Regulatory Commission Page 2 funding assurance is described below. The actions detailed in the plan are summarized in Attachment 2.Braidwood Station, Units 1 and 2, Byron Station, Units 1 and 2 On March 31, 2009 (Reference 8), EGC submitted the amount of funds required for radiological decommissioning based on a site-specific SAFSTOR estimate for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, as allowed by 10 CFR 50.75(e)(1)(i).
These site-specific estimates were submitted to the NRC by EGC on December 18, 2006 (Reference 9). The decommissioning funding assurance illustrated by these site-specific estimates was accepted by the NRC on April 24, 2007 (Reference 10). Based on these site-specific cost estimates, and the decommissioning trust fund values as of December 31, 2008, for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, there was a difference in the amount required for decommissioning funding assurance and the trust fund values. EGC calculated the difference as of December 31, 2008 as $53.5M for Braidwood Station Unit 1, $35.1 M for Braidwood Station Unit 2, $41.3M for Byron Station Unit 1, and $40.5M for Byron Station Unit 2. The determinations herein of decommissioning funding assurance differences reflect the difference between fund values as of a specified date and the funding levels determined for NRC decommissioning funding assurance consistent with 10 CFR 50.75(e)(1)(i).
As part of EGC's normal, 5-year cycle for updating decommissioning cost estimates, as specified in Regulatory Guide 1.159, Revision 1, Section 1.4.3, EGC is updating the site-specific cost estimate for both Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, in 2009. EGC expects a reduction in the site-specific SAFSTOR radiological decommissioning costs, based on the results of other EGC estimates completed during this cycle. This reduction is expected mainly due to a reduction in the waste disposal costs for Class A waste, which will now be sent to the EnergySolutions site in Clive, Utah, per EGC's contract with EnergySolutions.
EGC will submit the new site-specific SAFSTOR decommissioning cost estimates to the NRC. Based on the schedule for completing these site-specific cost estimates, the NRC submittals will occur by November 20, 2009, for Byron Station, Units 1 and 2, and by January 15, 2010, for Braidwood Station, Units 1 and 2.If the site-specific cost estimates for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, coupled with trust fund values, do not illustrate adequate decommissioning funding assurance, EGC will establish additional decommissioning funding assurance using a guarantee method, as allowed by NRC regulations, on or before April 1, 2010, and upon approval by the EGC Board of Directors.
The additional funding assurance will be calculated based on the funds required for radiological decommissioning considering the site-specific SAFSTOR estimates and the decommissioning trust fund values as of December 31, 2009.As stated above, the initial amount of any additional decommissioning funding assurance will be calculated as of December 31, 2009. Any additional funding assurance not in the form of cash contributions directly into the decommissioning trust July 29, 2009 U.S. Nuclear Regulatory Commission Page 3 funds (10 CFR 50.75(e)(1)(i)), will be provided in the form of a guarantee (10 CFR 50.75(e)(1)(iii))
to be recalculated on an annual basis (as of December 31). The value of the guarantee will be adjusted, if necessary, in accordance with those calculations by April 1 of the following year. Consistent with 10 CFR 30, Appendix A, any financial tests required for the guarantee will also be re-verified on an annual basis, and the form of the guarantee will continue to meet all NRC regulations.
As such, decommissioning funding assurance will be provided through a combination of acceptable funding methods.Also, it is important to note that the value of the decommissioning trust funds has increased to a value of $177.2M for Braidwood Station Unit 1, $196.3M for Braidwood Station Unit 2, $199.1 M for Byron Station Unit 1, and $193.OM for Byron Station Unit 2, as of June 30, 2009, providing additional decommissioning funding assurance margin.Clinton Power Station On March 31, 2009 (Reference 8), EGC submitted the amount of funds required for radiological decommissioning based on a site-specific SAFSTOR estimate for Clinton Power Station, as allowed by 10 CFR 50.75(e)(1)(i).
Based on this site-specific cost estimate and the decommissioning trust fund value as of December 31, 2008, for Clinton Power Station, there was a very small difference in the amount required for decommissioning funding assurance.
Further, in conjunction with the Clinton Power Station license transfer from AmerGen Energy Company, LLC to EGC, EGC established a Parental Guarantee from Exelon Corporation in the amount of $151,758.34.
A copy of this Parental Guarantee is included as Attachment 3.The site-specific estimate and Parental Guarantee show adequate decommissioning funding assurance exists for Clinton Power Station. EGC will submit the Clinton Power Station site-specific SAFSTOR decommissioning cost estimate to the NRC by August 28, 2009. EGC concludes that no other action is required to show adequate decommissioning funding assurance for Clinton Power Station.Furthermore, based on the Clinton Power Station trust fund value as of June 30, 2009, of $303.2M, the Parental Guarantee is no longer required to show adequate decommissioning funding assurance.
Therefore, this letter also serves as notice to the NRC that Exelon intends to cancel the Parental Guarantee.
This cancellation will not occur until after 120 days of this notice, as specified by 10 CFR 30, Appendix A.LaSalle County Station, Units 1 and 2 On March 31, 2009 (Reference 8), EGC submitted the amount of funds required for radiological decommissioning based on a site-specific SAFSTOR estimate for LaSalle County Station, Units 1 and 2, as allowed by 10 CFR 50.75(e)(1)(i).
This site-specific estimate was submitted to the NRC by EGC on December 18, 2006 (Reference 9). The decommissioning funding assurance illustrated by this site-specific estimate was accepted by the NRC on April 24, 2007 (Reference 10). Based on this site-specific cost estimate and the decommissioning trust fund value as of December 31, 2008, for July 29, 2009 U.S. Nuclear Regulatory Commission Page 4 LaSalle County Station, Units 1 and 2, there was a small difference in the amount required for decommissioning funding assurance and the trust funds values. EGC calculated the difference as of December 31, 2008 as $9.5M for LaSalle County Station Unit 1, and $3.8M for LaSalle County Station Unit 2.As part of the normal, 5-year cycle for updating decommissioning cost estimates, as specified in Regulatory Guide 1.159, Revision 1, Section 1.4.3, EGC is updating the site-specific cost estimate for LaSalle County Station, Units 1 and 2 in 2009. This cost estimate was completed in June 2009, and shows a reduction in the overall SAFSTOR decommissioning costs. This reduction is mainly due to a reduction in the waste disposal costs for Class A waste, which will now be sent to the EnergySolutions site in Clive Utah, per EGC's contract with EnergySolutions.
The new site-specific estimate provides adequate decommissioning funding assurance for LaSalle County Station, Units 1 and 2. Therefore, EGC will submit the new LaSalle County Station, Units 1 and 2, site-specific SAFSTOR decommissioning cost estimate to the NRC by August 28, 2009. EGC concludes that no other action is required to show adequate decommissioning funding assurance for LaSalle County Station, Units 1 and 2.Also, it is important to note that the value of the decommissioning trust funds has increased to a value of $276.8M for LaSalle County Station, Unit 1, and $269.4M for LaSalle County Station, Unit 2, as of June 30, 2009, providing additional decommissioning funding assurance margin.In summary, EGC's plan is to put the above actions in place to meet NRC minimum funding assurance requirements.
EGC remains confident that sufficient funds will be available to decommission all EGC sites when required.
For these sites, the current license expiration dates are at least 13 years away. Further, up to an additional 60 years can be used to safely decommission these sites. This additional time allows for the accumulation of earnings on the funds, as permitted by NRC regulations, such that adequate decommissioning funding assurance is provided for each of the above plants.Furthermore, EGC intends to pursue a 20-year license extension for all of these sites, allowing yet an additional 20 years of fund returns before decommissioning commences; thereby, providing further decommissioning funding assurance.
Regulatory commitments are contained in Attachment 2 of this letter.If you have any questions about this letter, please contact Patrick Simpson at (630) 657-2823.Res~cfully, Keith R. Jury Vice President
-Licensing and Regulatory Affairs Exelon Generation Company, LLC Attachments ATTACHMENT 1 REFERENCES
- 1. Letter from Marshall J. David (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Braidwood Station, Unit 1 ," dated June 18, 2009 2. Letter from Marshall J. David (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Braidwood Station, Unit 2," dated June 18, 2009 3. Letter from Marshall J. David (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Byron Station, Unit 1 ," dated June 18, 2009 4. Letter from Marshall J. David (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Byron Station, Unit 2," dated June 18, 2009 5. Letter from Stephen P. Sands (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for Clinton Power Station, Unit 1," dated June 18, 2009 6. Letter from Stephen P. Sands (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for LaSalle County Station, Unit 1 ," dated June 18, 2009 7. Letter from Stephen P. Sands (U.S. NRC) to Charles G. Pardee (Exelon Generation Company, LLC), "Exelon Generation Company, LLC's Status of Decommissioning Funding Assurance for LaSalle County Station, Unit 2," dated June 18, 2009 8. Letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U.S. NRC,"Report of Status of Decommissioning Funding for Reactors," dated March 31, 2009 9. Letter from Kenneth A. Ainger (Exelon Generation Company, LLC) to U.S. NRC,"Site-specific Decommissioning Cost Estimates," dated December 18, 2006 10. Letter from Christopher Gratton (U.S. NRC) to Christopher M. Crane (Exelon Generation Company, LLC), "Braidwood Station, Units 1 and 2; Byron Station, Units 1 and 2; and LaSalle County Station, Units 1 and 2 -Review of Site-Specific Decommissioning Cost Estimates," dated April 24, 2007 ATTACHMENT 2 Regulatory Commitments The following list identifies those actions committed to by Exelon Generation Company, LLC, (EGC) in this submittal.
Any other actions discussed in the submittal represent intended or planned actions by EGO, are described only for information, and are not regulatory commitments.
COMMITMENT TYPE COMMITMENT COMMITTED DATE ONE-TIME PROGRAM-OR "OUTAGE" ACTION MATIC (YES/NO) (YES/NO)Provide site-specific SAFSTOR August 28, 2009 Yes No decommissioning cost estimate for Clinton Power Station Provide site-specific SAFSTOR decommissioning cost estimates August 28, 2009 Yes No for LaSalle County Station, Units 1 and 2 Provide site-specific SAFSTOR decommissioning cost estimates for Byron Station, Units 1 and 2 Provide site-specific SAFSTOR January 15, 2010 Yes No decommissioning cost estimates for Braidwood Station, Units 1 and 2 Obtain approval from EGC Board First Quarter 2010 Yes No of Directors of any required additional guarantee in the amount necessary to provide adequate funding assurance for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, based on site-specific SAFSTOR decommissioning cost estimates and decommissioning trust fund values as of December 31, 2009 Establish guarantee, as allowed April 1 2010 Yes No by NRC regulations, for any difference in funding assurance for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, based on site-specific SAFSTOR decommissioning cost estimates and decommissioning trust fund values as of December 31, 2009 COMMITMENT TYPE COMMITMENT COMMITTED DATE ONE-TIME PROGRAM-OR "OUTAGE" ACTION MATIC (YES/NO) (YES/NO)Any additional funding assurance Ongoing No Yes for Braidwood Station, Units 1 and 2, and Byron Station, Units 1 and 2, provided in response to commitments in letter RS-09-095, not in the form of cash contributions directly into the decommissioning trust funds (10 CFR 50.75(e)(1)(i)), will be provided in the form of a guarantee (10 CFR 50.75(e)(1)(iii))
to be recalculated on an annual basis (as of December 31). The value of the guarantee will be adjusted, if necessary, in accordance with those calculations by April 1 of the followina year.
ATTACHMENT 3 PARENTAL GUARANTEE FOR CLINTON POWER STATION PARENT GUARANTEE NRC DECOMMISSIONING FUNDING ASSURANCE Guarantee made this January 8, 2009 by Exelon Corporation, a corporation organized under the laws of the Commonwealth of Pennsylvania, herein referred to as "guarantor," to the U.S.Nuclear Regulatory Commission (NRC), on behalf of our subsidiary Exelon Generation Company, LLC (ExGen) of 300 Exelon Way, Kennett Square, PA 19348, obligee.Recitals 1. The guarantor has full authority and capacity to enter into this guarantee pursuant to its bylaws, articles of incorporation, and the laws of Pennsylvania, its State of incorporation.
Guarantor has approval from its Board of Directors to enter into this guarantee.
- 2. This guarantee is being issued so that ExGen will be in compliance with regulations issued by the NRC, an agency of the U.S. Government, pursuant to the Atomic Energy Act of 1954, as amended and the Energy Reorganization Act of 1974. The NRC has promulgated regulations in Title 10, Chapter I of the Code of Federal Regulations, Part 50, which require that a holder of, or. an applicant for, a license issued pursuant to 10 CFR Part 50 provide assurance that funds will be available when needed for require decommissioning activities.
- 3. This guarantee is issued to provide financial assurance for a portion of the costs of decommissioning activities for Clinton Power Station as required by 10 CFR Part 50. The decommissioning costs for which the guarantee is issued are: $151,758.34.
- 4. The guarantor meets or exceeds the financial test criteria as stated in NRC 10 CFR 30 Appendix A Section II, and will comply with the notification requirements as specified in 10 CFR Part 50 and Appendix A to Part 30.
- 5. The guarantor is the sole member of Exelon Generation Company, LLC, the holder of NRC License No. NPF-62 for Clinton Power Station, V-852, RR3, Box 228, Clinton, IL 61727.6. Decommissioning activities as used below refers to the activities required by 10 CFR Part 50 for decommissioning of the facility(ies) identified above.7. For value received, and pursuant to the authority delegated to the officers of guarantor by its Board of Directors, the guarantor guarantees to the NRC that if the licensee fails to perform the required decommissioning activities, as required by License No. NPF-62, due to lack of funds, the guarantor shall either, as the guarantor shall determine:
- a. carry out the required activities, or b. provide all funds necessary, up to the amount of this guarantee specified in Section 3, to carry out the required activities, or c. set up a trust fund in favor of ExGen in the amount of these current cost estimates or guarantee amount for these activities.
- 8. The guarantor shall assure that its independent accountant submit revised financial statements, financial test data, and will perform the review specified in NRC 10 CFR 30 Appendix A Section II, B and C, and notify the NRC as required by these sections.9. The guarantor and the licensee agree that if the guarantor fails to meet the financial test criteria at any time after this guarantee is established, the guarantor and licensee shall send, within 90 days of the end of the fiscal year in which the guarantor fails to meet the financial test criteria, by certified mail, notice to the NRC. If ExGen fails to provide alternative financial assurance as specified in 10 CFR Part 50, as applicable, and obtain written approval of such assurance from the NRC within 180 days of the end of such fiscal year, the guarantor shall provide such alternative financial assurance in the name of ExGen or make full payment under the guarantee to a standby trust established by ExGen.
- 10. Independent of any notification under paragraph 8 above, if the NRC determines for any reason that the guarantor no longer meets the financial test criteria or that it is disallowed from continuing as guarantor for the facility under License No. NPF-62, the guarantor agrees that within 90 days after being notified by the NRC of such determination, an alternative financial assurance mechanism as specified in 10 CFR Part 50 as applicable, shall be established by the guarantor in the name of ExGen unless ExGen has done so.11. The guarantor as well as its successors and assigns agree to remain bound jointly and severally under this guarantee notwithstanding any or all of the following:
amendment or notification of license or NRC-approved decommissioning funding plan for that facility, the extension or reduction of the time of performance of required activities, or any other modification or alteration of an obligation of the licensee pursuant to 10 CFR Part 50.12. The guarantor agrees that it will be liable for all litigation costs incurred by ExGen or the NRC in any successful effort to enforce the agreement against the guarantor.
- 13. The guarantor agrees to remain bound under this guarantee for as long as ExGen must comply with the applicable financial assurance requirements of 10 CFR Part 50, for the previously listed facility(ies) except that the guarantor may cancel this guarantee by sending certified mail to the NRC and to ExGen, such cancellation to become effective no earlier than 120 days after receipt of such notice by both the NRC and ExGen as evidenced by the return receipts.
If the licensee fails to provide alternative financial assurance as specified in 10 CFR Part 50, as applicable, and obtain written approval of such assurance within 120 days after the sending of the above notice by the guarantor, the guarantor shall provide such alternative financial assurance.
- 14. The guarantor expressly waives notice of acceptance of this guarantee by the NRC or by ExGen. The guarantor also expressly waives notice of amendments or modification of the decommissioning requirements and of amendments or modifications of the license.
- 15. If the guarantor files annual financial reports with the U.S. Securities and Exchange Commission, then it shall promptly submit them to the NRC during each year in which this guarantee is in effect.I herby certify that this guarantee is true and correct to the best of my knowledge.
Effective date: ,AIL~~JQj.k Signature of witness or notary: Exelon Generation Company, L OFFICIAL SEAL Maria Dolores Munguia Notary Public, State of Illinois Commission Expires 04/04/2012"jnstopher M Crane President and Chief Operating Officer Signature of witness or notary: ,4 , i,-OFFICIAL SEAL Maria Dolores Munguia Notary Public, State of Illinois Commission Expires 04/04/2012