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MONTHYEARML22207A0492022-07-25025 July 2022 Information Request, Security IR 2022402 NLS2021035, Attachment/Enclosureport of Change and Summary of 50.54(q) Analysis - On-Shift Staffing Analysis, Rev. 32021-05-10010 May 2021 Attachment/Enclosureport of Change and Summary of 50.54(q) Analysis - On-Shift Staffing Analysis, Rev. 3 NLS2016063, Enclosure 2: Response to Areas of Requested Information in Appendix a of Generic Letter 2016-01, Monitoring of Neutron-Absorbing Materials in Spent Fuel Pools (Non-Proprietary Version)2016-10-27027 October 2016 Enclosure 2: Response to Areas of Requested Information in Appendix a of Generic Letter 2016-01, Monitoring of Neutron-Absorbing Materials in Spent Fuel Pools (Non-Proprietary Version) ML16125A5222016-05-0404 May 2016 FOIA/PA-2016-0455 - Resp 1 - Final, Agency Records Subject to the Request Are Enclosed ML15014A1602015-01-14014 January 2015 Attachment 2 - NRC Working Group Recommendations to Revise the Substantive Cross-Cutting Issue Process ML15014A1532015-01-14014 January 2015 Attachment 1- NEI Comments on NRC Working Group Recommendations to Revise the Substantive Cross-Cutting Issue Process ML13143A3312013-06-0606 June 2013 Operating Boiling-Water Reactor Licensees with Mark 1 and Mark 2 Containments Addresses List - Enclosure 2 ML12056A0522012-03-12012 March 2012 Enclosure 6 - List of Power Reactor Licensees and Holders of Construction Permits in Active or Deferred Status ML1003306012010-02-0808 February 2010 Compression Test of Concrete, 4000 Psi ML0933507512010-01-14014 January 2010 Temporary Instruction 2515/180, Managing Fatigue ML1003413132010-01-0808 January 2010 Compression Test of Concrete, 3000 Psi ML0911802472009-03-0909 March 2009 Enclosure 5 - FAQ Log ML0921105892009-03-0606 March 2009 Nebraska Game and Parks Commission Species by County List ML0917606542008-04-0404 April 2008 CNS Lr - Air Pollutants and Control Techniques - Particulate Matter, Control Techniques, EPA ML0917501832008-02-15015 February 2008 Lr - NPPD Statement on Addressing Climate Change ML0732400242007-10-25025 October 2007 Examples of Max Thermal Power License Conditions ML0721104332007-07-25025 July 2007 Questions from 1 Through 8 ML0628602342006-10-11011 October 2006 SERP Worksheet for SDP-Related Finding at Cooper Nuclear Station, Service Water Gland Seal Water Configuration Deficiency ML0628602412006-10-11011 October 2006 Analysis: Brief Description of Issue ML0628602402006-10-11011 October 2006 Analysis: Briefing Description of Issue ML0628602292006-10-11011 October 2006 Analysis: Brief Description of Issue ML0628300792006-10-0606 October 2006 Release Severity and Timing Classification Scheme (Severity, Timing) ML0627101442006-09-25025 September 2006 Violations (Violations Are Severity Level IV Unless Otherwise Stated) ML0623601172006-08-22022 August 2006 Identification and Resolution of Problems - SW System Alignment ML0623601262006-08-22022 August 2006 Loop Category ML0623601232006-08-22022 August 2006 Danger Will Robinson: If You Change Cell Locations You May Break the VB Code! ML0623601192006-08-22022 August 2006 Potential Risk Contribution from Large Early Release Frequency (LERF) ML0622205612006-08-0909 August 2006 SDP Phase 1 Screening Worksheet for IE, Ms, and B Cornerstones ML0622204842006-08-0909 August 2006 Undated Paper, Page 8, Table 2 ML0622204962006-08-0909 August 2006 Preliminary Risk Screening for Cooper Service Water Issues ML0622205002006-08-0909 August 2006 Danger Will Robinson: If You Change Cell Locations You May Break the V ML0622205442006-08-0909 August 2006 State the Performance Deficiency Exactly as Stated ML0618607002006-07-0303 July 2006 Enclosure - Final Significance Determination Cooper Nuclear Station, Service Water Gland Seal Water Configuration Deficiency ML0601805372005-06-27027 June 2005 CNS - 06-2005 - Initial Examination Written Reference Handout ML0628602152004-12-0202 December 2004 SERP Worksheet for DP-Related Finding at Cooper Nuclear Station, Service Water Gland Seal Water Configuration Deficiency ML0628601972004-11-30030 November 2004 E-Mail from Sanborn to Allen Et Al., Agenda for Region IV Serp'S on Thurs., Dec. 2, Outside Scope ML0628601862004-10-20020 October 2004 SERP Worksheet for SDP-Related Finding at Cooper Nuclear Station, Service Water Gland Seal Water Configuration Deficiency ML0619802422004-10-18018 October 2004 NRC Question B and CNS Answer ML0619802352004-10-18018 October 2004 NRC Question a and CNS Answer ML0619802282004-09-22022 September 2004 Condition Report CR-CNS-2004-06422, Alarm Procedure Errors ML0619404202004-09-21021 September 2004 CNS Answers to NRC Questions ML0623602872004-08-25025 August 2004 Memo from R. A. Gramm (NRR) to T. A. Bergman (Oedo), Subj: G20040484, Re-Issued Briefing Package for Drop-In Visit on September 2, 2004 by Nebraska Public Power District (NPPD) Officials... ML0628601042004-07-15015 July 2004 SERP Worksheet for SDP-Related Finding at Cooper Nuclear Station, Service Water Gland Seal Water Configuration Deficiency ML0628601052004-07-15015 July 2004 SERP Worksheet for SDP-Related Finding at Cooper Nuclear Station, Service Water Gland Seal Water Configuration Deficiency ML0628601062004-07-15015 July 2004 SERP Worksheet for SDP-Related Finding at Cooper Nuclear Station, Service Water Gland Seal Water Configuration Deficiency ML0628601092004-07-15015 July 2004 SERP Worksheet for SDP-Related Finding at Cooper Nuclear Station, Service Water Gland Seal Water Configuration Deficiency ML0619404382001-12-26026 December 2001 CNS Notification 10132527 ML0619403082001-06-12012 June 2001 CNS Surveillance Data Sheets - Procedure 7.3.1.11, Revision 3 2022-07-25
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Page 8, Table 2:
- Diesel Mission Time was increased from 2.5 to 14 hours1.62037e-4 days <br />0.00389 hours <br />2.314815e-5 weeks <br />5.327e-6 months <br /> to account for the increased time expected to recuver offsite power derived from data analysis published in NUREG/CR-5496.
Page 9, Table 3.a:
NOTE 1: To simplify the data analysis, the analyst assumed that the ratio of high and low pressure sequences were the same as for internal events baseline. This has been accepted practice for achieving a reasonable approximation for ALERF.
Page 11, First paragraph:
As described in the IPEEE, the licensee determined that there were three different potential fire scenarios in the service water pump room, namely: a fire damaging one pump, caused by a small oil-spill fire limited to a 2-quart spill from the lower bearing reservoir associated with that pump; a fire that results from the spill of all the oil from a single pump (28 quarts),
spreading rapidly, and damaging three pumps; and fires that affect all four pumps. The licensee had determined that fires affecting only two pumps were not likely, because of the nature of oil spills and spreading calculations. The analyst determined that a four-pump fire was part of the baseline risk, therefore, it would not be evaluated. A one-pump fire would not automatically result in a plant transient. However, the analyst assumed that a three-pump fire affecting both of the Division I pumps, would result in a loss of service water system initiating event.
Page 14, Several paragraphs:
In accordance with Manual Chapter 0609, Appendix H, "Containment Integrity SDP," the analyst determined that this was a Type A finding, because the finding affected the plant core damage frequency. The analyst evaluated both the baseline model and the current case model to determine the LERF potential sequences and segregate them into the categories provided in Appendix H, Table 5.2, OPhase 2 Assessment Factors - Type A Findings at Full Power. The primary distinctions in categories are based on the initiator type, the pressure of the reactor coolant system at the time of core damage, and whether the drywell floor has been flooded, either by the event or by operator action. The type of event is indicative of the mode of core damage and the available systems; the coolant system pressure indicates whether the core will melt through or be ejected from the vessel; and in a Mark I containment, the steel line is significantly more susceptible to melt through if there is no water on the drywell floor. The categories, the total core damage frequency related to each of these categorizations, the LERF factors, and an estimation of the change in LERF are documented in Table 5 of this worksheet.
Following each model run, the analyst segregated the core damage sequences as follows:
Loss of coolant accidents were assumed to result in a wet drywell floor. The analyst assumed that during all station blackout initiating events the drywell floor remained dry.
The Cooper Nuclear emergency operating procedures require drywell flooding if reactor vessel level can not be restored. Therefore, the analysts assumed that containment flooding was successful for all high pressure transients and those low pressure transients that had the residual heat removal system available.
All individual intersystem loss of coolant accident initiators designated in the SPAR model were grouped in the ISLOCA category.
Page 16, First Bullet:
As stated in Assumption i in the above analysis, the analyst Uted a value of 0.4 for the probability that operators would fail to realign gland water prior to failure of the Division II pumps. This value was derived using the INEEL's SPAR-H method. The licensee used a Human Error Probability of 9.2 x 10.2 derived from for the probability that operators would fail to realign gland water prior to failure of the Division II pumps. The analyst used a failure probability of 0.4, derived from the INEEL's SPAR-H method.