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| * Entergy Operations, Inc.
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| River Bend Station 5485 U.S. Highway 61N St. Francisville, LA 70775 Tel 225-381-4177 William F. Maguire Site Vice President 10 CFR 50.90 RBG-47799 February 28, 2018 ATTN: Document Control Desk U. S. Nuclear Regulatory Commission
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| * Washington, D. C. 20555
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| ==SUBJECT:==
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| Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (TSTF-425)
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| River Bend Station, Unit 1 Docket No. 50-458 License No. NPF-47
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| ==REFERENCES:==
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| NUREG-1434, "Standard Technical Specifications General Electric BWR/6 Plants," Revision 4, Volume 1, Specifications, April 2012 (NRC Agencywide Documents Access and Management System (ADAMS)
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| Accession No. ML12104A195)
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| ==Dear Sir or Madam:==
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| In accordance with the provisions of Title 1O of the Code of Federal Regulations (10 CFR Part 50.90), "Application for amendment of license, construction permit, or early site permit," Entergy Operations, Inc. (Entergy) is submitting a request for an amendment-to the technical specifications (TS) for River Bend Station, Unit 1 (River Bend).
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| The proposed amendment would modify the River Bend TS by relocating specific surveillance frequencies to a licensee-controlled program with the implementation of Nuclear Energy Institute (NEI) 04-10, "Risk-Informed Technical Specification Initiative 58, Risk-Informed M~thod for Control of Surveillance Frequencies."
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| Attachment 1 provides a description of the proposed change, the requested confirmation of applicability, and plant-specific verifications. Attachment 2 provides documentation of probabilistic risk assessment (PRA) technical adequacy. Attachment 3 provides the existing TS pages marked up to show the proposed change. Attachment 4 provides revised (clean) TS pages. Attachment 5 provides the proposed TS Bases changes for information only. Attachment /
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| 6 provides a Proposed No Significant Hazards Consideration. Attachment 7 provides a jtP /) _
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| ' ,Jf~
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| RBG-47799 Page 2 of 3 cross-reference table that correlates River Bend TS surveillance requirement numbers to the NUREG-1434 (Reference) TS surveillance requirement numbers.
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| Entergy requests approval of the proposed license amendment by February 28, 2019 with the amendment being implemented within 90 days.
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| No new regulatory commitments are made in this submittal.
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| In accordance with 10 CFR 50.91, "Notice for public comment; State consultation," a copy of this application, with attachments, is being provided to designated State of Louisiana and State of Texas Officials.
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| If you should have any questions regarding this submittal, please contact Timothy Schenk, Manager, Regulatory Assurance, at 225.381.4177.
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| I declare under penalty of perjury that the foregoing is true and correct.
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| Executed on February 28, 2018 Sincerely, WFM/alc Attachments: 1. Description and Assessment
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| : 2. Documentation of PRA Technical Adequacy
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| : 3. Proposed Technical Specification Changes (Mark-Up)
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| : 4. Revised Technical Specification Pages
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| : 5. Proposed Technical Specification Bases Changes (Information only)
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| : 6. Proposed No Significant Hazards Consideration
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| : 7. River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference cc: U.S. Nuclear Regulatory Commission Region IV 1600 E. Lamar Blvd.
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| Arlington, TX 76011-4511
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| RBG-47799 Page 3 of 3 Ms. Lisa M. Regner, Project Manager U.S. Nuclear Regulatory Commission MS-8-H4 One White Flint North 11555 Rockville Pike Rockville, MD 20852 NRC Senior Resident Inspector PO Box 1050 St. Francisville, LA 70775 Department of Environmental Quality Office of Environmental Compliance Radiological Emergency Planning and Response Section Ji Young Wiley P.O. Box 4312 Baton Rouge, LA 70821-4312 Public Utility Commission of Texas Attn: PUC Filing Clerk 1701 N. Congress Avenue P. 0. Box 13326 Austin, TX 78711-3326 RBF1-17-0135 LAR-2017-08
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| ATTACHMENT 1 RBG-47799 DESCRIPTION AND ASSESSMENT
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| - Description and Assessment RBG-47799 Page 1 of 7 1.0 Description The proposed amendment would modify Technical Specifications (TS) by relocating specific surveillance frequencies to a licensee-controlled program with the adoption of Technical Specification Task Force (TSTF)-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control-Risk Informed Technical Specification Task Force (RITSTF) Initiative Sb." Additionally, the change would add a new program, the Surveillance Frequency Control Program, to TS Chapter 5.0, Administrative Controls.
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| The changes are consistent with NRC approved lndustry/TSTF Standard Te.chnical Specifications (STS) change TSTF-425, Revision 3, (Rev. 3) (NRC Agencywide Documents Access and Management System (ADAMS) Accession No. ML090850642).
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| The Federal Register notice published on July 6, 2009 (74 FR 31996) announced the availability of this TS improvement.
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| 2.0 Assessment 2.1 Applicability of Published Safety Evaluation Entergy Operations, Inc. (Entergy) has reviewed the safety evaluation provided in Federal Register Notice 74 FR 31996, dated July 6, 2009. This review included the NRC staff's model safety evaluation (SE), TSTF-425, Revision 3, and the requirements specified in NEI 04-10, Revision 1 (NRC ADAMS Accession No. ML071360456).
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| Attachment 2 includes Entergy's documentation with regard to the River Bend Station, Unit 1 (River Bend) probabilistic risk assessment (PAA) technical adequacy consistent with the requirements of Regulatory Guide 1.200, Revision 2 (NRC ADAMS Accession No. ML090410014), Section 4.2, and describes any PAA models without NRG-endorsed standards, including documentation of the quality characteristics of those models in accordance with Regulatory Guide 1.200.
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| Entergy has concluded that the justifications presented in the TSTF proposal and the model SE prepared by the NRC staff are applicable to River Bend and justify this amendment to incorporate the changes to the River Bend TS.
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| 2.2 Optional Changes and Variations The proposed amendment is consistent with the STS changes described in TSTF-425, Revision 3; however, Entergy proposes variations or deviations from TSTF-425, as identified below, and include differing TS Surveillance numbers.
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| : 1. The definition of STAGGERED TEST BASIS is being retained in the River Bend TS Section 1.1, *"Definitions," because this terminology continues to be used in several SR Frequencies which are not the subject of this amendment request and is not proposed to be changed (e.g., SRs 3.4.4.3, 3.5.1.7, and 3.6.1.6.1). This is an administrative deviation from TSTF-425 with no impact on the NRC staff's model safety evaluation dated July 6, 2009 (74 FR 32001).
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| i - Description and Assessment RBG-47799 Page 2 of 7
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| : 2. River Bend SRs with SR numbers that differ from the corresponding TSTF-425 SRs are administrative deviations from TSTF 425 with no impact on the NRC's model SE dated July 6, 2009 (74 FR 32001).
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| : 3. For NUREG-1434 SRs not contained in the River Bend TS, the corresponding mark-ups included in TSTF-425 for these SRs are not applicable to River Bend. This is an administrative deviation from TSTF-425 with no impact on the NRC's model safety evaluation dated July 6, 2009 (74 FR 32001).
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| : 4. Plant-specific SRs 3.4.9.2, 3.4.10.2, 3.6.2.3.2, 3.9.8.2, and 3.9.9.2 are not contained in the mark-ups provided in TSTF-425. These SRs were added to the River Bend TS per License Amendment 188 (N RC ADAMS Accession No. ML15195A061),
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| which implements TSTF-523, Revision 2. TSTF-523 allows the option of relocating the applicable SRs to the Surveillance Frequency Control Program (SFCP). For these and other plant-specific SRs identified in Attachment 7 that are not contained in the NUREG-1434 mark-ups provided in TSTF-425, Entergy has determined that the relocation of the frequencies for these River Bend plant-specific SRs is consistent with the intent of TSTF-425, Revision 3, and with the NRC's model safety evaluation dated July 6, 2009 (74 FR 32001 ). The subject plant-specific SR frequencies are periodic frequencies and do not meet the scope exclusion criteria identified in Section 1.0, "Introduction," of the model SE.
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| In accordance with TSTF-425, changes to the frequencies for these SRs would be controlled under the SFCP. The SFCP provides the necessary administrative controls to require that SRs related to testing, calibration and inspection are conducted at a frequency to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met. Changes to frequencies in the SFCP would be evaluated using the NRC approved methodology and probabilistic risk guidelines contained in NEI 04-1 O, Revision 1. This deviation from TSTF-425 is consistent with other industry applications adopting TSTF-425 (e.g., Waterford Unit 3 License Amendment 249 - NRC ADAMS Accession No. ML16159A419, Perry Unit 1 License Amendment 171 - NRC ADAMS Accession No. ML15307A349, and Brunswick Units 1 and 2 License Amendments 276 and 304, respectively - NRC ADAMS Accession No. ML17096A129).
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| : 5. The SFCP is added to TS 5.5.12 and the word "DELETED" is removed instead of adding the program at the end of TS Section 5.5. This change requires formatting that moves applicable portions of text to the following pages as identified in the markup of the TS pages (Attachment 3). This change is an administrative deviation from TSTF-425 with no impact on the NRC's model SE dated July 6, 2009 (74 FR 32001)
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| : 6. TS 5.5.14.d is revised, in part, as follows (deleted text in strikeout and added text in italics):
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| "Measurement, at designated locations, of the CRE pressure ... by one subsystem of the CRFA System ... at a Frequency of 24 months on a STAGGERED TEST BASIS in accordance with the Surveillance Frequency
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| - Description and Assessment RBG-47799 Page 3 of 7 Control Program. The results shall be trended and used as part of the 24 month assessment of the CRE boundary assessment specified in 5.5.14.c (ii)."
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| TSTF-425 includes the relocation of the frequency for NUREG 1434, SR 3.7.3.4, associated with verifying each Control Room Fresh Air (CRFA) System subsystem can maintain a positive pressure relative to adjacent building(s). This SR was revised under TSTF-448, "Control Room Habitability," to perform control room envelope unfiltered air inleakage testing in accordance with the Control Room Envelope Habitability Program. The requirement to perform the relative pressure suNeillance was included in the new NUREG 1434, TS 5.5.15, "Control Room Envelope Habitability Program," as TS 5.5.15.d. River Bend adopted TSTF-448 in Amendment 154 dated November 2007 (NRC ADAMS Accession No. ML072490080), designating the Control Room Envelope Habitability Program as TS 5.5.14 with the subject suNeillance requirement as TS 5.5.14.d. Therefore, the frequency change identified for NUREG-1434 SR 3.7.3.4 in TSTF-425 is being adopted as the River Bend TS 5.5.14.d frequency. This is an administrative deviation from TSTF-425 with no impact on the NRC staff's model SE dated July 6, 2009 (74 FR 31996). In addition, on July 26, 2016, the NRC approved a similar SR frequency relocation (i.e., TS 6.5.17.d frequency) in the Waterford Unit 3 TSTF-425 License Amendment 249 (NRC ADAMS Accession No. ML16159A419).
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| : 7. Periodic frequencies associated with River Bend TSs 5.5.7, 5.5.9, and 5.5.14 are included in the scope of this amendment that are not identified for relocation in TSTF-425, Revision 3.
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| The first paragraph of TS 5.5.7 is revised, in part, as follows (deleted text in strikeout and added text in italics):
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| " ... required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in Regulatory Guide 1.52, Revision 2, except that testing specified at a frequency of 18 months is required at a frequency of 24 months in accordance with the Surveillance Frequency Control Program."
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| TS 5.5.9.c is revised as follows (deleted text in strikeout and added text in italics):
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| "Total particulate concentration of the fuel oil in the storage tanks is < 10 mg/I when tested every 31 days in accordance with ASTM D-2276, Method A-2 or A-3 at a frequency in accordance with the Surveillance Frequency Control Program."
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| TS 5.5.14.c is revised, in part, as follows (deleted text in strikeout and added text in italics):
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| "Requirements for ... (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0, except that testing specified at a frequency of 18 months is required at a frequency ef.--24 months in accordance with the Surveillance Frequency Control Program."
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| - Description and Assessment RBG-47799 Page 4 of 7 Entergy has determined that the relocation of the periodic frequencies associated with these specifications are consistent with the intent of TSTF-425, Revision 3, and with the NRC's model SE dated July 6, 2009 (74 FR 32001 ). The subject TS Section 5.5 frequencies are periodic frequencies and do not meet the scope exclusion criteria identified in Section 1.0, "Introduction," of the model SE. These changes are similar to the SR frequency relocation (i.e., TS 6.5.17.d frequency) that the NRC approved for Waterford Unit 3 in License Amendment 249 (ML16159A419) as described in Item 6 herein.
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| In accordance with TSTF-425, changes to the frequencies for these surveillances would be controlled under the SFCP. The SFCP provides the necessary administrative controls to require that surveillances related to testing, calibration and inspection are conducted at a frequency to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met. Changes to frequencies in the SFCP would be evaluated using the NRC approved methodology and probabilistic risk guidelines contained in NEI 04-10, Revision 1.
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| : 8. SR 3.8.1.8 text is revised to correct a formatting error. Currently, SR 3.8.1.8.a and SR 3.8.1.8.b are listed within the same SR table row, each with a Frequency specified as 24 months. The proposed amendment would modify SR 3.8.1.8 to add text and combine the two SRs into one'single SR with two sub-activities and one Frequency in accordance with the guidance of Section 2.5.6 of TSTF-GG-05-01, Writer's Guide for Plant-Specific Improved Technical Specifications, June 2009 (ISTS Writer's Guide) restoring consistency with other SRs (e.g., SRs 3.8.1.7, 3.8.1.11, 3.8.1.12, 3.8.1.13, and 3.8.1.14). SR 3.8.1.8 is revised as follows (deleted text in strikeout and added text in italics):
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| "Verify, for required unit power supplies:
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| : a. Verify mManual transfer of unit power supply from the normal offsite circuit to required alternate offsite circuit.-; and
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| : b. Verify aAutomatic transfer of bus E22-S004 through NNS-SWG1A or NNS-SWG1 B from the 22 kV onsite circuit to required offsite circuit."
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| Revising the text of SR 3.8.1.8 to combine SR 3.8.1.8.a and SR 3.8.1.8.b into one single SR does not alter the intent of the current SRs nor does the change have an adverse impact on the proposed amendment. This change is an administrative deviation from TSTF-425 with no impact on the NRC's model SE dated July 6, 2009 (74 FR 32001 ).
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| : 9. NRC letter dated April 14, 2010 (NRC ADAMS Accession No. ML100990099),
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| provides a change to an optional insert (Insert #2) to the existing TS Bases to facilitate adoption of the Traveler ..The TSTF-425 TS Bases insert states the following:
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| "The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program."
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| - Description and Assessment RBG-47799 Page 5 of 7 This statement only applies to frequencies that have been changed in accordance with the SFCP and does not apply to frequencies that are relocated but not changed.
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| Consistent with NUREG-1434, Revision 4 (NRG ADAMS Accession No. ML12104A195), Entergy has replaced the TSTF-425 TS Bases Insert #2 with the following variations based on the context of the specific Bases:
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| Individual SR Bases -
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| "The Surveillance Frequency is controlled under the Surveillance Frequency Control Program."
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| Multiple SR Bases -
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| "The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program."
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| SR Bases containing additional frequencies not controlled in the SFCP -
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| "The time interval based Surveillance Frequency[ies] is[are] controlled under the Surveillance Frequency Control Program."
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| SR Bases based on TSTF-523 -
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| "The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Surveillance Frequency may vary by location susceptible to gas accumulation."
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| This administrative deviation from TSTF-425 does not alter the intent of the proposed amendment and does not impacton the NRC's model SE dated July 6, 2009 (74 FR 32001 ).
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| 1O. Due to the relocation of SR frequencies and replacing them with "In accordance with the Surveillance Frequency Control Program," there are multiple SRs that moved to the next page requiring further formatting as identified in the markup of the TS pages (Attachment 3). The following new pages are added as a result of these formatting revisions: Pages 3.3-6a, 3.3-52a, 3.5-5a, 5.0-16b. Current Page 3.8-16 has been replaced with a new Page 3.8-16 to accommodate moving multiple TS 3.8.1 SRs to the following pages and the text, "Table 3.8.1-1 has been deleted," on current Page 3.8-16 is removed. Additionally, minor formatting errors have also been corrected as identified in the markup of the TS pages. For examples; "NOTE" is change to "NOTES" and a line space added between Notes 1 and 2 in SR 3.5.1.2 and 3.5.2.4; a line space is added after the Frequency in SR 3.2.2.1; the Frequency for SR 3.5.3.2 is revised to align with the SR text consistent with NUREG-1434 SR 3.5.3.3 and in accordance with Section 2.5 of the ISTS Writer's Guide; and a double line is added at the end of the SR table after SR 3.8.4.8 in accordance with Section 2.1.6 of the ISTS Writer's Guide. The formatting changes identified in the markup of the TS pages are administrative deviations from TSTF-425 with no impact on the NRC's model SE dated July 6, 2009 (74 FR 32001).
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| - Description and Assessment RBG-47799 Page 6 of 7
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| : 11. The SR rows associated with SR 3.6.4.1.7 and SR 3.8.3.6 are deleted because the associated SRs have been deleted in previous River Bend license amendments and are no longer needed. Deleting these rows does not have an adverse impact on the proposed amendment. 'These formatting changes are administrative deviations from TSTF-425 with no impact on the NRC's model SE dated July 6, 2009 (74 FR 32001).
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| Entergy proposes to relocate surveillance frequencies except those that reference other approved programs, are purely event-driven, are event-driven but have a time component for performing the surveillance on a one-time basis once the event occurs, or are related to specific conditions. Entergy considers the differences listed herein to be minor variations or deviations of the type permitted by TSTF-425.
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| Attachment 7 provides a cross-reference between the NUREG-1434 SRs included in TSTF-425 versus River Bend TS. This attachment includes a summary description of the referenced TSTF-425/River Bend TS SRs which is being provided for information purposes only and is not intended to be a verbatim description of the TS SRs. This cross-reference highlights the following:
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| * NUREG-1434 SRs included in TSTF-425 and corresponding River Bend TS SRs with plant-specific surveillance numbers;
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| * NUREG-1434 SRs not included in TSTF-425 that meet TSTF criteria for frequency relocation and c9rresponding River Bend TS surveillances with plant-specific surveillance numbers, as applicable;
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| * NUREG-1434 SRs included in TSTF-425 that are not contained in the River Bend TS;and
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| * River Bend plant-specific TS surveillances that meet TSTF criteria for frequency relocation but are not contained in either NUREG-1434 or markups in TSTF-425.
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| Inclusion of Attachment 7 is provided to assist the NRC staff's review of the proposed amendment and has no impact on the NRC staff's model SE dated July 6, 2009 (74 FR 32001 ).
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| 3.0 Regulatory Analysis 3.1 Applicable Regulatory Requirements A description of the proposed changes and their relationship to applicable regulatory requirements is provided in TSTF-425, Revision 3 and the NRC's model SE published in the Notice of Availability dated July 6, 2009 (74 FR 31996). Entergy has concluded that the relationship of the proposed changes to the applicable regulatory requirements presented in the Federal Register riotice is applicable to River Bend.
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| 3.2 No Significant Hazards Consideration Entergy Operations, Inc. (Entergy) has reviewed the proposed no significant hazards consideration (NSHC) determination published in Federal Register 74 FR 32000, dated
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| - Description and Assessment RBG-47799 Page 7 of 7 July 6, 2009. Entergy has concluded that the proposed NSHC presented in the Federal Register notice is applicable to River Bend Station, Unit 1 and is provided as an attachment to this amendment request, which satisfies the requirements of 10 CFR 50.91 (a).
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| 3.3 Precedent Relocation of surveillance frequencies to a licensee controlled program was approved for multiple licensees including; Cooper Nuclear Station per License Amendment No.
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| 258 issued on March 31, 2017 (NRC ADAMS Accession No. ML17061A050), D.C. Cook Units 1 and 2 per License Amendment Nos. 334 and 316, respectively, issued on March 31, 2017 (NRC ADAMS Accession No. ML17045A150), and Brunswick Units 1 and 2 per License Amendment Nos. 276 and 304, respectively, issued on May 24, 2017 (NRC ADAMS Accession No. ML17096A129).
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| 3.4 Conclusion Based on the considerations discussed herein, (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public.
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| 4.0 Environmental Consideration Entergy has reviewed the environmental consideration included in the NRC's model safety evaluation published in the Federal Register on July 6, 2009 (74 FR 32006).
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| Entergy has concluded that the NRC's findings presented therein are applicable to River Bend Station, Unit 1, and the determination is hereby incorporated by reference for this application.
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| Attachment 2 RBG-47799 Documentation of PRA Technical Adequacy
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| lg ENERCON
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| .
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| * PROJECT REPORT COVER SHEET Excel!ence-£very project. Every day.
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| ==Title:==
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| River Bend Station Report No.: ENTCORPSO-RBS-01 PRA Technical Adequacy to Support Revision: 0 Relocation of Technical Specification Surveillance Requirements to an Client: Entergy Owner Controlled Program Project Identifier: ENT#CORP-00050 Item Cover Sheet Items Yes No 1 Does this Project Report contain any open assumptions, including preliminary information, which require confirmation? (If YES, identify the D cg]
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| assumptions.)
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| 2 Does this Project Report supersede an existing Project Report? (If YES, identify the supers~ded Project Report.)
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| I D cg]
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| Superseded Project Report No.
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| Scope of Revision: Initial issue
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| }
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| Revision Impact on Results: Not applicable Safety-Related D Non-Safety-Related cg]
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| (Enter Name and Sign)
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| Originator: lsha Lee kia. e. le,e, /_,,
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| { Digitally signed by lsha lee
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| \DN; cn=lsha lee, o=ENERCON, ou,
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| /..,..em<!ll=ilee@enercon.com, c=US Date:201a.02.01 22:33:35-06'00' Reviewer: Diane Jones ~ 'Jv<:) r* Digitally signed by Diane M Jones DNccn=rnaneMJooes,o,o,,
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| (..Vl.L6:'emajl=djones@enercon.com, c=US
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| ,., Dale: 2018.02.02 08:29:49 -06'00' r Digitally signed by Diane MJones
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| ~~
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| Approver: Diane Jones DN:cn=DlaneMJones,o,ou,
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| (..V'U.6 'e~J!=djones@enercon.com,,c=~S Date: 02/01/18 1 ,, Date: 2018.02.02 08:30:30 ..{16 00
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| 0 ENERCON Excellence-Every proj<,CL Every day, PROJECT REPORT REVISION STATUS SHEET Riyer Bend Station Report No.: ENTCORPSO-RBS-01 PRA Technical Adequacy to Support Revision: 0 Relocation of Technical Specification Surveillance Requirements to an Owner Controlled Program Project Report Revision Status:
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| Revision Description 0 02/01/2018 Initial issue Attachment Revision Status:
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| Attachment Attachment No. of Pages Revision No. of Pages Revision No. No.
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| N/A
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| River Bend Station PRA Technical Adequacy to Support RBS Relocation of Technical Specification Surveillance Requirements to an Owner Controlled Program (TSTF 425)
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| ENTCORPSO-RBS-01, Rev. 0 RBS PRA Technical Adequacy' Page 4 of 29 TABLE OF CONTENTS
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| : 1. *PURPOSE ....... :........................................................................................................ 5
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| : 2. SCOPE .............................................................................................. ,...................... 5 2.1. Surveillance Frequency Change Process ................................................................. 6 2.2. Technical Adequacy of a PR~ .................................................................................. 7
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| : 3. RBS PRA TECHNICAL ADEQUACY ........................................................................ 8 3.1. Discussion .............................. :.................................................................................. 8
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| , 3.2. RBS Internal Events and Internal Flooding PRA Model ............................................ 9 3.2.1. Plant Changes Not Yet Incorporated ...................................................................... 9 3.2.2. Peer Review Facts and Observations (F&Os) ....................................................... 9
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| ;3.2.3. Consistency ,with Applicable PRA Standards ....................................................... 10 3.3. RBS Fire PRA Model ...............................................................................................55 3.3.1. Plant Changes Not Yet lncorporated ........ .'........................................................... 55 3.3.2. Peer Review Facts and Observations (F&Os) ...................................................... 55 3.3.3. Consistency with Applicable PRA-8tandards .......................................................55 3.4. Identification of Key Assumptions ............................................................................55 3.5. External Events Considerations ...............................................................................55
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| : 4. CONCLUSIONS .......................................................................................................56
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| : 5. REFERENCES ........................................................................................................56 LIST OF TABLES I
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| Table 1 List of Finding F&Os against the RBS Internal Events Model (from Revision 5 Full-Scope Peer Review) ................................................................................................ 11 Table 2 List of Finding F&Os against the RBS Internal Flooding and LERF Models (from Revision 6 Focused-Scope Peer Review) ................................................................43
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| /
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| ENTCORP50-R8S-01, Rev. 0 RBS PRA Technical Adequacy Page 5 of 57
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| : 1. PURPOSE The purpose of this report is to* document the technical adequacy of the River Bend Station (RBS) Probabilistic Risk Assessment (PRA) model to support the implementation of the Surveillance Frequency Control Program (SFCP), also referred to as Technical Specifications Initiative Sb (Reference 1). RBS will follow the guidance provided in NEI 04-10, Revision 1 (Reference 2), in evaluating proposed surveillance test interval (STI) changes (also referred as "surveillance frequency" changes).
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| : 2. SCOPE As explained in NEI 04-10, the Technical Specifications Initiative Sb uses a risk-informed, performance based approach for establishment of the surveillance frequencies, where PRA methods are used to determine the risk impact of the revised intervals. The PRA technical adequacy is addressed through NRC Regulatory Guide (RG) 1.200 (Reference 3), which references the ASME/ANS PRA standard, RA-Sa-2009 (Reference 4), for internal events at power. Risk impacts associated with fire, seismic, external events, and shutdown activities may be considered quantitatively or qualitatively.
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| NEI 04-10 guidance includes the five key safety principles described in RG 1.174 (Reference 14), which are followed as part of this risk-informed Technical Specification Interval change program. The five key safety principles are:
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| : 1. Change meets current regulations unless it is explicitly related to a requested exemption or rule change
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| : 2. Change is consistent with defense-in-depth philosophy
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| : 3. Maintain sufficient safety margins
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| : 4. Proposed increases in core damage frequency (CDF) or risk are small and consistent with the Commission's Safety Goal Policy Statement
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| : 5. Use performance-measurement I
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| strategies to monitor the change The RBS PRA model Revision 6 is the current model of record for RBS (Reference 5). This model and its technical content was constructed and documented to meet the ASME/ANS PRA standard (Reference 4). The PRA model quantification methodology used at Entergy Operations, Inc. (Entergy), nuclear sites is common and well-known to the industry.
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| Entergy's approach for maintaining, updating and documenting the PRA models at all Entergy nuclear sites is controlled in the fleet procedures. These procedures are consistent with the guidance of the AS ME/ANS PRA standard (Reference 4). The procedural process is comprehensive and detailed, which in turn provides the basis for establishing and maintaining the technical adequacy of the models, as well as ensuring the models reflect the as-built, as-operated plant configuration of the sites. In addition, self-assessments and independent peer reviews are also utilized by Entergy, which reassures the confidence in the approach and overall adequacy of the models against the recognized industry standards and methodologies.
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| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 6 of 57 Sections 2.1 and 2.2 describe the general change process and PRA adequacy requirements, respectively, required to support the Initiative Sb. Section 3 documents the technical adequacy of the RBS PRA model specifically.
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| 2.1. Surveillance Frequency Change Process NEI 04-10 describes the required steps to be followed to adjust an STI. A summary is presented below.
| |
| * Once the STI requiring adjustment is selected, NRC regulatory commitments are collected and reviewed. If any prohibitive commitments are identified, such are examined to determine if the commitment can be changed. If there are no prohibitive commitments, or the commitments may be changed using a commitment change process based on NRC endorsed guidance, then evaluation of the STI revision proceeds. If a regulatory commitment exists and the commitment change process does not permit the change, then the STI revision is not implemented (NEI 04-10, Steps 0-4 (Reference 2)).
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| * The PRA technical adequacy is evaluated using guidance from RG 1.200 (Reference 3).
| |
| The RG addresses the need to evaluate important assumptions that relate to key modeling uncertainties (such as reactor coolant pump seal models, common cause failure methods, success path determinations, human reliability assumptions, etc.).
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| Further, the RG addresses the need to evaluate parameter uncertainties and demonstrate that calculated risk metrics (i.e., CDF and large early release frequency (LERF)) represent mean values ..The identified "gaps" to Capability Category II requirements from the endorsed PRA standards in the RG and the identified key sources of uncertainty serve as inputs to identifying appropriate sensitivity cases (NEI 04-10, Step 5 (Reference 2)).
| |
| * Select the revised STI value and revise any changes to the test strategy (NEI 04-10, Step 6 (Reference 2))
| |
| * Qualitative considerations or qualitative analyses are developed for the STI revision.
| |
| Qualitative considerations include surveillance test and performance history, past industry and plant-specific experience, impact on defense-in-depth protection, among other considerations (NEI 04-10, Step 7 (Reference 2))
| |
| * Perform quantitative and/or qualitative PRA assessments. Steps 8 through 12 in NEI 04-1O provide details regarding the use of PRA for evaluating the STI. The use of the PRA includes: determining if the structures, systems, and components (SSCs) in question are modeled in the PRA, whether the SSCs or operator actions can be modeled (and make changes to the model if possible) or not, perform qualitative assessments as needed, evaluate total and cumulative effect on CDF and LERF, and perform sensitivity studies as needed.
| |
| * The results and proposed STI changes are documented and summarized for consideration by the Integrated Decision-making Panel (IDP). The IDP is usually comprised of the site Maintenance Rule expert panel, a surveillance test coordinator and a subject matter expert. The IDP approves or rejects the STI changes (with the possibility of adjustments if applicable). If the IDP approves the STI changes, these are documented and implemented. The IDP is also responsible for reviewing the
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| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 7 of 57 performance monitoring results and providing feedback if the STI changes, once implemented, result in unsatisfactory performance (NEI 04-10, Steps 16-20 (Reference 2)).
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| 2.2. Technical Adequacy of a PRA As previously discussed, NEI 04-10 endorses the guidance of the NRC Regulatory Guide 1.200 (Reference 3) for the PRA technical adequacy determination. For the purposes of this report, Section 4.2 of RG 1.200 is used in support of Initiative Sb licensee applications. It is important to note that the scope of Initiative Sb applications is broad, and PRA assessments needed for each application vary from application to application. The following requirements are noted in Section 4.2 as necessary to demonstrate that the technical adequacy of the PRA is of sufficient quality t_o support the application submittal:
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| : 1. To address the need for the PRA model to represent the as-designed or as-built, as-operated plant.
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| : 2. Identification of permanent plant changes (such as design or operational practices) that have an impact on those SSCs modeled in the PRA but have not been incorporated in the baseline PRA model. If a plant change has not been incorporated in the PRA, the licensee provides a justification of why the change does not impact the PRA results used to support the application. This justification should be in the form of a sensitivity study that demonstrates the accident sequences or contributors significant to the application decision were not adversely impacted (remained the same).
| |
| : 3. Documentation that the parts of the PRA required to produce the results used in the decision are performed consistently with the standard as endorsed in the appendices of the RG. If a requirement of the standard (as endorsed in the appendix to the RG) has not been met, the licensee is to provide a justification of why it is acceptable that the requirement has not been met. This justification should be in the form of a sensitivity study that demonstrates the accident sequences or contributors significant to the application were not impacted (remained the same):
| |
| : 4. A summary of the risk assessment methodology used to assess the risk of the application, including how the base PRA model was modified to appropriately model the risk impact of the application and results. (Note that this is the same as that required in the application-specific regulatory guides.)
| |
| I
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| : 5. Identification of the key assumptions and approximations relevant to the results used in the decision-making process. Also, include the peer reviewers' assessment of those assumptions. These assessments provide information to the NRC staff in their determination of whether the use of these assumptions and approximations is appropriate for the application, or whether sensitivity studies performed to support the decision are appropriate.
| |
| : 6. A discussion of the resolution of the peer review (or self-assessment, for peer reviews performed using the criteria in NEI 00-02) facts and observations that are applicable to the parts of the PRA required for the application. This discussion should take the following forms:
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| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 8 of 57
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| * a discussion of how the PRA model has been changed,
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| * a justification in the form of a sensitivity study that demonstrates the accident sequences or contributors significant to the application decision were not adversely impacted (remained the same) by the particular issue.
| |
| : 7. The standards or peer review process documents may recognize different capability categories or grades that are related to level of detail, degree of plant specificity, and degree of realism. The licensee's documentation is to identify the use of the parts of the PRA that conform to capability categories or grades lower than deemed required for the given application (Section 1-3 of ASME/ANS RA-Sa-2009).
| |
| This PRA technical adequacy report addresses the quality of the PRA to support relocation of STI frequencies to a licensee controlled document. There are no STI changes proposed for this Initiative Sb application. Items 3 and 4, above, are addressed when preparing an STI change request and are, therefore, not covered in this report. The remaining items above are discussed in Section 3.
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| : 3. RBS PRA TECHNICAL ADEQUACY 3.1. Discussion The RBS PRA models are controlled in accordance with Entergy procedures consistent with the requirements provided in the ASME/ANS PRA Standard, as previously stated in Section 2.
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| Entergy procedures define the process to be followed to implement scheduled and interim PRA model updates and to control the PRA model files. In addition, the procedure also defines the process for identifying, tracking and implementing model changes, and for identifying and tracking model improvements or potential issues that may affect the model. Model changes that are identified are tracked via model change requests (MCRs), which are entered in the Entergy MCR database.
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| Periodic PRA model updates are typically performed at least once every four years, with the option of extending the frequency for up to two years, such that the total update period does not exceed six years. Extensions are justified showing that the PRA model continues to adequately represent the as-built, as-operated plant and must be approved by management.
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| The RBS PRA model revision 6 was compleJed in October 2017 and included an upgrade of the internal flood and LERF analyses. RBS models follow the guidelines of RG 1.200. Section 3.2
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| * discusses the requirements in RG 1.200 to demonstrate PRA technical adequacy as applicable to the current RBS internal events and internal flooding models.
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| A fire PRA model for RBS is currently being developed in accordance with NUREG/CR-6850 (Reference 11) and is scheduled to be complete in 2019. Section 3.3 discusses the requirements in RG 1.200 to demonstrate PRA technical adequacy, as applicable to RBS fire risk evaluations for STI changes.
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| It is important to note that the technical adequacy of the RBS PRA has been documented in' additional reports to support the following PRA applications:
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| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 9 of 57
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| * Integrated Leak Rate Test- License Application associated with Amendment 191: NRC ADAMS Accession Nos. ML15307A283 (RBG-47620) and ML16287A599
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| * License Renewal Severe Accident Mitigation Alternatives analysis - RBS License Renewal Application, Appendix E: NRC ADAMS Accession Nos. ML17153A285 (RBG-47735) and ML17174A531 3.2. RBS Internal Events and Internal Flooding PRA Model 3.2.1. Plant Changes Not Yet Incorporated As discussed in in Section 3.1, an MCR database tracks PRA issues or improvements identified by PRA personnel. The MCR database includes the identification of plant changes that could impact the PRA model.
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| As part of the PRA evaluation for each STI change request, as sensitivity cases are expected to be explored for areas of uncertainty associated with unresolved items (peer review Findings for ASME/ANS PRA Standard Capability II or plant changes) that would impact the results of the STI change evaluation, prior to presenting the results of the risk analysis to the IDP.
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| A review of open MCRs against the RBS PRA model showed that there are 20 MCRs related to Engineering Changes (ECs) either not yet incorporated in the model (a total of 5), or recently incorporated or addressed in the Revision 6 model update and not yet closed (a total of 15). The 5 MCRs not yet incorporated include documentation improvements, EOOS mapping or shutdown EOOS logic changes, all of which have minimal or no impact on the overall PRA results.
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| 3.2.2. Peer Review Facts and Observations (F&Os)
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| The RBS PRA model has undergone several peer reviews which document the model quality and identify any areas with potential for improvement. The following assessments have been performed and documented for the RBS model:
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| * An industry peer review of the RBS PRA model Revision 5 (completed in March 2011) was conducted by the Boiling Water Reactor Owners Group (BWROG) in April 2011 (Reference 6). This peer review documented ninety-eight (98) new F&Os including fifty-nine (59) Findings, thirty-eight (38) Suggestions and one (1) Best Practice. The peer review concluded that the RBS PRA substantially met the ASME/ANS PRA standard at Capability Category II or better.
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| * In September 2017, a focused-scope peer review was conducted for the RBS internal event model Revision 6 upgrade of the internal flooding and LERF analyses. The focused scope peer review was performed against the AS ME/ANS PRA standard RA-Sa-2009 and RG 1.200 requirements for internal flooding and LERF. This focused scope peer review documented thirty (30) new F&Os; eleven (11) Findings and nineteen (19) Suggestions.
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| The RBS PRA internal events model Revision 6 was completed and approved in October 2017.
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| The peer review findings from 2011 and the associated resolutions, as well as the remaining
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| | |
| ENTCORPSO-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 10 of 57 unresolved findings related to the internal events PRA model, are documented in the MCR database and are presented in Table 1. Note that the 18 findings associated with internal flooding and 9 findings associated with LERF are not included in Table 1, as these findings are superseded by those from the 2017 focused J scope peer review.
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| The 11 findings related to the 2017 internal flooding and LERF PRA focused scope peer review are reported in Table 2. An update to the current model is in progress to address the unresolved internal flooding and LERF findings and to incorporate model refinements.
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| 3.2.3. Consistency with Applicable PRA Standards The RBS PRA model Revision 6 largely meets the ASME/ANS PRA standard (Reference 4)
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| Capability Category II of the Supporting Requirements (SRs). Current Entergy PRA documentation includes a self-assessment that documents how each high-level requirement (HLR) and SR are met.
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| The latest full-scope peer review for RBS was conducted in April 2011 using RG 1.200, Revision 2. Since then, model Revision SA (to support license renewal SAMA analysis, but not otherwise used or implemented), and Revision 6 were completed which ensured all the significant F&Os from the peer review were addressed. All the F&Os are captured and documented in the MCR database. A search of RBS MCRs related to the peer review F&Os was performed. Finding-level F&O MCRs 'related to the internal event and internal flooding model are listed in Tables 1 and 2, along with the respective disposition/resolution, if resolved, and the impact on the applications.
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| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 11 of 57 Table 1 List of Finding F&Os against the RBS Internal Events Model (from Revision 5 Full-Scope Peer Review)
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| .. MCR .. .. ** *.
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| Applicable Importance to
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| *Status Finding* Disposition .
| |
| *.Number.* :SR(sl .,Aoolicati6n PRA Peer Review F&O 1-1: (DA-CB)
| |
| Actual run times from the MRULE Table C-2A of PRA-RB-01-002S05 logs were used whenever discusses the rationale used to determine possible. These-logs are typically run times. While a few components (e.g., kept for risk significant This issue was SW pumps) appear to be collect actual components as identified by the resolved and run vs. standby time in the supporting MRULE expert panel. Used therefore has no spreadsheets, the standby time for most EOOS logs for other plant- impact in STI change RB-4291 Resolved DA-CB components in running systems was specific data with a small number evaluations estimated (e.g., 1/2, 1/3, etc.). Therefore, of exceptions. It was necessary performed in Category I is met. to resort to critical hours with the accordance with the EOOS data. Identified for the SFCP.
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| Possible Resolution: To meet Category II, RBS staff for recommendations to actual plant experience concerning the MRULE expert panel.
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| standby/run fractions needs to be collected and used in the PRA.
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| RBS Peer Review F&O 1-5: (AS-B3)
| |
| There is not a specific discussion of the phenomenological impacts of each initiator upon the mitigating systems in the Rev. 6 Change AS notebook (PRA-RB-01-002S01). One This issue was specific exception to this is the impacts of resolved and Added Section 4.1 to PSA-RBS-debris entrainment for ECCS following therefore has no 01-AS, to discuss LOCA, which is discussed for the Large impact in STI change RB-4292 Resolved AS-B3 phenomenological events in the and Intermediate LOCA event trees. It evaluations Accident Sequence notebook.
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| appears that phenomenological impacts performed in This section refers the user to the are addressed in the AS logic for all accordance with the system notebook success criteria initiators. However, documentation of SFCP.
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| for the impact of support systems.
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| other impacts (or noting the absence of any impacts) should be provided.
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| Possible Resolution: Include an explicit discussion of phenomenological impacts
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| | |
| ENTCORP50-RBS-01, Rev. O RBS PRA Technical Adequacy Page 12 of 57 MCR Applicable Importance to
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| *Status Finding Disposition
| |
| *Number SR(s) Application (or lack thereof) for each event tree.
| |
| The RBS model does include Common Cause Failure of the control rods to insert, with a prob~~ility of 2.5E-07. This plant spec1f1c CCF calculation is considered more applicable to RBS than the generic NUREG/CR-5500 value.
| |
| Accounting for the 2.1 E-06 RBS PRA R5 Peer Review F&O 1-7: (SY probability of mechanical A-11 ))
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| common cause failure of the Reactor Protection System from In the RPS model for mechanical failure to NUREG/CR 5500 has only a scram, the only failures that are miniscule impact on calculated considered are those that affect the SDV core damage frequency. Using valves. In reality, other failure modes This issue was the cutsets pre-generated for (including mechanical binding of the resolved and MSPI purposes with a E 13 control rods themselves) may be more therefore has no truncation limit, the probability of likely. NUREG/CR-5500 Volume 111 for impact in STI change RB-4293 Resolved SY-A11 corresponding basic event C71-example, estimates control rod binding for evaluations CRD-CF-CTROD was adjusted a BWR at 2.1 E-6. Inclusion of this performed in from 2.5E-07 to 2.1 E 06. The additional failure mode would increase the accordance with the resulting CDF increased from co~p~ted failure probability of the RPS by SFCP.
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| 2.642E-06 to 2.688E-06, a 0.17%
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| a significant amount.
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| mcre~se: Thus, this finding questioning the modeling of Possible Resolution: Revise the RPS fault common cause mechanical tree model to consider the complete failure probability in the RBS PRA spectrum of possible failure mechanisms does not impact the technical for the RPS and the control rods.
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| quality of the RBS Rev.5 PRA model.
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| Note the applicable Supporting Requirement from the Standard was judged to be Met.
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| No changes to PRA model reauired.
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| ENTCORP50-RBS-01, Rev. O RBS PRA Technical Adequacy Page 13 of 57 MCR ~pplicable Importance to Status Finding "Disposition Number SR(s) Aoolication RBS PRA R5 Peer Review F&O 1-9 (SY-As documented in HRA A24) calculation PRA-RB-01-002S03 the diesel recovery (ZHE-FO- '
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| Several equipment recovery events are OGN1 HRS) and the decay heat included in the models. These are a removal recovery (ZRC-XHE-FO-diesel recovery (ZHE-FO-OGN1 HRS) and OHRL T) are the only equipment a decay heat removal recovery (ZRCXHE-recovery actions other than Loss FO-OHRLT). While a basis for these of Offsite Power modelled in the events is provided in the HRA notebook at-power PRA. MCR RB-4742
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| ~PR_A-RB-01-002S03), the bases may not and work tracking item WT-Justify the use of the specific data values WTHQN-2012-0250-used, as required by this SR.
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| 004.documented the applicability of the NU REG diesel recovery to For the diesel repair, the value for the River Bend. MCR RB-4294 (and non-repair probability is based on a MCR RB-4735) addresses the ge~eric analysis using industry data and This issue was decay heat removal recovery.
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| various assumptions. No documentation resolved and was provided to demonstrate that the data therefore has no RB- Review of this issue results in OA-C15, would be applicable to River Bend as impact in STI change 4294, Resolved engineering judgement that an SY-A24 required by this SR. evaluations RB-4742 appropriate value is applied for performed in this repair/recovery term although For the OHR repair, the data used to accordance with the the basis (EPRI TR-1003113) develop this non-recovery probability is SFCP.
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| ~as not applicable. Therefore, a based on an EPRI report concerning rigorous and appropriate basis, recovery of loss of OHR cooling during based on actuarial data, was shutdown conditions. As shutdown used to develop a nonrecovery conditions can vary significantly from at-probability for the ZRC-SHE-FO-power systems (in terms of factors such OHRL T function of containment as number of cooling water trains decay heat removal prior to avail_able, etc.), the data may not be containment overpressurization at applicable to the situation being evaluated 16+ hours that could in the River Bend PRA.
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| subsequently result in core damage. This was done for Possible Resolution: As required by this Rev.5A and is retained /
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| SR, evaluate the repair data used for the incorporated into Rev.6.
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| diesel and OHR repair terms for applicability to River Bend and document this evaluation. If necessarv,
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| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 14 of 57 MCR Applicable Importance to Status Finding Disposition Number. SR(s) Aoolication select more representative data sources for these repair events.
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| ENTCORPSO-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 15 of 57 MCR Applicable Importance to Status Finding Disposition Number SR(s) Aoolication .
| |
| PRA Peer Review F&O 1-10 (AS-A11)
| |
| Transfers between event trees is accomplished through a direct transfer of the sequence logic through the top logic model. This approach generally retains the dependencies through the This issue was quantification process. However, in the resolved and case of transfers between the LOSP and therefore has no Changes to include LOOP ATWS event trees, it does not appear that impact in STI change RB-4295 Resolved AS-A11 sequences under A TWS logic sequence information is properly evaluations incorporated into fault tree.
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| transferred, as no LOSP/ATWS cutsets performed in appear in the results. accordance with the SFCP.
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| Possible Resolution: Review the fault tree and event tree logic associated with the LOSP to A TWS sequence transfer and modify as necessary to obtain proper results.
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| PRA RS Peer Review F&O 1-11 (HR-03): Updated PSA-RBS-01-HR report, Section 1.4.1 to include OSP and Since HLR-HR-D concerns pre-initiating STP procedures that are used for events, no evidence of an evaluation pre-initiator HRA development.
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| process for the quality of pre-initiator Also clarified that the SOPs written procedures and the quality of the include sign-off verifications for This issue was pre-initiator human-machine interface system lineups. resolved and could be found anywhere in the River therefore has no Bend PRA documentation. Additional discussion from ILRT impact in STI change RB-4296 R13solved HR-03 extension request: evaluations Note that Post Initiator procedures have performed in been evaluated for quality (Section 1.4.1) "This is considered to be primarily accordance with the as well as the quality of the man machine an issue of increasing the SFCP.
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| interface (Section 1.4.3.) in the RBS robustness of PRA model HRA/Rule Recovery Work Package, documentation. Only negligible Calculation PRA-RB-01-002S03. or very slight changes in PRA would be expected as a result of Possible Resolution: Perform an the review of pre-initiator
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| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 16 of 57 MCR *--
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| * Applicable Importance to Status Finding Disposition Number --SR(s)
| |
| * Aoolication assessm_ent of the quality of pre-initiator procedures. Any inadequacy in procedures and man-machine interface. the procedures associated with pre-initiator human failure events would be evidenced during the construction of the detailed spreadsheet calculations for these probabilities. These spreadsheets include documentation and review of the procedure references for each individual pre-initiator event, as well as review of the procedures and nature of indications for the calculation of the basic human
| |
| - error probability. The Man-machine interface quality discussion of section 1.4.3 is also generally applicable to pre-accident initiator actions as well as post-accident actions. No
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| - procedural inadequacies were
| |
| -- noted during the development of these HRA calculations.
| |
| Procedure RBNP 001, "Development and Control of - .
| |
| RBS Procedures," governs plant operations procedures. RBNP-001 includes requirements for Technical Verification and Validation of procedures to ensure procedure quality. Thus, the intent of the SR is fulfilled through the HRA calculation process."
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| (_
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| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 17 of 57" MCR Applicable Importance to Status F_inding Disposition Number SR(s)' Application This item requires the decomposition of surveillance tests, when applicable, to ensure that the number of demands is correctly counted for Bayesian updates of demand failure rates.
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| In this revision of this notebook, the only updated demand rates This issue was PRA R5 Peer Review F&O 2-3 (DA-C10): were those for the chillers (CHR resolved and FS), air handlers (CLU FS) and therefore has no Surveillance tests are not decomposed diesel generators (DG FS). All impact in STI change RB-4301 Resolved DA-C10 into sub-elements. other updated type codes were evaluations hourly rate events. These performed in Possible Resolution: Decompose components are high-level (i.e.,
| |
| accordance with the surveillance tests into sub-elements. they are not subcomponents like SFCP.
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| diesel sequencers, that may not be tested every time with other associated equipment). Thus, no surveillance test decomposition is required. In addition, the demand data were obtained from the system engineer for CHR/CLU and MSPI for DG.
| |
| PRA R5 Peer Review F&O 2-7 (HR-D5):
| |
| It was determined that the Dependent pre-initiator dependencies Finding mischaracterized the have been assessed. However, several HRA methodology as double-This issue was independent pre-initiator human error counting the shift status check, as resolved and event assessments are non-conservative the BHEP calculation of therefore has no and judged to be evaluated too low by NUREG/CR-4772 inherently impact in STI change RB-4302 Resolved HR-D5 RBS analysts. includes a check for if there is a evaluations status check as part of its performed in For example, in worksheet hfe_a.xls, the approved methodology.
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| accordance with the independent event B21-XHE-MC-V658A One event value was found to be SFCP.
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| twice credits the 'Status Check Each Shift inappropriate per guidance and or Day'. Once in the ASEP screening was corrected in revision 5A.
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| questions leading to ASEP case VII and a In addition, it was concluded that second time in the 'Adjustment for the RBS PRA is already
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| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 18 of 57 MCR-- Applicable Importance to
| |
| _ .Status-* Finding Di_sposition, Number SR(s) - Aoolication Average Unavailability'. This double consistent with the counts potential recovery actions leading recommendations of Finding 2 7 to a very low estimate of the independent against SR HR D5, and that the event at -1.3 E-07. Finding mischaracterized the methodology used and use of EN-NE-G-013 (HRA) specifies a minimum specific values. Thus, no further individual HEP of 1E-5 and a combined action was required.
| |
| Uoint) HEP of 1E-6. Therefore, an independent value assessed at 1.3 E-07 deviates from the Entergy Guidance Document.
| |
| Also, the NUREG on good HRA practices is NUREG-1792. This NUREG states the following:
| |
| The total combined probability of all the
| |
| .HFEs in the same accident sequence/cut set should not be less than a justified value. It is suggested that the value not be below -0.00001 since it is typically hard to defend that other dependent failure modes that are not usually treated (e.g.,
| |
| random events such as even a heart attack) cannot occur. Depending on the independent HFE values, the combined probability may need to be higher.
| |
| Possible Resolution: Reevaluate the HEP
| |
| ~
| |
| estimation methodology such that stated quidelines are being followed.
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 19 of 57 MCR'
| |
| * Applicable :Importance to Status . SR(s). .. Finding* Dis.position *.
| |
| .Number * *Aoolicatiori PRA R5 Peer Review F&O 2-10 (MU-C1): This issue is mainly associated with ensuring the cumulative In Engineering Guide EN-NE-G-026, impact of pending PRA changes Revision 0, 'Probabilistic Safety is known. Since the biggest, and Assessment Applications', all Unresolved most direct impact for cumulative F&Os, MCRs, and gaps impacting an effects is on MSPI, evaluating the application are reviewed against a specific cumulative impact of Unresolved application. Justification is provided as to MCRs on MSPI is the most direct why Unresolved items in the model are method of ensuring that acceptable for the application or why they significant cumulative impacts are do not impact the results. However, it is identified. To ensure this is not mandatory to follow this guideline; this performed, and that the needs to be made mandatory. cumulative impacts of Unresolved MCRs are known, Section 5.3.4 In accordance with EN-DC-151 Revision of EN-DC-151 adds the following 2, the cumulative impact of pending model text to address this MCR: This issue was changes is not tracked. Per the guidance, resolved and only when a model change request for an "Evaluate pending changes to therefore has no implemented change is graded A, or there the model for their cumulative impact in STI change RB-4303 Resolved MU-C1 are over 25 Unresolved model change impact on MSPI and provide evaluations requests that are graded B for a particular revised PSA input to the performed in model will an interim PRA update be MSPI basis document as accordance with the implemented. required by References 4 and SFCP.
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| 5 after incorporation."
| |
| However, a method to measure the cumulative impact of pending changes To ensure the impact of individual particularly on the particular applications MCRs is classified correctly, l of concern should be implemented to fully Section 5.3.5 of EN-DC-151 was meet the intent of this SR. revised to add the following text to address this MCR:
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| Possible Resolution: Make the evaluation
| |
| - process used to assess impacts on risk "The PSA engineer shall be applications a formal procedure. cognizant of impact of this issue on other site Also, implement *a method that considers applications (e.g., for NFPA the cumulative impact of pending changes 805 plants, consider the with respect to the specific applications impact of plant changes on that are in effect for the plant. fire risk and total plant risk as
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| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 20 of 57 MCR Applicable Importance to Status Finding Disposition Number SR(s)
| |
| * Aaalication per EN-DC-128)."
| |
| Also, section 5.6.8 of EN-DC-151 now requires that:
| |
| "Applications being initiated or revised during the PRA update cycle shall consider the cumulative impact of impending PSA changes (which are documented via the MCR database)"
| |
| Section 5.0 of Data calculation PRA-RB-01-002S06 includes PRA R5 Peer Review F&O 3-5 (IE-C2): justification for use of data from January 2004 for initiating events PRA-RB-01-002S06, Section 5 Generic with a relatively high (>0.5/year) data was updated with plant trip data from frequency. This applies only to January 1, 1987 to May 31, 2009 for all the IE-T3A reactor scram/
| |
| transient events except for T3A (which turbine trip initiator. A review of used January 1, 2004 to May 31, 2009). data showed only negligible However, justification for excluding data is impact of neglecting the older This issue was not provided as required by the SR. data; the IE-T3A frequency resolved and changed only from 1.39 per therefore has no In addition, the description in Section 5.1 calendar year to 1.32 per impact in STI change RB-4304 Resolved IE-C2 allures to assumption #3 as the basis for calendar year when considering evaluations this exclusion. This assumption instead all data since 1987 or the smaller performed in defines the T3A plant initiator. The 2004-2009 interval; this would accordance with the appropriate assumption is #1 of Section have a miniscule impact upon the SFCP.
| |
| 2.0. final value of 0.846 per reactor critical year calculated using the Possible Resolution: Document the Bayesian update process. Note process used and the justification for this only impacts IE-T3A, which is screening /grouping actual plant trip data. by its nature the initiating event Also, correct the assumption number from with the lowest CCDP.
| |
| #3 to #1.
| |
| Consideration of more recent data would show an even lower
| |
| | |
| ENTCORPSO-RBS-01, Rev. 0 RBS PRA Technical Adeguacy Page 21 of 57 MCR Applicable . Importance to Status Finding Disposition Number SR(s)
| |
| * Aoolication plant specific IE-T3A frequency, as 2004-2009 was a period of higher IE-T3A incidence; only one such event occurred subsequently through the end of 2013.
| |
| This is a documentation issue.
| |
| Added discussion and detail to Sections 4.3.5 (ISLOCA) and 4.3.6 (BOC) and included reference to BOC report in Section 4.3.6.
| |
| Section 5.0 was revised to include following at end of first PRA RS Peer Review F&O 3-10 (SC-A3):
| |
| paragraph:
| |
| Based on information in PRA-RBS Development of support system 002S14, Although Section 4.0 provide initiating events is documented in This issue was success criteria relevant to the equipment the system's system notebook. resolved and needed for all key safety functions that Success criteria for support therefore has no involve LOCAs and general transients, system initiating events can be impact in STI change RB-4305 Resolved SC-A3 success criteria for support system different from the system models evaluations initiators, LOCAs outside containment based on the system performed in and ISLOCAs are missing. '
| |
| requirements to maintain power accordance with the operation compared to the SFCP.
| |
| Possible Resolution: Include appropriate requirements after a scram success criteria for support systems occurs. Support systems which initiators, LOCAs outside containment and are also initiating events included ISLOCAs.
| |
| Service Water, Turbine Plant Cooling Water, Instrument Air and DC power.
| |
| Appendix D of PSA-RBS-01-SC Success Criteria, includes a tabi'e that provides the system functional top logic required for success of initiators. This table
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 22 of 57 MCR Applicable Importance to Status Finding Disposition Number *SR(s) Application has been enhanced to incorporate the success criteria for the various transient initiators, including support system initiators.
| |
| This Finding is documentation in nature and resolution did not impact PRA results. System engineers were consulted during development of System Notebooks. Inputs from System Engineering have been PRA R5 Peer Review F&O 3-16 (SY-A4): documented in PRA-RB 002S11 Attachment B. System PRA-RB-01-002S11, based on engineers participated in the information provided by the PSA group, Expert Panel review documented plant walkdowns have been condqcted to in PRA-RB-01-002S02, ensure the system model correctly reflects Integration & Quantification This issue was the as-built, as-operated plant. -However, package, for Rev.5, and PSA-resolved and limited evidence exists that interviews RBS-01-QU for Rev.6. The PRA therefore has no have been conducted to ensure the model is subject to discussion impact in STI change RB-4306 Resolved SY-A4 system model correctly reflects the as- with system engineers as part of evaluations built, as-operated plant. the Maintenance Rule Expert performed in Panel and as periodic plant accordance with the Possible Resolution: Provide solid issues arise. System SFCP.
| |
| evidence and documentation that Engineering also reviews risk interviews/reviews with knowledgeable information related to PRA model plant personnel (i.e., system engineers) revisions. Thus, numerous occurred to document that the system opportunities exist and have been model correctly reflects the as-built, as- utilized for review of the RBS operated plant. PRA by knowledgeable plant personnel, including system engineers.
| |
| Note the applicable Supporting Requirement from the Standard was judged to be Met.
| |
| Documentation in Attachment B of the main Svstem Notebook of
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 23 of 57 MCR * -Applicable Importance to Status Finding Disposition
| |
| * Number SR(s) Application RBS PRA revision 6 contains the
| |
| - results of the operator interviews and additional information was provided on the email discussions provided with System Engineers PRA Peer Review F&O 3-17 (SY-BB and SY-A4):
| |
| PRA-RB-01-002S1 rR 1 states that plant walkdowns were used to identify spatial A discussion of harsh and environmental hazards. Attachment environments is added to all A of that document contains a set of System Notebooks as part of completed walkdown forms. A sample of Section 1.5.
| |
| those forms were reviewed; many of the This issue was forms indicated the existence of some This Finding is documentation in resolved and kind of spatial or environmental hazard for nature and resolution will not therefore has no the walkdown area. Review of several SY-A4, impact PRA results. Spatial and impact in STI change RB-4307 Resolved ~ys_te~ notebooks did not reveal any SY-BB environmental hazards have evaluations 1nd1cat1on that the identified spatial and been considered in the performed in environmental hazards identified in the development of system models accordance with the walkdowns were reviewed for inclusion in and Event Trees (e.g., SFCP.
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| or exclusion from the system models. No conservatisms in Accident evidence was found that identified Sequence modeling for hazards were accounted for in the system ISLOCA/BOC) or integrated fault tree model.
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| Possible Resolution: Incorporate
| |
| ' information to the walkdowns in the system notebooks documentation and reflect in models, as appropriate.
| |
| | |
| ENTCORPSO-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 24 of 57
| |
| ""MCR *
| |
| *,Nunibi3f .
| |
| This Finding is essentially the same as Finding 3-5 against IE-The IE notebook provides a list of plant C2, which is addressed via MCR-trips identified by LERs between 1987 and RB-4304. The specific 1987 trip This issue was 2009. Each event is either screened, with discussed related to Finding 4-1 resolved and justification, or categorized into the is one of the older IE-T3A events, therefore has no appropriate IE. However, many events for which justification for use of IE-A3, impact in STI change RB-4310 Resolved that would have been categorized as only more recent events was IE-C2 evaluations reactor trip / turbine trip were screened justified in the IE calculation PRA-performed in based solely on age. RB-01-002S06 and, as accordance with the documented under MCR-RB-SFCP.
| |
| Possible Resolution: Re-screen plant- 4304 (above), there is negligible
| |
| . specific events and provide a technical impact upon the model.
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| basis (e.g., implementation of a scram reduction program), rather than an age basis, for exclusion of events.
| |
| PRA Peer Review F&O 4-2 (IE AS and IE- This Finding is related to A2) documentation; in addition, the applicable Supporting Calculation PRA-RB-01-002S06, Requirements from the Standard Appendix I provides a system-by-system were judged by the peer review evaluation to determine possible support- team to be Met.
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| system IE's.
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| This issue was Appendix C of the Initiating Event resolved and However, details of the screening process Report (PSA-RBS-01-IE) therefore has no are not provided. In addition, some specifies that the system-by-IE-A2, impact in STI change RB-4311 Resolved systems wer.e screened for one failure system screening is based on IE-AS evaluations mode (for example, LPCS inadvertent whether loss of the system will performed in start) but not other failure modes (for result in a plant trip or disable a accordance with the example, LPCS pipe break inside system needed to mitigate a plant SFCP.
| |
| containment). trip. Table 4 (and Appendix E for HVAC) provides a more detailed Possible Resolution: Document the discussion of the reasons for systematic approach used. That screening specific systems. The systematic approach should consider all following documentation is added credible system failure modes. Rescreen to Section 4.3 to clarify screening s stems in accordance with the criteria:
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 25 of 57 MCR Applicable ., Importance to.
| |
| Status Finding Disposition Number : . SR(s)
| |
| * Application t systematic approach. "Appendix C does not include plant shutdowns due to exceeding the Technical Specification Allow Outage Time. Tech. Spec. required plant shutdowns are considered manual shutdowns and are counted in IE category IE-T3A. Pipe breaks that result in a reactor trip are evaluated as part of the internal flooding analysis
| |
| [23] and are not considered in Appendix C."
| |
| The specific example cited of a LPCS pipe break inside containment is a scenario that has a negligible risk impact.
| |
| LPCS piping subject to vessel pressure is considered in determination of LOCA initiating event frequencies, and is also considered in the ISLOCA analysis. This line is above the level of the suppression pool and would result in a maximum sustained leak rate of 50 gpm, the capacity of the LPCS keep-fill pump, prior to operator action to terminate the event. This would not be expected to be a challenge to olant operation.
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 26 of 57 MCR
| |
| * Applicable Importance to Status Finding Disposition
| |
| *Number SR(s) Application PRA R5 Peer Review F&O 4-3 (IE-A6):
| |
| Calculation PRA-RB-01-002S06, Section 4.9, Table 5, examines common cause failure of multiple AC or DC buses and eliminates them from consideration. Revised the screening of multiple This issue was System-by-system screening in Appendix AC or DC Buses in Table 5 of the resolved and I, considers system level multiple failures. Initiating Events Report (PSA-therefore has no Initiating event fault trees considered RBS-01-IE) to provide additional impact in STI change RB-4312 Resolved IE-A6 multiple failures by design. details on the screening of evaluations multiple AC or DC buses.
| |
| performed in There is no evidence presented in the IE Common cause failures are accordance with the notebook that multiple failures (for CCF) included in the fault tree modeling SFCP.
| |
| were considered in the development of of initiating events.
| |
| the IE list.
| |
| Possible Resolution: Evaluate the potential for CCF failures causing an initiating event.
| |
| This concerns identification of 3 shutdowns as Manual Shutdowns PRA R5 Peer Review F&O 4-4 (IE-A7): vice Scrams.
| |
| The IE notebook provides a list of plant 9/1/08 was the shutdown for trips identified by LERs between 1987 and hurricane Gustav. This was a This issue was 2009. Each event is either screened, with controlled plant shutdown. The resolved and justification, or categorized into the plant was not in danger of therefore has no appropriate IE. Several of the events that automatic scram at the time but impact in STI change RB-4313 Resolved IE-A7 screen in were at low power operations. was doing a manual shutdown evaluations At least 3 events (dated 5/23/07 3/21/08, due to grid stability issues. The performed in and 9/1/08) were identified as scrams but plant was shut down prior to what accordance with the were screened out as 'manual would have been a partial loss of SFCP.
| |
| shutdowns.' offsite power event a couple of hours after the plant scram from Possible Resolution: Re-screen events to low power.
| |
| which section b applies.
| |
| . 5/23/07 was a shutdown for Recirc Flow Control Valve
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 27 of 57 MCR Applicable . .Importance to, Status . "SR(sl . Finding Disposition Number . *" "" Application
| |
| * repairs. This was a controlled plant shutdown and the order was given to scram from low power
| |
| (-30%) instead of continuing to drive rods in.
| |
| 3/21/08: repairs for a stem-disk separation on a feedwater heater valve. Inserted manual scram
| |
| - once downpowered to 15%.
| |
| Thus, these were all controlled evolutions and no scram was required as part of the plant shutdown process.
| |
| Note the applicable Supporting Requirement from the Standard was judged to be Met.
| |
| Further note these events would be considered IE-T3A events, which are low CCDP events with corresponding low contribution to plant risk (only 3.7% of plant risk per the Rev.5 Summary calculation despite having the highest initiating event frequency of 0.846/year of all initiating events.
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 28 of 57
| |
| , /";; ;,,
| |
| -'MCR
| |
| ;Nurntsfir{ . *.* oi~p<>si~ioJ1(
| |
| . "~.,<' .~,*,
| |
| Since the lognormal distribution based on plant specific data and that for generic data overlap, it is consistent wi1h Entergy and industry practice to use Bayesian
| |
| ,r- updating for deriving the IE-T3A frequency for use in the RBS PRA. Specifically, the 5% value for the plant specific distribution of 0.637/rx-year for Revision 5 is less than that for the generic (0.725) even though the plant specific mean of 1.46 is greater RBS PRA Peer Review F&O 4-5 (IE-C1). than that of the generic. Entergy practice would be to use only the The plant-specific reactor/ turbine trip rate plant specific data if the 5%-ile of This issue was
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| \
| |
| (T3A) is significantly higher than the the higher probability event is
| |
| * resolved and generic, with the plant-specific mean well higher than the 95%-ile of the therefore has no above the generic and updated 95th. lower event, a criterion which this impact in STI change RB-4314 Resolved IE-C1 data did not meet, thus Bayesian evaluations Possible Resolution: This indicates that updating is considered valid. The performed in the PRA should use the plant-specific primary reason why Bayesian accordance with the values without Bayesian updating updating is done in the first place SFCP.
| |
| (reference IE notebook, Appendix B, page is because it is difficult to obtain a 53). . high degree of statistical confidence with plant-specific data only. Again, the underlying assumption in Bayesian analysis is that the generic data is representative of the plant-
| |
| . specific data. Thus, Bayesian updating of data where there is an overlap of the distributions should be used in order to obtain a more accurate estimate of actual future performance.
| |
| Note that NUREG/CR-6823 and a
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 29 of 57
| |
| ~' ,~ t
| |
| <~pplicablei*
| |
| <7,5R*s-*/ .1bispo~itionL: *
| |
| ",.' . :':.\-' *''";;\':...,,*.,t.
| |
| _standard textbook on the subject (Martz, Harry F and Waller, Ray I A, "Bayesian Reliability Analysis") /
| |
| do not provide any specific criteria based on distribution overlap or lack thereof for when Bayesian update results would not be legitimate. The RBS IE-T3A frequency meets the requirements of Entergy Data Analysis guide EN-NE-G-007 to "Check that the mean value is reasonable when compared to the generic value."
| |
| Note the applicable Supporting Requirement from the Standard was judged to be Met.
| |
| The generic aata for the Internal Events (IE) notebook came from NUREG CR-6928 and was developed using beta or gamma PRA RS Peer Review F&O 4-6 (IE-C4 and distributions. To maintain DA-04):
| |
| consistency with methodology, the Bayesian updating of the This issue was For those 1.E frequencies for which generic plant specific events would be resolved and data IA'.as updated by plant specific data, a performed using a and 13 factors. therefore has no Bayesian process was used. IE notebook IE-C4, However, NUREG CR-6928 also impact in STI change RB-4315 Resolved assumption 5 states that all generic data DA-04 provides mean and error factor evaluations was considered to be lognormal, but no (EF) parameters, which are used performed in basis was provided for that assumption.
| |
| for developing lognormal accordance with the distributions. This would suggest SFCP.
| |
| Possible Resolution: Revise IE notebook that it is acceptable to use the -
| |
| assumption 5 to provide the required data to develop lognormal justification. .
| |
| distributions.
| |
| ( V Converting from gamma or beta distribution to lo normal does
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| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 30 of 57 MCR Status Applicable Finding Disposition.
| |
| Importance to
| |
| .Number SR(s) . . Application cause some loss of fidelity.
| |
| However, the numbers provided in NUREG CR-6928 are best estimates based on the quality of the data provided by each plant.
| |
| Therefore, a small loss of fidelity would not be considered significant because there is some uncertainty in the base numbers.
| |
| The primary reason for developing lognormal plant specific data is to maintain consistency with common cause and human failure events. Using one type of distribution for all of the data that is input into the uncertainty analysis makes possible much more accurate results.
| |
| Initiating Event frequencies for PRA R5 Peer Review F&O 4-7 (IE-C12)
| |
| ISLOCA and BOC are developed in the calculations for those Table 10 of the IE notebook provided the specific events, PRA-RB required comparison for most initiators.
| |
| 002S08 and PRA RB 01-002S15.
| |
| LOOP, breaks outside containment, and This issue was ISLOCAs are not discussed in that table.
| |
| Loss of vital DC bus initiating resolved and From table 10, the frequency of loss of frequency is considered to have a therefore has no vital DC buses is approximately a factor of high degree of site specificity and impact in STI change RB-4316 Resolved IE-C12 1 O below the generic value. The the peer review had no negative evaluations frequency of these 2 initiating events were comments regarding the performed in based on screened generic data, screening methodology. When accordance with the indicating that 90% of the generic events reviewed, the 3 LER's which are SFCP.
| |
| were considered not applicable to RB.
| |
| the basis of the NUREG/CR-5750 Loss of DC initiating event Possible Resolution: Revise the method to frequency are either applicable to determine the IE frequency for loss of vital other higher CCDP transients or de busses to use a fault tree model.
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| simolv not a transient initiator.
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| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 31 of 57
| |
| **MCR* Applicable *. lmp.ort~.nce to;
| |
| .:Number
| |
| 'Status * . . SR(s): .. Fin.ding Disposition .
| |
| Application The Loss of DC frequency at a non-Entergy. BWR/6 of 5.25E-04 is comparable to that of RBS (1.83E 04) despite the fact that that plant is accounting for a 1987 Loss of DC event in developing its plant specific initiator frequency. (section 3.5.2 of its IE notebook, -PSA-001). The other non-Entergy BWR6 has a single Loss of a Non-Safety DC bus initiator with a frequency of 4.65E-03, but documents an additional BWR with a 3.30E-04 frequency (DB-004-IE Sec.4.2).
| |
| Thus, comparison to other plants shows that the RBS value is not an outlier and compares appropriately to other plant values.
| |
| Since Loss of DC events have a CCDP of approximately E 06, and a generic frequency of 1.17E-03, highly conservative use of the generic frequency would only result in a near-negligible CDF
| |
| .contribution of approximately 1E 09.
| |
| Note the applicable Supporting Requirement from the Standard was judged to be Met.
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 32 of 57 MCR Status Applicable Finding Disposition Importance to Number SR(s) Application RBS R5 Peer Review F&O 4-9 (AS-A3) r The A TWS event analyses, documented in PRA-RB-01-002S07 revision 1, table 1 identifies the systems associated with each safety function. That table also identifies safety function success criteria This issue*was in most cases. The success .criteria for resolved and Updated Section 2.1 and Table 1 RPS-mechanical was found in a notebook therefore has no of the ATWS notebook to provide assumption. However, there is at least impact in STI change RB-4317 Resolved AS-A3 more detail on the A TWS one instance in which success criteria is evaluations Success Criteria, especially for not documented in table 1. An example is performed in SLC.
| |
| SLC. accordance with the SFCP.
| |
| Possible Resolution: Update the documentation to specify the missing success criteria or provide a pointer to where that criteria is located. In addition, update table 1 to include all success criteria.
| |
| PRA R5 Peer Review F&O 4-14 (SY- Added the following additional A19): detail to Assumption 2 of the Revision 6 system Feedwater/Condensate system analysis has been PRA-RB-01-002S11, LPCI and CCP notebook: updated to include system models contain basic events for maintenance unavailability of the RHR Three Condensate pumps and unavailability for pumps and CCP pumps at the component three Feedwater pumps are condensate, level. Basic events for maintenance operating during 100% power feedwater, and unavailability are indicated by 'MA' in the operation [1, 2]. After complete makeup water RB-4318 Resolved SY-A19 basic event name. implementation of the Power pumps.
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| Uprate modification, it was Section 1.7 of the system notebooks determined that two condensate No impact expected documents the review of test and pumps may not provide sufficient in STI change maintenance applicability associated with flow to the suction of the reactor evaluations a given system/train/component. feed pumps at 100% reactor performed in power, so three pumps are accordance with the PRA-RB-01-002S11 R1 documents the normally used to ensure positive SFCP.
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| feedwater and condensate system condensate flow to the reactor
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 33 of 57 MCR Applicable Importance.to Status Finding Disposition Number SR(s) Aoolication analysis. Unavailability of a feedwater or feed pumps in the event that one condensate pump due to maintenance is condensate pump fails [2]. Plant not included in the analysis. There are 3 operation at reduced power levels 40% feedwater pumps and 3 50% can be achieved with two condensate pumps. Therefore, condensate pumps and one ,,
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| maintenance of a single feedwater pump heater string in service.
| |
| or a single condensate pump during Feedwater and Condensate power operations is possible. pump maintenance unavailability are accounted for in the initiating Possible Resolution: Add maintenance event logic for the Loss of unavailability to the feedwater and Feedwater event and these condensate system analysis. unavailabilities are mapped in EOOS for configuration risk manaqement purposes PRA Peer Review F&O 5-4: (HR-E4)
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| No documentation of simulator
| |
| '-- observations were identified. While Appendix C to PRA-RB-01-002S03 This issue was documents operator input for the HRA Documentation of simulator resolved and analysis, no documented talk throughs or observations by PRA staff and therefore has no review by either Operations Staff or other discussions with Operations impact in STI change RB-4321 Resolved HR-E4 Operations Training Staff with respect to regarding the RBS PRA model is evaluations the response modeling (accident discussed in and documented performed in sequence progression) was identified. with the Rev.6 HRA notebook, accordance with the PSA-RBS-01-HR.
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| SFCP.
| |
| Possible Resolution: Involve/conduct and document Operations/Operations Training review of the response models to insure timing and operator response modeling is correct.
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 34 of 57 MCR Applicable Importance to Status Finding Disposition Number SR(s) Application RBS PRA Peer Review F&O 5-5 (HR E-4):
| |
| B21-XHE-FO-INHIB was identified which coupled two separate operator actions (inhibit ADS and terminate and prevent HPCS) in a single action. Both of these Changes have been incorporated This issue was actions may or may not be performed by resolved and the same individual. Spreadsheet Separated the B21-XHE-FO- therefore has no HFE_CP.xls only evaluates inhibit ADS INHIB into B21-XHE-FO-INHIB impact in STI change RB-4322 Resolved HR-E4 with no execution probability based on a for ADS Inhibit and E22-XHE-FO- evaluations simple action (agree), however, terminate INHIB for HPCS termination. performed in and prevent of HPCS is performed via a accordance with the hardcard (several actions).
| |
| SFCP.
| |
| Possible Resolution: Model the inhibit ADS during an ATWS and terminate and prevent HPCS as separate operator actions (separate actions on EOP-01A in step RCA-3)
| |
| RBS RS PRA Peer Review F&O 5-6: (HR- The Revision 5 RBS model has E2, HR E-4) an action (B21-XHE-FO-LVCTL) to control RPV level and power An operator action was not during an A TWS. The operator identified/modeled for the termination and action to terminate LP injection is This issue was prevention of the low pressure injection included in the control of RPV resolved and systems (EOP-01A RLA-13). Following level and power control. During a therefore has no an emergency depressurization, if this full power A TWS, the MS IVs HR-E4, impact in STI change RB-4323 Resolved action was not performed, a substantial close on high pressure, so HR-E2 evaluations uncontrolled injection could occur feedwater will empty the hotwell performed in resulting in a power excursion. Operator pretty quickly. CRD and RCIC accordance with the review/walk through/talk through the have limited flow so the RPV SFCP.
| |
| specific accident sequence may have level cannot be maintained above identified this detail. -186 inches requiring emergency depressurization. RPV pressure Possible Resolution: Model the low would have to be reduced to pressure terminate and prevent operator about 200 psiq before LPCI and
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 35 of 57 MCR* *Applicable Importance to*
| |
| * :,Status,,** Finding Disposition . .. .,
| |
| 1 Numb~r *. -SR(s) . .
| |
| * Aoolication action and validate with Operations/ LPCS would inject. The Operations training. operators would control level increase to limit power oscillations so they would not allow all LPCI and LPCS pumps c_ inject immediately after depressurization. The action to l terminate LP injection is only entered if the RPV level is above
| |
| -56 inches. If the operators control RPV level between -186 inches and -56 inches, then there is never a need to terminate all LP injection.
| |
| Therefore, the task analysis discussion in 821-XHE-FO-LVCTL was updated to be consistent with EOP-1A, but the human error probability for this operator action encompasses the action to terminate ECCS injection at the upper level control band (ULCB is -56 inches per EOP-1A).
| |
| RBS R5 PRA Peer Review F&O 5-7 (HR- Findings 5-5 and 5-6 addresses E3) the modeling of terminate-and-prevent EOP actions.
| |
| This issue was Appendix C to PRA-RB-01-002S03 resolved and documents operator input for the HRA. Resolution of this finding was therefore has no Per discussion with the RBS HRA analyst, primarily documentation in nature impact in STI change RB-4324 Resolved HR-E3 interviews involved discussions of as consideration of operator tools evaluations procedural application. However, is implicit in operator interviews in performed in operator action B21-XHE-FO-INHIB as support of HRA analyses and in accordance with the presented (page 127) coupled the inhibit other interactions with Operations SFCP.
| |
| ADS action with the HPCS terminate and staff that results in inputs to the prevent action. In the development of the plant PRA. Continued interaction action in spreadsheet HFE GP.xis, the with Operations staff, including
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 36 of 57 MCR Applicable Importance to Status
| |
| * SR(s) . .Finding Disposition. * , Aaalication*
| |
| Number action was modeled only as the inhibit regular simulator observations by ADS function. When the use of the site PRA engineer, has not operational "hardcards" (as documented identified any deviations between on the operator interview sheet) was the "Hard Cards" of procedure asked, the more experienced PRA staff OSP 0053 (Emergency and did not indicate awareness of this Transient Response Support application. HPCS terminate and prevent Procedure) and detailed is a specific "hardcard" shown in OSP- Abnormal Operating Procedure 0053 as Attachment 5. While an (AOP) instructions. This is as extensive review could not be conducted, anticipated, as OSP 0053 is this singular thread could indicate a intended to provide the same weakness in confirming (understanding) important guidance as in AO P's actual plant operational aspects and and per EOP's .but in a more procedural usage. streamlined fashion. Per OSP 0053, "Hard Cards" were Possible Resolution: Review the developed to reduce the information documented on the talk probability of operator error in th roughs to ensure the developed HEPs carrying out these actions and model the as-operated facility. are considered an expedited "short form" for response to transients.
| |
| Note OSP-0053 Hard Cards were mentioned only once during operator interview related to Initiating Events or HRA in support of PRA Revision 5 or for interviews conducted during the
| |
| / Internal Flooding Analysis. Hard Cards also were not a topic brought up during Expert Panel meeting or in various discussions that have occurred with Operations staff regarding PRA models over the past several years. Thus, it is concluded that the reliance on procedures (and olant focus on Procedural
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 37 of 57 MCR Applicable Importance to .
| |
| Status Finding .. Disposition .
| |
| Number SR(s) . Application Adherence) provides the basis for confirming adequate consideration of plant operational aspects and procedural usage with regard to the HRA and other aspects of PRA modeling. This is consistent with recent observations of simulator scenarios by PRA staff. It is thus concluded that the basis for modeling of Operator actions in HRA analyses is robust and proper.
| |
| Use of OSP-0053 Hard Cards is sometimes noted as part of simulator observations performed by the plant PRA engineer. The roughly quarterly simulator observations along with communications with Operations on risk assessment issues ensures that the plant PRA for River Bend reflects actual plant operational aspects and procedural usage.
| |
| RBS PRA R5 Peer Review F&O 5-8 (SY- Concurrent maintenance events A20): have been added to the CAFTA model per MCR RB-4285. That This issue was DA-C14 basis for assessment notes that included addressing impact of resolved and Appendix Hof PRA-RB-01-002S05 Rev1 concurrent maintenance on the therefore has no EC22619.pdf discusses 'super outages' Service Water fault tree model. impact in STI change RB-4325 Resolved SY-A20 that occur usually twice a year on various There is no need to address any evaluations components belonging to intersystem concurrent maintenance on the performed in trains. Basic events CONCRNT-MA- CRD system as there is no such accordance with the D1V01, CONCRNT-MA-D1V02, and maintenance and the CRD SFCP.
| |
| CONCRNT-MA-D1V03 were developed for hydraulic system is a low risk these outaQes. AlthouQh developed to importance system thus
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 38 of 57 MCR Applicable Importance to Status Finding Disposition Number SR{s) . Aoolication .
| |
| represent actual maintenance practices, maintenance impacts have these basic events do not appear in the negligible impact on the base PRA fault model. PRA model (and concurrent maintenance does not impact risk Also, the CRD System and SW fault tree changes in EOOS). No action models do not include the simultaneous beyond that already completed unavailability of redundant equipment due per MCR RB-4285 is required.
| |
| to technical specification constraints for planned activities.
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| Possible Resolution: Incorporate these events into the model. Evaluate CRD and SW for possible simultaneous maintenance conditions.
| |
| RBS PRA R5 Peer Review F&O 5-10 While additional insights would be (QU-04 and LE-F2) obtained from a deeper and more detailed review of differences A comparison among the BWR/6 between plants, the level of detail population was conducted and is at which River Bend has documented in PRA-RB-01-002 revision performed this comparison is
| |
| : 1. Observations of differences were judged to be better than average.
| |
| noted, however, additional depth as to the RBS participates in the monthly differences may be required establish BWR6 PRA conference call, This issue was more credible explanations. For example, which includes discussions of the resolved and the loss of the power conversion system various plant system models to therefore has no QU-04 differences may to more attributable to the allow for understanding of impact in STI change RB-4326 Resolved LE-F2 additional containment heat removal differences due to plant designs evaluations capability at RB verses high pressure and modeling. Additional insights performed in injection when compared to Plant "B" have been gained through accordance with the (Plant B also has a motor driven participation in the Perry Level 2 SFCP.
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| feedwater pump). Additionally, higher focused scope peer review and SBO contributions were attributed to the through support work for the dependence upon electrical switchgear Grand Gulf PRA Revision 4A, room cooling (RCIC is not dependent completed in 2017.The additional upon electrical switchgear room cooling). insights would be of value but This SR is marked as met, however, a would not result in changes to the finding has been given to-establish more results of the plant PRA.
| |
| credible explanations of the deltas. Additionallv, the recent BWROG
| |
| | |
| ENTCORPSO-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 39 of 57 MCR Applicable Importance fo *
| |
| '. Status . . SR(s) . Finding Disposition Number Application report on cross-comparison of Possible Resolution: Provide a more PRA results has been reviewed detailed/credible comparative analysis of for potential insights based on significant deltas identified. differences between plants. Thus, this Finding was documentation in nature and has been closed as part of th~ Revision 6 PRA update.
| |
| With the Level 2 update (PSA-RBS-01-L2-01, Revision 0), the RBS LERF profile changed significantly. The updated results are compared to similar plants in the updated document.
| |
| RBS PRA RS Peer Review F&O 6-2 (DA- DG information from the Revision D4): 5 Data calculation PRA-RB 002S05 (p.64) clearly shows an BYS-EG1 FTR distribution shows a prior appropriate overlap between of 8E-4 while the plant data is near 1E-2. plant specific and generic data, Concern is that generic data from reliable for both Standby DG's and the components is applied to an unreliable SBO DG. While the plant specific component. Found the same concern 50th percentile value is about the This issue was with EGS-EG1A,B and E22-* on page 65. 95th percentile of the generic resolved and FTR data, the plant specific FTS therefore has no As a follow-up, the utility stated the first distribution is entirely bounded by impact in STI change RB-4330 Resolved DA-D4 distribution did not meet their acceptance the generic distribution and the evaluations criteria, but the second did (not less than plant specific F1 (failure to run performed in 5 percentile of generic mean). Plant first hour) data is smaller than the accordance with the criteria may not meet the reasonableness generic data (50th percentile of SFCP.
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| requirement of the standard. plant distribution is about 5th percentile of generic distribution).
| |
| Possible Resolution: Review the updated This clearly passes the results and correct any values that do not reasonableness test for meet the acceptance criteria. application of Bayesian updating.
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| Document the review that the posterior There is no known significant distributions to confirm the Bayesian different in unreliability amongst updates were aooropriate. RBS diesel generators that would
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 40 of 57 MCR Applicable Importance to Status Finding Disposition Number SR(s) Application impact the calculation of failure rates using Bayesian updating.
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| - The DA-D4 comment in part concerns the Station Blackout diesel generator, which was replaced in 2010 with a new unit.
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| The new diesel would be expected to have improved reliability. Even so, R5 of the PRA used the conservative plant specific FTR data in the Bayesian update process to establish a value of 3.47E 02.
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| Note the applicable Supporting Requirement from the Standard was judged to be Met.
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| No action required in response to this Findini:i/MCR.
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| Guide EN-NE-G-010 Attachments RBS PRA R5 Peer Review F&O 6-5 (DA- 6.4 and 6.5 provide the event and C1): component type identifiers and standard failure modes codes for The generic data document PRA-ES-c01- Entergy PRA's. The Tables in This issue was 003 has a type code of BUS FTOP where calculation ES 01 003 show the resolved and the database has a type code of BAC NO mapping of VY failure modes, per therefore has no for bus failure to operate. There is no EN-NE-G-010, to the NUREG/CR impact in STI change RB-4331 Resolved DA-C1 direct tie from the database to the 6928 failure modes. This evaluations documentation. Also, the ASL DN type confirms, for example, that BUS performed in appears to be STL FTOP in the generic FTOP from the NUREG is accordance with the data document. mapped for VY to BAC LP or SFCP.
| |
| BOC LP for VY, bus fail to Possible Resolution: Resolve the operate events for AC or DC differences between the documentation busses.
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| and the contents of the PRA database.
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| The RBS CAFTA database file
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 41 of 57 includes in the Type Code data window the corresponding NUREG/CR-6928 type codes; BAC NO and BOC NO are tied to BUS FTOP, and ASL ON and ASL NO are tied to STL FTOP demand failures.
| |
| Thus, documentation exists to provide the direct tie from the source NUREG to the RBS type codes.
| |
| Note the applicable Supporting Requirement from the Standard was judged to be Met.
| |
| Since the discussed documentation exists, no further work is required for closure of this MCR.
| |
| RBS PRA R5 Peer Review F&O 6-6 (OA-06):
| |
| Found in FPW-ENG-C2-2FTR that it Corrections to the EOG fail to run appears to use a generic independent for the first hour/fail to start were This issue was event as described in PRA-RB-01-002S04 made. Additional errors were resolved and and not the calculated independent event discovered during the review of therefore has no in the database that matches the the CCF files to address this F&O OA-06, impact in STI change RB-4332 Resolved document PRA-RB-01-002S05. (2.07E-03 and were corrected and SY-B4 evaluations EF 9.8 vs. 3.75E-04 EF 18). Checked the incorporated as well in the RBS performed in spreadsheet RBSCCF that was used to PRA model. Corrections also accordance with the develop the CCFs and found the 2.07E-3 made and incorporated for the SFCP.
| |
| event was used. The cutset file provided FPW CCF and EOG FO transfer (RBS-R5_rec_merged.cut contains the pump CCF terms.
| |
| 3.75E-4 value.
| |
| Possible Resolution: U date the CCF BE
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 42 of 57 MCR Applicable Importance to
| |
| . ~tatus . SR(s): Finding Disposition
| |
| * Number Application /:.
| |
| calculation to use the current independent BE failure values and consistent component boundaries.
| |
| RBS PRA R5 Peer Review F&O 6-7 (DA-D6, SY-B4)
| |
| The EDGs independent run basic events have been split into first hour and fails to continue running events (e.g. EGS-DGN-F1-EG01A and EGS-DGN-FR-EG01A).
| |
| The CCF basic events have combined failure to start and failure to run for the first hour (e.g. EGS-DGN-C2-DGFR), but This issue was this is not well documented, and the BE Changes were made to the CCF resolved and name is misleading. documentation and values therefore has no DA-D6, developed for EDGs events noted impact in STI change RB-4333 Resolved SY-B4 Did not find CCFs for EOG FO transfer in the finding description. evaluations pump check valves (e.g. EGF-CKV-CC- Changes were incorporated in the performed in V33) although CCFs exist for pumps. RBS PRA model. accordance with the
| |
| - This omission was self-identified by the SFCP.
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| PRA staff, but has not yet been incorporated into the model.
| |
| Possible Resolution: Update the CCF analysis to include the missing CCF events for the transfer pumps.
| |
| Enhance the documentation of the DG CCF events to better explain the FTS and FTR modelin~.
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 43 of 57 Table 2 List of Finding F&Os against the RBS Internal Flooding and LERF Models (from Revision 6 Focused-Scope Peer Review)
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| . . )'
| |
| MCR '
| |
| . 'Status
| |
| ,Applicable Finding Disposition Importance to Number ' - SR(s) . - .. _aoolication Operator interviews for the hydrogen control system and containment isolation operator actions are documented in the HRA notebook. (see events CIS-XHE-FO-ISOL, HCS-XHE-SR LE-C6 back-references to SY SRs FOIGNIT and HCS-XHE-FO-for modeling of the additional systems ENG1).
| |
| that may be added into the PSA for Level 2 accident progression modeling.
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| Section 2.1 of the RBS System SR SY-A4 CC-II requires plant notebook discusses the walkdown walkdowns and interviews with plant process and continual interactions personnel regarding the system with Operations and System modeling. The HCS and CIS system Engineering regarding This is a analyses (PSA-RBS-01-SY, Appendices confirmation of the RBS PRA documentation issue.
| |
| 17 and 28, respectively) do not model. Therefore, no impact is incorporate walkdowns or interviews expected in STI RB-6085 Unresolved LE-C6 with plant personnel as required by SR Regarding walkdowns, Section 2.1 change evaluations SY-A4.
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| of the RBS System notebooks performed in credit 'The continual use of EOOS accordance with the (This F&O originated from SR LE-C6, by Operations and other plant SFCP.
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| Finding 2-3) personnel ensures that the model accurately reflects the as-built, as-Possible Resolution: Revise the HCS operated plant. This is further and CIS system analyses (PSA-RBS substantiated by plant walkdowns SY, Appendices 17 and 28, respectively) by PSA staff, multiple cutset to incorporate walkdowns and interviews reviews during model updates with with plant personnel as required by SR Operations, System Engineering, SY-A4.
| |
| and other knowledgeable plant personnel, and frequent use of the model by Maintenance Rule personnel. Issues or questions raised during any of these processes result in a Model
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 44 of 57 MCR Applicable Importance to Status Finding Disposition Number SR(s) aoolication Change Request (MCR) for the PSA staff to address." Adding additional documentation of walkdowns the '
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| igniters, HCS diesel and of containment isolation valves is not expected to result in any changes to the PRA models.
| |
| Section 4 of PSA-RBS-01-L2-01, Rev. 0, River Bend Level 2 PRA, states that accident sequences that are successfully in the Level 1 remain depressurized for the Level 2 analysis.
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| This is reflected in the Level 2 PSA logic under the L2-LATE-INJ-FAIL gate where low pressure injection is allowed without questioning whether the SRVs remain Additional discussion regarding functioning. The Level 2 analysis does equipment survivability, including not provide the justification for continued addressing SRV's, has been This issue was functioning of the SRVs during the added to Level 2 notebook PSA- resolved and therefore extreme high temperatures during core RBS-01-L2-01 Section 6.1.4. This has no impact in STI RB-6086 Resolved LE-C9 damage severe accident progression. Finding was addressed via more change evaluations detailed documentation. No performed in (T,his F&O originated from SR LE-C9, changes to the Level 2 model accordance with the Finding 2-4) were required. This information SFCP.
| |
| was also provided to the NRG in Possible Resolution: Provide the response to a SAMA RAI.
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| justification in the Level 2 PSA for continued functioning of the SRVs (such that the RPV depressurization remains functioning) during the extreme high temperatures during core damage severe accident progression.
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| In order to meet Capability Category II, review for other similar cases.
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| Screened out flooding areas are clearly The door to the Main Control This is a RB-6095 Unresolved IFSO-A3 identified in Table 1 of AS notebook. Room is an airtight door and thus documentation issue.
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| not subject to water propaqation Therefore, no impact is
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| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 45 of 57 MCR Applicable Importance to Status Finding Disposition Number SR(s) *. aoolication Flood Area 136-30 is a small area through gaps in the door. Thus, expected in STI outside the MCR. It is screened any buildup in water height in the change evaluations because water is assumed to relieve to room would result in failure of the performed in the lower levels via "an appreciable door C136/5 from this elevator accordance with the gap". However, there is limited (and vestibule room to the stairway. SFCP.
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| unspecified) flow area to lower levels There is no flood propagation to (gaps in elevator door and under a the main control room from this normally closed fire door). The location.
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| screening provided in Section 5.5.34 of the !FAS Notebook indicates that up to Thus, this is a documentation 1600 gpm could flow into the area via a issue.
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| FWS rupture. This magnitude of flow could quickly*** fill this small area and while a considerable flowrate to the lower levels is clearly expected, it is not completely clear that water will not also flow under the doors to the MCR.
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| *** Assuming the area is 100 ft-sq, 1500 gpm would raise level at a rate of approximately 1fUmin.
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| Possible Resolution: Provide a more detailed assessment of the potential for water to enter the MCR from FPW breaks in flood area 136-30.
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| Flooding mechanisms are documented Human-induced in the IE notebook. Industry data was flooding represents a used for pipe breaks and ruptures due to small portion of the maintenance. Internal OE was reviewed Additional discussion regarding internal flooding for inadvertent actuation and other human induced flooding is events. A very small events resulting in a flood. necessary. Additional RB-6096 Unresolved IFSO-A4 change to flooding consideration of human induced results is expected.
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| (This F&O originated from SR IFSO-A4, flooding is not expected to change Impact of this finding is Finding 3-4) the IFA results.
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| expected to be assessed in a case-by-Maintenance-Induced flooding is case STI evaluations.
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| screened based on a generally derived
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 46 of 57 MCR Applicable Importance to Status. Finding ' Disposition Number SR(sl aoolication 1.125E-05/yr frequency. This does not directly address the requirement to identify human-induced mechanism.
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| The peer review team judges that the requirement to evaluate human induced mechanisms necessitates a specific evaluation of testing and maintenance activities performed at the plant.
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| Possible Resolution: A more detailed assessment of human induced failure mechanisms is required. It is recommended to consider specific routine and special tests and maintenance for potential human failure which could lead to water release.
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| The LE-F3 SR refers to QU requirements. With regard to QU-E2:
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| Section 6.7 of the Level 2 Report and Appendix G, Section 7.1 of the LERF report provide sensitivities which Impact of this finding is address some key assumptions made in expected to be the development of the PRA model. It is assessed in case-by-not clear how these were selected or if case STI evaluations.
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| they adequately address all relevant A review of key assumptions The STI evaluation assumptions. documented in the LERF analysis process, as described is needed to determine if RB-6101 Unresolved LE-F3 in Section 2.1, already With regard to QU-01: A review of the additional sensitivity analyses are requires sensitivity significant accident sequences/cutsets needed to address the uncertainty studies to be was performed but there is no tabulation associated with them.
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| performed as needed.
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| of the reviewed cutsets and specific Minimal impact in insights (see Section 5.2.1 for non-results or the STI significant cutsets). This is a minor item process is expected.
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| but it would be an improvement to document the significant cutsets similarly to that done for the non-significant cutsets.
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| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 47 of 57 te, MCR Applicable Importance to
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| . Status,: ,' Finding
| |
| * Disposition Number SR(s) " *application (This F&O originated from SR LE-F3, Finding 3-9)
| |
| Possible Resolution: With regard to LE meeting the QU-E2 SR, an assessment should be undertaken to consider the completeness of Appendix G, Section 7.1 of the LERF report with regard to whether uncertainty from key assumptions is adequately addressed for all relevant assumptions.
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 48 of 57 MCR Applicable Importance to
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| ;Status Finding
| |
| * Disposition Number SR(s) application Modification of the system fault tree was performed during the quantification process using FRANX software. This software maps flood initiators to failed equipment and HFEs within the fault
| |
| - tree. Thus, the initiator fails all applicable equipment and triggers the applicable internal events initiator prior to quantification of the fault tree.
| |
| HFEs and applicable isolation fault tree logic for flooding events (e.g., timely isolation of the flood, etc.) are also inserted using FRANX.
| |
| Documentation of system analysis This is a associated with flood isolation is This finding is a documentation documentation issue.
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| provided in PSA-RBS-01-IF-QU section issue and additional discussion is No impact is expected 4.1.5. However, the documentation needed in the IFA analysis.
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| RB-6104 Unresolved IFQU-A2 on STI change does not include dependencies, source The RBS IFA does not contain evaluations performed of unreliability/unavailability data, or how any circular logic that needs to be in accordance with the circular logic was broken. The isolation broken.
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| SFCP.
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| fault trees do not consistently apply isolation valve dependencies due to removal of circular logic and the location for breaking circular logic does not account for the potential for unavailability/unreliability prior to flooding damage of the dependency.
| |
| (This F&O originated from SR IFQU-A2, Finding 4-4)
| |
| Possible Resolution: Add documentation to IF-QU section 4.1.5 to explain flooding isolation component dependencies, data analysis, and the process/location for breaking circular
| |
| | |
| ENTCORP50-R8S-01, Rev. 0 RBS PRA Technical Adequacy Page 49 of 57 MCR Applicable Importance to Status . SR(s) Finding .. *_ Disposition Numb.er .- application '
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| logic and why the break location does not exclude potential insights associated with unreliability/unavailability of dependencies prior to flood damage.
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| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 50 of 57 MCR - Applicable Importance to Status Finding Disposition Number SR(s) application IF-AS notebook (PSA-RBS-01-IF-AS) section 5 describes the scenario development including affected equipment in each flood area for each scenario, applicable flood rates and capacities, and required operator response to mitigate the scenario.
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| Table 2 of IF-AS summarizes the initiator, equipment failure basic events, applicable internal events initiator, and This is a very minor
| |
| -additional failures caused by isolation error in the FRANX failure that are used to map the flood The exclusions noted are very model which does not scenario to applicable internal events minor and nonconsequential change the internal model elements. errors in the software model. events PRA results.
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| RB-6105 Unresolved IFSN-A10 Correction of the specific FRANX No impact is expected Several equipment failures were exclusion errors does not change on STI change "excluded" in the Firelmpact table in the the Internal Flood PRA results. evaluations performed FRANX database that were listed in IF- in accordance with the AS as failed for the scenario. This SFCP.
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| exclusion prevented them from being applied to the fault tree.
| |
| (This F&O originated from SR IFSN-A10, Finding 4-5)
| |
| Possible Resolution: Update the affected FRANX scenarios to reflect all failures documented in IF-AS for the scenarios and re-quantify.
| |
| The calculation of HEPs is documented No impact on STI in the quantification notebook (PSA- changes is expected.
| |
| A review of HEPs included in the RBS-01-IF-QU), attachment B.3. The A consistency check of internal flood analysis needs to be HEPs are quantified using the EPRI HEPs and its RB-6106 Unresolved IFQU-A5 performed and documented. No HRA calculator and generally comply documentation will not changes to the internal flood with the Capability Category II post- impact STI change analysis results is expected.
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| initiator HEP SRs noted in the HR-E, evaluation performed HR-F, and HR-G HLRs. However, the in accordance with the
| |
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| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 51 of 57 MCR Applicable Importance to Status Finding Disposition Number SR(s) aoolication following discrepancies are noted: SFCP.
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| HR-G6: A consistency check of the HEPs was not performed.
| |
| (This F&O originated from SR IFQU-A5, Finding 4-6)
| |
| Possible Resolution: Perform and document an HFE consistencv check.
| |
| Quantification of internal flood accident sequences was performed using the PRAQuant computer software to quantify the one-top fault tree model created by merging the internal events model with the flood initiators, HFEs, and isolation logic. Use of the internal events fault tree as a starting point The HEP seed values ensures appropriate dependencies, are expected to have accident sequences, maintenance minimal impact on the unavailability, and HRA are considered. The HEP seed values are flooding results as the expected to have minimal or no risk significant RB-6108 Unresolved IFQU-A7 QU-C1: It does not appear that HFE impact on the flooding results, as dependencies were values were seeded to a higher level to the risk-significant dependencies captured. This finding ensure that cutsets with multiple HFEs were captured.
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| will be assessed in are not truncated.
| |
| case-by-case STI evaluations.
| |
| (This F&O originated from SR IFQU-A7, Finding 4-8)
| |
| Possible Resolution: Re-quantify the fault tree using seeded HFE values to ensure that combinations are not truncated. Document the process for seedinq in IF-QU.
| |
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| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 52 of 57
| |
| * MCR Applicable. Importance *to
| |
| . Finding Disposition , ..
| |
| Number
| |
| * SR(s) . *. ' .application
| |
| * Documentation of the quantification notebook is lacking significant discussion required by the QU-0 high level requirements.
| |
| QU-01 and 02: Appendix F of the IFQU notebook provides a summary of the cutset reviews performed. These appear thorough but represent review of interim models. There appears to be minimal review of the cutsets yielded by the final IF model. For example, the top IF cutset includes a BE ADS-HOS-RP-QKCNT "FAILURE OF AIR HOSE Reviews of non-significant Internal USED FOR QUICK CONNECTION Flood cutsets were performed but BlW IAS AND SW". This BE is not not documented in notebooks. This is a documented in any current PRA Also, much of the information documentation issue; document and appears to be included discussed in the peer review additional discussion only in a superseded DA notebook. comments is contained in the of flooding results will RB-6109 Unresolved IFQU-82 Updated cutset review would have Summary notebook, which had not impact STI change discussed/reviewed this BE and not been approved at the time of evaluations performed potentially highlighted the DA issue. the peer review and contains risk in accordance with the While minor, this example demonstrates metric information on the SFCP.
| |
| the importance of cutset review of combined IFPRA and Internal dominant cutsets (ASME QU-01 via Event model.
| |
| IFQU-A7, 82). Similarly, cutset review of non-significant cutsets is useful (ASME QU-05 via IFQU-A7, 82).
| |
| QU-04: No comparison to other similar plants is present in the IF notebooks.
| |
| QU-05: It does not appear that a sample of non-significant cutsets were reviewed for consistency.
| |
| QU-06: The IF-QU notebook provides summaries of CDF/LERF contribution
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 53 of 57 MCR Applicable Importance to.
| |
| .Status. Finding Disposition Number SR(s) application percentage by building and system.
| |
| Review of significant contributors associated with equipment failures, operator actions, and common cause failures were not performed.
| |
| QU-07: Review of basic event importance measure results for consistency was not performed.
| |
| QU-F3. Detailed discussion of cutsets is presented in Appendix F of the IFQU notebook. For example, the following cutset description is included:
| |
| "Cutset 1 involves a flood in zone 3 of the 141' elevation of the Aux Building (AB), due to a moderate service water (SW) line break (IE-FLD-AB-141_03SW-M). The SW break requires isolation of Normal Service Water (NSW), resulting in a transient (T-62) sequence.
| |
| Feedwater and condensate fail due to -
| |
| the loss of turbine plant component cooling water (CCS) from the isolation of NSW. High Pressure Core Spray (HPCS) fails due to splashing of the min-flow valve, and control rod drive (CRD) injection fails due to loss of reactor plant component cooling water (CCP) from the isolation of NSW. RCIC fails upon suction transfer to the suppression pool (SP) due splashing of the transfer valves. Random failure of depressurization occurs, meaning no low-pressure injection can occur."
| |
| This provides a very good overview of the cutset. It demonstrates model review and also presents results in a
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 54 of 57 MCR Applicable* Importance to Status.' Finding . .Dispo5.ition Number SR(s) application way understandable for those not familiar with the RBS IF Model.
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| However, these descriptions apply to interim models.
| |
| Development of cutset descriptions similar to the example present here should be developed for the final IF model in order to meet the requirement to: "provide a detailed description of significant accident sequences or -
| |
| functional failure groups" (QU-F3).
| |
| (This F&O originated from SR IFQU-B2, Finding 4-9)
| |
| Possible Resolution: Perform comparisons and reviews as specified in QU elements and add documentation to the IF-QU notebook. -*
| |
| Sources of modeling uncertainty were Impact of this finding is not documented in IF-QU or discussed expected to be with respect to impact on the results.
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| assessed in case-by-case STI evaluations.
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| QU-E1, 2, 4: Sources of modeling The STI evaluation uncertainty were not documented in IF- A review of potential sources of process, as described QU or discussed with respect to impact modeling uncertainty and their in Section 2.1, already RB-6110 Unresolved IFQU-B3 on the results. impact on results is needed. This requires sensitivity review should be documented as studies to be (This F&O originated from SR IFQU-B3, well as the impact on the results.
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| performed as needed.
| |
| Finding 4-10)
| |
| Minimal impact in results or the STI Possible Resolution: Document sources evaluation process is of modeling uncertainty in the IF-OU expected.
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| notebook.
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy J Page 55 of 57 3.3. RBS Fire PRA Model 3.3.1. Plant Changes Not Yet Incorporated River Bend does not currently have a fire PRA model. Any plant changes that may impact fire risk are being incorporated during the development of RBS fire PRA model, planned for completion in 2019.
| |
| 3.3.2. Peer Review Facts and Observations (F&Os)
| |
| Upon completion of the fire PRA, a peer review will be conducted against the AS ME/ANS PRA standard (Reference 4), and the resulting F&Os addressed per Entergy procedures.
| |
| Because RBS does not have a fire PRA per the current AS ME/ANS PRA standard, a bounding fire risk evaluation, based on information from the Individual Plant Examination of External Events (IPEEE, Reference 8) and other available insights for fire risk, is performed for STI ci'<anges in accordance with the guidance of NEI 04-10(Revision 2).
| |
| 3.3.3. Consistency with Applicable PRA Standards As discussed in Section 3.3.1, River Bend does not currently have a fire PRA model.
| |
| 3.4. Identification of Key Assumptions The Initiative Sb is a risk-informed process which uses PRA model results to support a proposed STI change. The IDP uses the PRA results as an input to decide whether an STI change is warranted. The methodology recognizes that a key area of uncertainty for this application is the standby failure rate utilized in the determination of the STI extension impact. Therefore, the methodology requires the performance of selected sensitivity studies on the standby failure rate of the component(s) of interest for the STI assessment.
| |
| Any additional sensitivity studies identified for specific STI changes are also required per NEI 04-10, Revision 1. Therefore, results of the standby failure rate sensitivity study plus the results of any additional sensitivity studies identified during the performance of the reviews of gaps and open items as summarized in Sections D and 3.3 herein, will be documented and included in the results of the risk analysis submitted to the IDP.
| |
| 3.5. External Events and Shutdown Considerations The NEI 04-10 methodology allows for STI change evaluations to be performed in the absence of quantifiable PRA models for all external hazards and shutdown. For those cases where the STI cannot be modeled in the plant PRA, or where a particular PRA model does not exist for a given hazard group, a qualitative or bounding analysis is performed to provide justification for the acceptability of the proposed test interval change.
| |
| External hazards were evaluated in the RBS IPEEE submittal (Reference 8) in response to the NRC IPEEE Program (Reference 7). The IPEEE Program was a one-time review of external hazard risk and was limited in its purpose to the identification of potential plant vulnerabilities and the understanding of associated severe accident risks. RBS does not have a PRA model or applications associated with external hazards such as seismic, high wind or external flooding,
| |
| | |
| ENTCORP50-RBS-01, Rev. 0 RBS PRA Technical Adequacy Page 56 of 57 and quantitative results cannot be provided to support this STI effort. Therefore, a qualitative or bounding approach will be used to assess external event hazard risk at RBS for STI changes.
| |
| Because RBS does not have external hazards or RG 1.200 conforming shutdown PRA models, external hazards and shutdown screening evaluations are performed for STI changes in accordance with the guidance of NEI 04-10, Revision 1.
| |
| The RBS shutdown safety program developed to support implementation of NUMARC 91-06 (Reference 12) is used for the shutdown risk evaluation, or an application-specific shutdown analysis may be performed for STI changes in accordance with the guidance of NEI 04-10, Revision 1. The RBS shutdown safety program includes input from a Defense-in-Depth shutdown EOOS PRA model.
| |
| : 4. CONCLUSIONS The information presented in herein demonstrates that the RBS PRA technical adequacy and capability evaluations, as well as the maintenance and update processes conform to the ASME/ANS PRA Standard, which satisfies the guidance of RG 1.200, Revision 2.
| |
| : 5. REFERENCES
| |
| : 1. TSTF-425, "Technical Specification Task Force - Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative Sb", Revision 3, March 2009.
| |
| : 2. NEI 04-10, "Risk-Informed Technical Specifications Initiative Sb. Risk-Informed Method for Control of Surveillance Frequencies", Revision 1, April 2007.
| |
| : 3. Regulatory Guide 1.200, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities", Revision 2, March 2009.
| |
| : 4. ASME RA-Sa-2009, "Standard for Level 1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications", February 2009.
| |
| : 5. PSA-RBS-01, "RBS PSA Summary Report", Revision 0, October 2017.
| |
| : 6. "River Bend Station PRA Peer Review Report Using ASME/ANS PRA Standard Requirements", July 2011.
| |
| : 7. Generic Letter 88-20, "Individual Plant Examination of External Events (IPEEE) for Severe Accident Vulnerabilities-10CFR 50.54(f), Supplement 4", June 1991.
| |
| : 8. Engineering Report SEA-95-001, "Individual Plant Examination of External Plants (IPEEE)",
| |
| June 1995.
| |
| : 9. PSA-RBS-06-02, "Evaluation of River Bend Station PRA Model", Revision 0, April 2017.
| |
| : 10. RG 1.174, "An approach for using probabilistic risk assessment in risk-informed decisions on plant-specific changes to the licensing basis", Revision 2, May 2011.
| |
| | |
| ENTCORP50-R8S-01, Rev. 0 RBS PRA Technical Adequacy Page 57 of 57
| |
| : 11. NUREG/CR-6850 - EPRl-1011089, "Fire PRA Methodology for Nuclear Power Facilities",
| |
| August 2005.
| |
| : 12. NUMARC 91-06, "Guidelines for industry actions to assess shutdown management",
| |
| December 1991. *
| |
| : 13. NEI 05-04, "Process for Performing Internal Events PRA Peer Reviews Using the ASME/ANS PRA Standard", November 2008.
| |
| : 14. NEI 05-04/07-12/12-06 Appendix X, "Closeout of F&Os", March 2017 (NRC ADAMS Accession No. ML16158A035).
| |
| : 15. RBS-NE-14-00002, "RBS Rev. 5 PRA Technical Adequacy", Revision 0,
| |
| | |
| Attachment 3 RBG-47799 Proposed Technical Specification Changes
| |
| | |
| Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Determine the position of each control rod. 24 hours +~----
| |
| SR 3.1.3.2 DELETED
| |
| _)
| |
| SR 3.1.3.3 ---------------------------NOTE--------------------------------
| |
| Not required to be performed until 31 days after the control rod is withdrawn and THERMAL POWER is greater than the LPSP of the RPCS.
| |
| Insert each withdrawn control rod at least one notch. 31 days ~ , - - - ~
| |
| SR 3.1.3.4 Verify each control rod scram time from fully In accordance with withdrawn to notch position 13 is :s; 7 seconds. SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4 (continued)
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.1-9 Amendment No. ~. 4-e-1-,
| |
| | |
| Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS
| |
| ------------.. --------------------------------------------NOTE------------------------------------------------------------
| |
| D uring single control rod scram time Surveillances, the control rod drive (CRD) pumps shall be isolated from the associated scram accumulator.
| |
| SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify each control rod scram time is within the limits Prior to exceeding of Table 3.1.4-1 with reactor steam dome pressure 40% RTP after
| |
| ~ 950 psig. each reactor shutdown
| |
| ~ 120 days SR 3.1.4.2 Verify, for a representative sample, each tested 200 days ~ : : - - - -
| |
| control rod scram time is within the limits of cumulative Table 3.1.4-1 with reactor steam dome pressure operation in
| |
| ~ 950 psig. M0DE1 SR 3.1.4.3 Verify each affected control rod scram time is within Prior to declaring the limits of Table 3.1.4-1 with any reactor steam control rod dome pressure. OPERABLE after work on control rod or CRD System that could affect scram time (continued) in accordance ,Nith the Surveillance Frequency Control Pro~iram RIVER BEND 3.1-12 . Amendment No. 81 126, 4-ea,
| |
| | |
| Control Rod Scram Accumulators 3.1.5 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2 Declare the associated 1 hour control rod inoperable.
| |
| D. Required Action and 0.1 -------._ -NOTE-----------
| |
| associated Completion Not applicable if all Time of Required Actibn inoperable control rod B.1 or C.1 not met. scram accumulators are ass9ciated with fully inserted control rods.
| |
| Place the reactor mode Immediately switch in the shutdown position.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each_ control rod scram accumulator pressure 7 Elay:s ~
| |
| is~ 1540 psig.
| |
| In accordance with the Surveillance Frequency Contmi Program RIVER BEND 3.1-17 Amendment No. ~. 444,
| |
| | |
| Control Rod Pattern 3.1.6 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME B. Nine or more OPERABLE 8.1 ----------NOTE---------
| |
| control rcids not in A ffected control rods compliance with BPWS. may be bypassed in RACS in accordance with SR 3.3.2.1.9 for insertion only.
| |
| Suspend withdrawal of Immediately control rods.
| |
| 8.2 Place the reactor mode 1 hour switch in the shutdown position.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify all OPERABLE control rods comply with 24 f::l 91:lFS '
| |
| BPWS.
| |
| In accordance vvith the Surveillance Frequency Control Program RIVER BEND 3.1-19 Amendment No. &:1-,
| |
| | |
| SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 -----------------------------NOTE--.--------------------------
| |
| The minimum required available solution volume is determined by the performance of SR 3.1.7.5.
| |
| Verify available volume of sodium pentaborate 24 hours solution is greater than or equal to the minim um required available solution volume.
| |
| SR 3.1.7.2 Verify temperature of sodium pentaborate 24 hours '
| |
| solution is ~ 45°F.
| |
| \
| |
| SR 3.1.7.3 ----------------------------NO TE------------- * ------------------
| |
| Sodium Pentaborate Concentration (C), in w eight percent, is determined by the performance of SR 3.1.7.5. Boron-10 enrichment (E), in atom percent, is determined by the performance of SR 3.1.7 .9.
| |
| Verify that the SLC System satisfies the foll owing J~ Elays '
| |
| equation:
| |
| (C)(E) ~ 570 SR 3.1.7.4 Verify continuity of explosive charge. J~ Elays ,
| |
| (continued)
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.1-21 Amendment No. g.:J., 444,
| |
| | |
| SLC System 3.1.7 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.1.7.5 Verify the available weight of Boron-10 is 2 143 lbs, 31 days and the percent weight concentration of sodium pentaborate in solution is :<::; 9.5% by weight, and determine the minimum required available solution volume. Once within 24 hours after water or boron is added to solution Once within 24 hours after solution temperature is restored to 2 45°F SR 3.1.7.6 Verify each SLC subsystem manual, power operated, 31 days and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position, or can be aligned to the correct position.
| |
| SR 3.1.7.7 Verify each pump develops a flow rate 2 41.2 gpm at In accordance with a discharge pressure 2 1250 psig. the lnservice Testing Program SR 3.1.7.8 Verify flow through one SLC subsystem from pump 24 months on a '<"'"-----!
| |
| into reactor pressure vessel. STAGGERED TEST BASIS (continued)
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.1-22 Amendment No. 81 114, 4@g,
| |
| | |
| SDV Vent and Drain Valves 3.1.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 ---------------------------NOTE---------------------------------
| |
| Not required to be met on vent and drain valves closed during performance of SR 3.1.8.2.
| |
| Verify each SDV vent and drain valve is open. 31 days _ _ _ _ __,
| |
| SR 3.1.8.2 Cycle each SDV vent and drain valve to the fully 92 days closed and fully open position.
| |
| SR 3.1.8.3 Verify each SDV vent and drain valve: 24 months ~ - - - - - 1
| |
| : a. Closes in ::;; 30 seconds after receipt of an actual or simulated scram signal; and
| |
| : b. Opens when the actual or simulated scram signal is reset.
| |
| In accordance the Surveillance Frequency Control Prograrn RIVER SEND 3.1-25 Amendment No. 34-, 4-@g,
| |
| | |
| APLHGR 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)
| |
| LCO 3.2.1 All APLHGRs shall be less than or equal to the limits specified in the COLR.
| |
| APPLICABILITY: THERMAL POWER~ 23.8% RTP.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any APLHGR not within A.1 Restore APLHGR(s}' to within 2 hours limits. limits.
| |
| B. Required Action and B.1 Reduce THERMAL POWER 4 hours associated Completion to< 23.8% RTP.
| |
| Time not met.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify all APLHGRs are less than or equal to the Once within limits specified in the COLR. 12 hours after
| |
| ~ 23.8% RTP 24 hours < f - - - - ~
| |
| thereafter In accordance with the Surveillance Frequency Control Program RIVER BEND 3.2-1 Amendment No. 81, 114,
| |
| | |
| MCPR 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)
| |
| LCO 3.2.2 All MCPRs shall be greater than or equal to the MCPR operating limits specified in the COLR.
| |
| APPLICABILITY: THERMAL POWER~ 23.8% RTP.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any MCPR not within A.1 Restore MCPR(s) to within 2 hours limits. limits.
| |
| ~
| |
| B. Required Action and B.1 Reduce THERMAL POWER 4 hours associated Completion to < 23.8% RTP.
| |
| Time not met.
| |
| \ ,
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify all MCPRs are greater than or equal to the Once within limits specified in the COLR. 12 hours after
| |
| ~ 23.8% RTP
| |
| <,b.,dd a 24 hours<<------..
| |
| thereafter RIVER BEND 3.2-2 Amendment No. 81, 114,
| |
| | |
| LHGR 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 LINEAR HEAT GENERATION RATE (LHGR)
| |
| LCO 3.2.3 All LHGRs shall be less than or equal to the limits specified in the COLR.
| |
| APPLICABILITY: THERMAL POWER~ 23.8% RTP.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any LHGR not within A.1 Restore LHGR(s) to within 2 hours limits. limits.
| |
| B. Required Action and B.1 Reduce THERMAL POWER 4 hours associated Completion to < 23.8% RTP.
| |
| Time not met. I SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify all LHGRs are less than or equal to the limits Once within specified in the COLR. 12 hours after
| |
| ~ 23.8% RTP 24 h o u r s - - - - -
| |
| thereafter In accordance with the Surveiliance Frequency Control Program RIVER BEND 3.2-3 Amendment No. 81, 114,
| |
| | |
| FCBB 3.2.4 .
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 ---------------------------NOTE ----------------------------------
| |
| Not required to be performed until 15 minutes after entry into the Restricted Region if entry was the result of an unexpected transient.
| |
| Verify FCBB :<::; 1.0. 24 hours ....-------.
| |
| Once within 15 minutes following unexpected transient
| |
| /
| |
| \
| |
| RIVER BEND 3.2-6 Amendment No.400,
| |
| | |
| RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS
| |
| --------------------. -------------------------------------NO TES-------------------------------------- '------------------
| |
| : 1. Refer to Table 3.3.1.1-1 to determine which SRs apply for each RPS Function.
| |
| : 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for
| |
| * up to 6 hours provided the associated Function maintains RPS trip capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK.
| |
| SR 3.3.1.1.2 -----------------------------NOTE--------.-------------------
| |
| Not required to be performed until 12 hours after THERMAL POWER~ 23.8% RTP.
| |
| Verify the absolute difference between the average 7 days <.--------1 power range monitor (APRM) ctfannels and the calculated power :s; 2% RTP<a>.
| |
| SR 3.3.1.1.3 Adjust the flow control trip reference card to Once within conform to reactor flowCbl. 7 days after reaching equilibrium conditions following refueling outage.
| |
| (a) For a period of 30 days beginning with uprate COLR implementation and corresponding plant monitoring computer data bank changes the difference between the average power range monitor (APRM) channels and the calculated power must be within -2% RTP to
| |
| +7% RTP.
| |
| (b) Within 30 days of uprate COLR implementation and corresponding plant monitoring computer data bank changes the flow control trip reference card will be verified to conform to reactor flow in accordance with the uprated COLR.
| |
| (continued)
| |
| In *accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-:-3 Amendment No. 81100 106,114,
| |
| | |
| RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.3.1 :1.4 ------------------------------NOTE----------------------------
| |
| Not required to be performed when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2.
| |
| Perform CHANNEL FUNCTIONAL TEST. 7 flays*~
| |
| SR 3.3.1.1.5 Perform CHANNEL FUNCTIONAL TEST. 7 flays SR 3.3.1.1.6 Verify the source range monitor (SRM) and Prior to intermediate range monitor (IRM) channels withdrawing SRMs overlap. from the fully inserted position SR 3.3.1.1.7 ------------------------------N O TE----------------------------
| |
| Only required to be met during entry into MODE 2 from MODE 1.
| |
| Verify the IRM and APRM channels overlap. 7 flays SR 3.3.1.1.8 Calibrate the local power range monitors. 2QQQ MWQt+ ~
| |
| average core e*f30Sl:lF9 SR 3.3.1.1.9 Perform CHANNEL FUNCTIONAL TEST. 92 flays~
| |
| t
| |
| / <Delete line s p ace> ~ continued
| |
| <Move SH row to next page>
| |
| In accordance \Nith tile Surveiilance Frequency Control Program RIVER BEND 3.3-4 Amendment No. 81 1QQ 106 1Q7, 114,
| |
| | |
| RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.3.1.1.10 Calibrate the trip units. 9~ says -
| |
| SR 3.3.1.1.11 -------------------------------NOTES--------------- -----------
| |
| : 1. Neutron detector.s and flow reference transmitters are excluded.
| |
| : 2. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2.
| |
| : 3. For Function 2.b. the digital compone nts of the flow control trip reference cards are excluded.
| |
| Perform CHANNEL CALIBRATION. 184 says~
| |
| I .
| |
| SR 3.3.1.1.12 Perform CHANNEL FUNCTIONAL TEST. 24 rneRtRS -
| |
| SR 3.3.1.1.13 ---------------------------------NO TES------------------------
| |
| : 1. Neutron detectors are excluded.
| |
| : 2. For IRMs, not required to be perform ed when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2.
| |
| Perform CHANNEL CALIBRATION. 24 FR9RtRS ~
| |
| 1------...... SR 3.3.1.1.14 Verify the APRM Flow Biased Simulated T hermal 24 FR9RtRS
| |
| ~
| |
| Power-High time constant is within the lim its specified in the COLR.
| |
| <Delete line sp ace> ~(continued)
| |
| <Move two SR rows to next page>
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-5 Amendment No. 81 106 114, 168.
| |
| | |
| RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.3.1.1.15 Perform LOGIC SYSTEM FUNCTIONAL T EST. 24 FROAths ~
| |
| SR 3.3.1.1.16 Verify Turbine Stop Valve Closure and Tur bine 24 FROAths -
| |
| Control Valve Fast Closure Trip Oil Pressu re-Low Functions are not bypassed when THERMA L \
| |
| POWER is ~ 40% RTP.
| |
| SR 3.3.1.1.17 Calibrate the flow reference transmitters. 24 FR9Aths -
| |
| ~
| |
| SR 3.3.1.1.18 ---------------------------NOTES-------------------- ----------
| |
| : 1. Neutron detectors are excluded.
| |
| : 2. For Functions 3, 4, and 5 in Table 3.3 .1.1-1, the channel sensors are excluded.
| |
| : 3. FoF FuActioA 6, "A" equals 4 chaAAels feF the purpose of deterFRiAiAg the S+/\GGER ED
| |
| +ES+ BASIS FrequeAcy.
| |
| Verify the RPS RESPONSE TIME is within limits. 24 FR9Aths OA a --
| |
| S+,A,GGEREl.:;J
| |
| +ES+ BASIS
| |
| <Move SR row to new page 3.3-6a> ln accordance v1ith the Surveillance Frequency Control Program RIVER BEND 3.3-6 Amendment No. 81106 114,168,
| |
| | |
| SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS
| |
| --------------------------------------------------NOTE---------------------------------------------------------------
| |
| Refer to Table 3.3.1.2-1 to determine which SRs apply for each applicable MODE or other specified conditions.
| |
| SURVEILLANCE FREQUENCY SR 3.3.1.2.1 Perform CHANNEL CHECK. 12 hours""'~-----
| |
| SR 3.3.1.2.2 ---------------------------NOTES-----------------------------
| |
| : 1. Only required to be met during CORE ALTERATIONS.
| |
| : 2. One SRM may be used to satisfy more than one of the following.
| |
| Verify an OPERABLE SRM detector is located in: 12hours~
| |
| : a. The fueled region;
| |
| : b. The core quadrant where CORE ALTERATIONS are being performed when the associated SRM is included in the fueled region; and
| |
| : c. A core quadrant adjacent to where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region.
| |
| SR 3.3.1.2.3 Perform CHANNEL CHECK. 24 hours <I-""----*
| |
| (continued)
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-12 Amendment No. &+,
| |
| | |
| SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.3.1.2.4 ----------------------------NO TE------------------------------
| |
| * Not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant.
| |
| Verify count rate is: 12 hours during CORE
| |
| : a. 2 3.0 cps, or /\LTERATIOl'JS
| |
| : b. 2 0.7 cps with a signal to noise.ratio 2 2:1.
| |
| \
| |
| 24 hours SR 3.3.1.2.5 ---------------------------NOTE-------------------------------
| |
| N ot required to be performed until 12 hours after IRMs on Range 2 or below.
| |
| Perform CHANNEL FUNCTIONAL TEST. 31 days <1------1 SR 3.3.1.2.6 ------------------------NO TES--------------------------------
| |
| : 1. Neutron detectors are excluded.
| |
| : 2. Not required to be performed until 12 hours after IRMs on Range 2 or below.
| |
| Perform CHANNEL CALIBRATION. 24 months ---l RIVER BEND 3.3-13 Amendment No. 81, 168,
| |
| | |
| PBDS 3.3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.3.1 Verify each OPERABLE channel of PBDS ~2 R91:1FS, instrumentation not in Hi-Hi DR Alarm.
| |
| ~
| |
| SR 3.3.1.3.2 Perform CHANNEL CHECK. ~2 R91:1FS SR 3.3.1.3.3 Perform CHANNEL FUNCTIONAL TEST. 24 Ffl9AtRS ~
| |
| !n accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-14c Amendment No. 4-Ge,
| |
| | |
| Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS
| |
| ---------------------------------------------------NOTES----------------------------------------------------------------
| |
| : 1. Refer to Table 3.3.2.1-1 to determine which SRs apply for each Control Rod Block Function.
| |
| : 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains control rod block capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.2.1.1 --------------------------NOTE--------------------------------
| |
| Not required to be performed until 1 hour after THERMAL POWER is greater than the RWL high power setpoint (HPSP).
| |
| Perform CHANNEL FUNCTIONAL TEST. 92 Elays : : :
| |
| SR 3.3.2.1.2 --------------------------N OT E--------------------------------
| |
| N ot required to be performed until 1 hour after THERMAL POWER is > 35% RTP and less tha nor equal to the RWL HPSP. (
| |
| Perform CHANNEL FUNCTIONAL TEST. 92 Elays ~
| |
| SR 3.3.2.1.3 -----------------------------NOTE-----------------------------
| |
| N ot required to be performed until 1 hour after a ny control rod is withdrawn in MODE 2.
| |
| ~
| |
| Perform CHANNEL FUNCTIONAL TEST. 92 Elays (continued)
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-16 Amendment No. ~.
| |
| | |
| Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.3.2.1.4 --------.-------------------NOTE------------------------------
| |
| Not required to be performed until 1 hour after THERMAL POWER is ::s; 10% RTP in MODE 1.
| |
| Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.5 Calibrate the low power setpoint trip units. The 92 days Allowable Value shall be > 10% RTP and
| |
| ::s;35% RTP.
| |
| SR 3.3.2.1.6 Verify the RWL high power Function is not bypassed when THERMAL POWER is
| |
| > 68.2% RTP.
| |
| 1 SR 3.3.2.1.7 Perform CHANNEL CALIBRATION. 184 days SR 3.3.2.1.8 -----------*------------ -----NOTE----------------------------
| |
| Not required to be performed until 1 hour after reactor mode switch is in the shutdown position.
| |
| Perform CHANNEL FUNCTIONAL TEST. 24 months
| |
| * SR 3.3.2.1.9 Verify the* bypassing and movement of control rods - Prior to and during
| |
| , required to be bypassed in Rod Action Control the movement of System (RACS) is in conformance with applicable control rods analyses by a second licensed operator or other bypassed in qualified member of the technical staff. RACS line in with the RIVER BEND 3.3-17 Amendment No. 81 118, 168,
| |
| | |
| PAM Instrumentation 3.3.3.1 SURVEILLANCE REQUIREMENTS
| |
| ----------------------------------------------------------NOTE-----------------------------------------------------------
| |
| Th ese SRs apply to each FunGtion in Table 3.3.3.1-1.
| |
| SURVEILLANCE FREQUENCY SR 3.3.3.1.1 Perform CHANNEL CHECK. 31 days~,------.
| |
| SR 3.3.3.1.2 Deleted SR 3.3.3.1.3 Perform CHANNEL CALIBRATION. 24 months<::::*----.....
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-21 Amendment No. 81 142, 168,
| |
| | |
| Remote Shutdown System 3.3.3.2 3.3 INSTRUMENTATION 3.3.3.2 Remote Shutdown System LCO 3.3:3.2 The Remote Shutdown System Functions shall be OPERABLE.
| |
| APPLICABILITY: MODES 1 and 2.
| |
| ACTIONS
| |
| ----. -----------------------------------------------------NOTE---------------------------------------------------------- .
| |
| Separate Condition entry is allowed for each Function.
| |
| CONDITION REQUIRED ACTION COMPLETION TIME A.' One or more required A.1 Restore required Function 30 days Functions inoperable. to OPERABLE status.
| |
| B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.3.2.1 Perform CHANNEL CHECK for each requi red '31 days ::.
| |
| instrumentation channel that is normally en ergized.
| |
| (continued)
| |
| (
| |
| in accordance 'Nith the Surveiliance Frequency Control Program RIVER BEND 3.3,-23 Amendment No. 81, 156,
| |
| | |
| Remote Shutdown System 3.3.3.2 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY J
| |
| SR 3.3.3.2.2 Verify each required control circuit and transfer 24 FReRtRS switch is capable of performing the intended functions.
| |
| SR 3.3.3.2.3 Perform CHANNEL CALIBRATION for each 24 FR9RtRS ~
| |
| required instrumentation channel, except valve position instrumentation.
| |
| !n accordance with the Surveiiiance Frequency Control Program RIVER BEND 3.3-24 Amendment No. 81, 168,
| |
| | |
| EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS
| |
| ---------------------------------------------------NOTE------------------------------------------------------------------
| |
| Wh en a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains EOC-RPT trip capability.
| |
| SURVEILLANCE FREQUENCY
| |
| \
| |
| SR 3.3.4.1.1 Perform CHANNEL FUNCTIONAL TEST. 92 Ela ys, SR 3.3.4.1.2 Calibrate the trip units.
| |
| * 92 Elays :::.
| |
| SR 3.3.4.1.3 Perform CHANNEL CALIBRATION. The Allowab le 24 meRtl:is, Values shall be:
| |
| : a. TSV Closure: :s; 7% closed.
| |
| : b. TCV Fast Closure, Trip Oil Pressure -
| |
| Low: ~ 465 psig.
| |
| SR 3.3.4.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST, -"lA - ...
| |
| -~
| |
| . including breaker actuation.
| |
| SR 3.3.4.1.5 Verify TSV Closure and TCV Fast Closure, Trip O ii 24 rneRtR9'11 Pressure - Low Functions are not bypassed whe n THERMAL POWER is~ 40% RTP.
| |
| (continued)
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-27 Amendment No. 81, 168,
| |
| | |
| EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE fREQUENCY SR 3.3.4.1.6 ---------------------------N OT E-------------------------------
| |
| 8 re a ke r interruption time may be assumed from the most recent performance of SR 3.3.4.1. 7.
| |
| Verify the EOC-RPT SYSTEM RESPONSE TIME 24 months on a - -.....
| |
| is within limits. ST.i\GGERED TEST BASIS SR 3.3.4.1.7 Determine RPT breaker interruption time. 60 months""''----1 RIVER BEND 3.3-28 Amenpment No. 81, 168,
| |
| | |
| ATWS-RPT Instrumentation 3.3.4.2 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME B. One Function with B.1 Restore A TWS-RPT trip 72 hours A TWS-RPT trip capability capability.
| |
| not maintained.
| |
| C. Both Functions with C.1 Restore A TWS-RPT trip 1 hour A TWS-RPT trip capability capability for one Function.
| |
| not maintained. '
| |
| D. Required Action and D.1 Remove the associated 6 hours associated Completion recirculation pump from Time not met. service.
| |
| OR D.2 Be in MODE 2. 6 hours SURVEILLANCE REQUIREMENTS
| |
| -------------------------------------------------------NOTE-------------------------------------------------------------
| |
| When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains ATWS-RPT trip capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.4.2.1 Perform CHANNEL CHECK. ~2R9l:IFS~ /
| |
| (continued) ln accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-30 Amendment No. &+-,
| |
| | |
| ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE FREQUENCY SR 3.3.4.2.2 Perform CHANNEL FUNCTIONAL TEST.* 92 days...-------
| |
| SR 3.3.4.2.3 Calibrate the trip units. 92 days~:------*
| |
| SR 3.3.4.2.4 Perform CHANNEL CALIBRATION. The Allowable 24 months-__,.---1 Values shall be:
| |
| : a. Reactor Vessel Water Level-Low Low, Level 2: ~ -47 inches; and
| |
| : b. Reactor Steam Daine Pressure-High:
| |
| :::; 1165 psig.
| |
| SR 3.3.4.2.5 Perform LOGICSYSTEM FUNCTIONAL TEST, 24 months q - - - - - 1
| |
| * including breaker actuation.
| |
| ln accordance with the Frequency
| |
| \
| |
| RIVER BEND 3.3-31 Amendment No. 81 114, 168,
| |
| | |
| ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS
| |
| ------------------------------------------------------------NOTES-------------------------------- ----------------------
| |
| : 1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function.
| |
| * 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours for Functions 3.c, 3.f, 3.g, and 3.h; and (b) for up to 6 hours for Functions other than 3.c, 3.f, 3.g,* and 3.h, provided the associated Function or the redundant Function maintains ECCS initiation capability.
| |
| (
| |
| SURVEILLANCE FREQUENCY' SR 3.3.5.1.1 Perform CHANNEL CHECK. 12 R91:1FS ~
| |
| SR 3.3.5.1.2 Perform CHANNEL FUNCTIONAL TEST. 92 Elays c.::
| |
| SR 3.3.5.1.3 Calibrate the trip unit. 92 Elays, SR 3.3.5.1.4 Perform CHANNEL CALIBRATION. 92 Elays, SR 3.3.5.1.5 Perform 'CHANNEL CALIBRATION. 24 FF19Rti=ls "
| |
| A SR 3:3.5.1.6 Perform LOGIC SYSTEM FUNCTIONAL T EST. 24 FF!eRtRS '
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-38 Amendment No. 81, 168,
| |
| | |
| RCIC System Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS
| |
| ----------------------------------- .---------------NO TES---------------------------------------------------------------
| |
| : 1. Refer to Table 3.3.5.2-1 to determine which SRs apply for each RCIC Function.
| |
| : 2. ' When a channel is placed in an inoperable status .solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours for Functions 2 and 5; and (b) for up to 6 hours for Functions 1, 3, and 4 provided the associated Function maintains RCIC initiation capability,.
| |
| SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. i 12 hours SR 3.3.5.22 Perform CHANNEL FUNCTIONAL TEST. 92 days
| |
| . \
| |
| SR 3.3.5.2.3 Calibrate the trip units. 92 days SR 3.3.5:-2.4 Perform CHANNEL CALIBRATION. 24 months ----1 SR 3.3.5.2.5 Perform 1,..0GIC SYSTEM FUNCTIONAL JEST. 24 months In accordance with tl1e Surveiliance Frequency RIVER BEND 3.3-46 Am.endment No. 81, 168,
| |
| | |
| Primary Containment and Drywell Isolation l,nstrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS
| |
| ---------------------------------------------------NOTES------------------------------------------------------------
| |
| : 1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Function.
| |
| : 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains isolation capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK. 12 R9l::IFS ~
| |
| SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST. 92 ~ays '
| |
| SR 3.3.6.1.3 Calibrate the trip unit. 92 Elays .:::
| |
| SR 3.3.6.1.4 Perform CHANNEL CALIBRATION. 92 Elays SR 3.3.6.1.5 Perform CHANNEL CALIBRATION. 24 ffi9RtRS ~
| |
| ~
| |
| SR 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL T EST. 24 ffi8R{RS SR 3.3.6.1.7 -----------------------------NOTE-------------------- ---------
| |
| C ha n n e I sensors are excluded.
| |
| Verify the ISOLATION SYSTEM RESPONS ETIME 24 ffi8RtRS 9R a <l for the Main Steam Isolation Valves is with in limits. ~+AGGeReQ
| |
| +es+ BASIS
| |
| <Move SR row to new page 3.3-52a> in accorclance with the Surveillance Frequency Control Program RIVER BEND 3.3-52 Amendment No. 81, 168,
| |
| | |
| Secondary Containment and Fuel Building Isolation Instrumentation 3.3.6.2 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.1.2 Declare associated 1 hour isolation dampers inoperable.
| |
| C.2.1 Place the associated 1 hour ventilation subsystem in operation.
| |
| OR C.2.2 Declare associated 1 hour ventilation subsystem inoperable.
| |
| SURVEILLANCE REQUIREMENTS
| |
| -----------------------------------------------------NOTES------------------------------------------------------------
| |
| : 1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Isolation Function.
| |
| : 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains secondary containment isolation capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.6.2.1 Perform CHANNEL CHECK. 1~ R8b1FS ~
| |
| SR 3.3.6.2.2 Perform CHANNEL FUNCTIONAL TEST. 9.2 Elays ~
| |
| (continued)
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-59 Amendment No. 81, 113,
| |
| | |
| Secondary Containment and Fuel Building Isolation Instrumentation
| |
| ' 3.3.6.2 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.3.6.2.3 Calibrate the trip unit. 92: Elays j 2:4
| |
| ~
| |
| SR 3.3.6.2.4 Perform CHANNEL CALIBRATION. ffi9RtRS SR 3.3.6.2.5 Perform LOGIC SYSTEM FUNCTIONAL TE ST. 24 ffi9RtRS :::
| |
| \ In accordance with the Surveillance Frequency ~
| |
| Control Program RIVER BEND 3.3-60 Amendment No. 81113, 168,
| |
| | |
| Containment Unit Cooler System Instrumentation 3.3.6.3 SURVEILLANCE REQUIREMENTS
| |
| -------------------------------------------------------NOTES-----------------------------------------------------------
| |
| : 1. Refer to Table 3.3.6.3-1 to determine which SRs apply for each Containment Unit Cooler System Function.
| |
| : 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains containment unit cooler initiation capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.6.3.1 Perform CHANNEL CHECK. 24 R9l:IFS ~
| |
| SR 3.3.6.3.2 Perform CHANNEL FUNCTIONAL TEST. 92 Elays .::
| |
| SR 3.3.6.3.3 Calibrate the trip unit. 92 Elays.:::
| |
| SR 3.3.6.3.4 Perform CHANNEL CALIBRATION. 24 rneAtl=ls A SR 3.3.6.3.5
| |
| * Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 FH8AtRS ,:::
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-64 Amendment No. 81, 168,
| |
| | |
| Relief and LLS Instrumentation 3.3.6.4 SURVEILLANCE REQUIREMENTS
| |
| ------------------------------------------------------NOTE-------------------- .------------------------------------------
| |
| When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains LLS or relief initiation capability, as applicable.
| |
| SURVEILLANCE FREQUENCY SR 3.3.6.4.1 Perform CHANNEL FUNCTIONAL TEST. 92 Elays ~
| |
| SR 3.3.6.4.2 Calibrate the trip unit. 92 Elays ~
| |
| SR 3.3.6.4.3 Perform CHANNEL CALIBRATION. The Allowable 24 months Values shall be:
| |
| : a. Relief Function Low: 1133 +/- 15 p sig Medium: 1143 +/- 15 p sig High: 1153 +/- 15 psig
| |
| : b. LLS Function Low open: 1063 +/- 15 psig close: 956 +/- 15 psig Medium open: 1103 +/- 15 psig close: 966 +/- 15 psig High open: 1143 +/- 15 p sig close: 976 +/- 15 p sig SR 3.3.6.4.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months ~
| |
| In accordance with the Surveiilance Frequency Control Program RIVER BEND 3.3-67 Amendment No. 81114, 168,
| |
| | |
| CRFA System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS
| |
| ------------------------------------------------------N OTES-------------------------------------------------------------
| |
| : 1. Refer to Table 3.3.7.1-1 to determine which SRs apply for each Function.
| |
| : 2. *When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains CRFA initiation capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.7.1.1 Perform CHANNEL CHECK. ~2 A91:lFS '
| |
| SR 3.3.7.1.2 Perform CHANNEL FUNCTIONAL TEST. : 92 Elays *~
| |
| SR 3.3.7.1.3 Calibrate the trip units. 92 Elays ~
| |
| SR 3.3.7.1.4 Perform CHANNEL CALIBRATION. 24 meAtAS SR 3.3.7.1.5 Perform LOGIC SYSTEM FUNCTIONAL T EST. 24 meAtl=ls '
| |
| ln accordance vvith the Surveillance Frequency Control Program RIVER BEND 3.3-70 Amendment No. 81, 168,
| |
| | |
| LOP Instrumentation 3.3.8.1 SURVEILLANCE REQUIREMENTS
| |
| -------------------------------------------------- .------NO TES----------------------------------------------------------
| |
| : 1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function.
| |
| : 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 2 hours provided the associated Function maintains DG initiation capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.8.1.1 Perform CHANNEL CHECK.
| |
| SR 3.3.8.1.2 Perform CHANNEL FUNCTIONAL TEST. 31 days SR 3.3.8.1.3 Perform CHANNEL CALIBRATION. 24 months <!l------1 SR 3.3.8.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months -----i RIVER BEND 3.3-73 Amendment No. 81 168, 179,
| |
| | |
| RPS Electric Power Monitoring 3.3.8.2 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and - D.1 Initiate action to fully insert all Immediately associated Completion insertable control rods in core Time of Condition A or B cells containing one or more not met in MODE 4 or 5 fuel assemblies.
| |
| with any control rod withdrawn from a core cell containing one or more fuel assemblies.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.2.1 --------------------------NOTE-------------------------------
| |
| Only required to be performed prior to entering MODE 2 or 3 from MODE 4, when in MODE 4 for
| |
| ~ 24 hours.
| |
| Perform CHANNEL FUNCTIONAL TEST. 184 days i
| |
| ( continued) double with line>
| |
| Surveill.ance Control Program RIVER BEND 3.3-76 Amendment No. ~,
| |
| | |
| RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.3.8.2.2 Perform CHANNEL CALIBRATION. The Allowable 24 months Values shall be:
| |
| : a. Overvoltage Bus A:-::; 132 V Bus B :-::; 132 V
| |
| : b. Undervoltage Bus A;:::: 115 V Bus B;:::: 115 V C. Underfrequency (with time delay set to :-::; 4.0 seconds.)
| |
| Bus A::::: 57 Hz Bus B::::: 57 Hz SR 3.3.8.2.3 Perform a system functional test. 24 months RIVER BEND 3.3-77 Amendment No. 81, 168,
| |
| | |
| Recirculation Loops Operating 3.4.1 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME C. Requirements 8.3, 8.4, or C.1 Satisfy the requirements of 24 hours 8.5 of the LCO not met. the LCO.
| |
| D. Required actions and 0.1 Be in Mode 3. 12 hours associated completion
| |
| ~*
| |
| times of conditions A, B, or C not met.
| |
| OR No recirculation loops in operation.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 -----------------------------NOTE--------------------------------
| |
| Not required to be performed until 24 hours after both recirculation loops are in operation.
| |
| Verify recirculation loop jet pump flow mismatch with 24houra14:47, 13 May 2024 (EDT)-
| |
| both recirculation loops in operation is:
| |
| : a. :;; 10% of rated core flow when operating at
| |
| < 70% of rated core flow; and
| |
| : b. ::s; 5% of rated core flow when operating at
| |
| :::: 70% of rated core flow.
| |
| RIVER BEND 3.4-2 Amendment No. &1- 97 106,
| |
| | |
| FCVs 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 Flow Control Valves (FCVs)
| |
| LCO 3.4.2 A recirculation loop FCV shall be OPERABLE in each operating recirculation loop.
| |
| APPLICABILITY: MODES 1 and 2.
| |
| ACTIONS
| |
| ------------------------------------------------------NOTE--------------------------------------------------------------
| |
| Separate Condition entry is allowed for each FCV.
| |
| CONDITION REQUIRED ACTION COMPLETION TIME A. One or two required FCVs A.1 Lock up the FCV. 4 hours inoperable.
| |
| B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY
| |
| ~
| |
| SR 3.4.2.1 Verify each FCV fails "as is" on loss of hydraulic 24 Ff19Rths pressure at the hydraulic unit.
| |
| (continued)
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.4-6 Amendment No. 81, 168,
| |
| | |
| FCVs 3.4.2 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.4.2.2 Verify average rate of each FCV movement is: 24 months
| |
| : a. :s: 11 % of stroke per second for opening; and
| |
| : b. :s; 11 % of stroke per second for closing.
| |
| RIVER BEND 3.4-7 Amendment No. 81, 168,
| |
| | |
| Jet Pumps 3.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 ------------------------------NOTES-----------------------------
| |
| : 1. Not required to be performed until 4 hours after associated recirculation loop is in operation.
| |
| : 2. Not required to be performed until 24 hours after> 23.8% RTP.
| |
| Verify at least two of the following criteria 24 hours<f.-----~
| |
| (a, b, and c) are satisfied for each operating recirculation loop:
| |
| : a. Recirculation loop drive flow versus flow control valve position differs by :,;; 10% from established patterns.
| |
| : b. Recirculation loop drive flow versus total core flow differs by:,;; 10% from established patterns.
| |
| : c. Each jet pump diffuser to lower plenum differential pressure differs by:,;; 20% from established patterns, or each jet pump flow differs by:,;; 10% from established patterns.
| |
| in accordance vvith the Surveillance Frequency Controi Program RIVER BEND 3.4-9 Amendment No. a1, 114,
| |
| | |
| S/RVs 3.4.4 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.4.4.2 ------------------------------NOTE-------------------------------
| |
| Va Ive actuation may be excluded.
| |
| Verify each required relief function S/RV actuates on 24 months ~
| |
| an actual or simulated automatic initiation signal.
| |
| SR 3.4.4.3 ------------------------------NOTE-------------------------------
| |
| Not required to be performed until 12 hours ~fter reactor steam pressure and flow are adequate to perform the test.
| |
| Verify each required S/RV relief mode actuator In accordance with strokes when manually actuated. the lnservice Testing Program on a STAGGERED TEST BASIS for each valve solenoid RIVER BEND 3.4-11 Amendment No. 81 130, 168,
| |
| | |
| RCS Operational LEAKAGE 3.4.5 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time of Condition A or B AND not met.
| |
| C.2 Be in MODE 4. 36 hours Pressure boundary LEAKAGE exists.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify RCS unidentified LEAKAGE, total LEA KAGE, 12 hours*
| |
| and unidentified LEAKAGE increase are with in limits.
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.4-13 Amendment No. &:I-,
| |
| | |
| RCS Leakage Detection Instrumentation 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Perform CHANNEL CHECK of required drywe II ~~ R9HFS .;:
| |
| atmospheric monitoring system:
| |
| SR 3.4.7.2 Perform CHANNEL FUNCTIONAL TEST of re quired d1 Elays ~
| |
| leakage detection instrumentation.
| |
| SR 3.4.7.3 Perform CHANNEL CALIBRATION of require d -
| |
| '),I
| |
| - - - CL.
| |
| leakage detection instrumentation.
| |
| in accordance with the Survei!lancs Frequency Control Program RIVER BEND 3.4-19 Amendment No. 81, 168,
| |
| | |
| RCS Specific Activity 3.4.8
| |
| /
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 ----------------------------NOTE---------------------------------
| |
| 0 n ly required to be performed in MODE 1.
| |
| Verify reactor coolant DOSE EQUIVALENT 1-,131 7 days<<--------.
| |
| specific aqtivity is s 0.2 µCi/gm.
| |
| \
| |
| RIVER BEND 3.4-21 Amendment No. &:1-,
| |
| | |
| RHR Shutdown Cooling System - Hot Shutdown 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 ----------------------------NOTE---------------------------------
| |
| N ot required to be met until 2 hours after reactor steam dome pressure is less than the RHR cut in permissive pressure.
| |
| Verify one RHR shutdown cooling subsystem or 12 hours recirculation pump is operating.
| |
| SR 3.4.9.2 ----------------------------NOTE---------------------------------
| |
| N ot required to be performed until 12 hours after reactor steam dome pressure is less than the RHR cut in permissive pressure.
| |
| Verify RHR shutdown cooling subsystem locations 31 days susceptible to gas accumulation are sufficiently filled with water.
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.4-24 Amendment No. 81, 188,
| |
| | |
| RHR Shutdown Cooling System - Cold Shutdown 3.4.10 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPELETION TIME B. No RHR shutdown cooling B.1 Verify reactor coolant 1 hour from discovery subsystem in operation. circulating by an of no reactor coolant alternate method. circulation No recirculation pump in operation. Once per 12 hours thereafter B.2 Monitor reactor coolant Once per hour temperature and pressure.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify one RHR shutdown cooling subsystem or 12 hours recirculation pump is operating.
| |
| SR 3.4.10.2 Verify RHR shutdown cooling subsystem locations 31 days
| |
| ~usceptible to gas accumulation are sufficiently filled with water.
| |
| Control Program RIVER BEND 3.4-:_26 Amendment No. 81, 188,
| |
| | |
| RCS PIT Limits 3.4.11 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME C. -------------NOTE------------- . C.1 Initiate action to restore Immediately Required Action C.2 shall parameter(s) to within limits.
| |
| be completed if this Condition is entered.
| |
| (
| |
| ; C.2 Determine RCS is acceptable Prior to entering Requirements of the LCO for operation. MODE 2 or,3
| |
| , not met in other than MODES 1, 2, and 3.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 -----------------------------NOTE--------------------------------
| |
| 0 n ly required to be performed during RCS heatup and cooldown operations, and RCS inservice leak and hydrostatic testing.
| |
| Verify: ~30U-Am~inP.1u>-1-1t~ess:~ - - - - - ,
| |
| : a. RCS pressure and RCS temperature are within the limits of Figure 3.4.11-1, and b'. RCS heatup and cooldown rates are ::; 100°F in any one hour period for core not critical and core critical limits.
| |
| Ge. RCS heatup and cooldown rates are ::; 20°F in any one hour period for inservice leak and hydrostatic testing limits.
| |
| (continued)
| |
| In accordance Surveillance Frequency Control Program RIVER BEND 3.4-28 Amendment No. 81, 114,
| |
| | |
| RCS Prr Limits 3.4.'11 SUR\/EILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.4.11.5 ----------------------------NOTE---------------------------------
| |
| 0 nly required to be performed when tensioning the reactor vessel head bolting studs.
| |
| Verify reactor vessel flange and head flange 30 minutes 'Sr~------.
| |
| temperatures are::::: 70°F.
| |
| SR 3.4.11.6 ----------------------------NOTE--------------------------- *-----
| |
| Not required to be performed until 30 minutes after RCS temperature :,:; 80°F in MODE 4.
| |
| Verify reactor vessel flange and head flange 30 minutes~
| |
| temperatures are::::: 70°F.
| |
| SR 3.4.11.7 ----------------------------NOTE-------------- .------------------
| |
| Not required to be performed until 12 hours after RCS temperature:,:; 100°F in MODE 4.
| |
| Verify reactor vessel flange and head flange 12 hours temperatures are::::: 70°F.
| |
| (continued) in accordance with the Surveillance Frequency Control Program RIVER BEND 3.4-30 Amendment No. &1--,
| |
| | |
| Reactor Steam Dome Pressure 3.4.12 3.4 REA.CTOR COOLANT SYSTEM (RCS) 3.4.12 Reactor Steam Dome Pressure LCO 3.4.12 The reactor steam dome pressure shall be:,;; 1075 psig.
| |
| APPLICABILITY: MODES 1 and 2.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor steam dome A.1 Restore reactor steam dome 15 minutes pressure not within limit. pressure to within limit.
| |
| B. Required Action anq B.1 Be in MODE 3. 12 hours associated Completion Time not met.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify reactor steam dome pressure is :,;; 1075 p sig. 1~ A8l::lFS.::
| |
| In accordance with the Surveillance Frequency Controi Program RIVER BEND 3.4-33 Amendment No. 81, 114,
| |
| | |
| ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.11 Verify, for each ECCS injection/spray subsystem, 31 days~--------.
| |
| locations susceptible to gas accumulation are sufficiently filled with water.
| |
| SR 3.5.1.2 -----------------------------NOTES--------------------------------
| |
| : 1. Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the residual heat
| |
| <Add iine space> removal cut in permissive pressure in MODE 3, if
| |
| ~
| |
| capable of being manually realigned and not otherwise inoperable.
| |
| : 2. Not required to be met for system vent flow paths Frequency opened under administrative control.
| |
| with text> --..::;--:;;:-:;;:--::.::--=--=--=--=--=-=--=--=--=--=--=--=--=-=--=--=--::::--:.::_--:.::_--:.::_--=-=--.=--.=--::::--=--:....--::::-::::--:=--:_::--:_::--:_::***=*--~
| |
| Verify each ECCS injection/spray subsystem manual, A3.:i.1+1d1.::1aJJ.:ys~<1-------1 power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.
| |
| SR 3.5.1.3 Verify ADS accumulator supply pressure is 31 days
| |
| ;::: 131 psig.
| |
| SR 3.5.1.4 Verify each ECCS pump develops the specified flow In accordance with rate with the specified pump differential pressure. the lnservice Testing Program PUMP DIFFERENTIAL SYSTEM FLOW RATE PRESSURE LPC~ ;::: 5010 gpm ;::: 282 psid LPCI ;::: 5050 gpm ;::: 102 psid HPCS ;::: 5010 gpm ;::: 415 psid (continued)
| |
| RIVER BEND 3.5-4 Amendment No. 81, 188,
| |
| | |
| ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS continued)
| |
| SURVEILLANCE FREQUENCY SR 3.5.1.5 -----------------------------N.OTE--------------------------------
| |
| Vessel injection/spray may be excluded.
| |
| Verify each ECCS injection/spray subsystem actuates 24 months~-:-------.
| |
| on an actual or simulated automatic initiation signal.
| |
| SR 3.5.1.6 -------------------------------NOTE------------------------------
| |
| Va Ive actuation may be excluded.
| |
| Verify the ADS actuates on an actual or simulated automatic initiation signal.
| |
| SR 3.5.1.7 ------------------------------NOTE-------------------------------
| |
| N ot required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test.
| |
| Verify each ADS valve relief mode actuator strokes In accordance.with when manually actuated. the Inservice Testing Program on a STAGGERED TEST BASIS for each valve solenoid SR 3.5.1.8 --------- *---------------------NOTE------------------------------
| |
| EC CS actuation instrumentation is excluded.
| |
| Verify the ECCS RESPONSE TIME for each ECCS injection/spray subsystem is within limits.
| |
| In accordance the Surveiilance Frequency
| |
| <Move SR royv to new page 3.5-5a>
| |
| Control Program 3.5-5 Amendment No, 81 130, 168,
| |
| | |
| ECCS- Shutdown 3.5.2 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action C.2 and D.1 Initiate action to restore Immediately associated Completion primary containment to Time not met. OPERABLE status.
| |
| D.2 Initiate action to isolate Immediately required primary containment penetration flow paths.
| |
| AND D.3 ------------NOTE-----------
| |
| Entry and exit is permissible under administrative control.,
| |
| Initiate action to close Immediately one door in each primary containment air lock.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify, for each required low pressure Eccs*
| |
| injection/spray subsystem, the suppression pool water level is 2 13 ft 3 inches.
| |
| (continued)
| |
| In accordance the Surveiilance Frequency Controi Program RIVER BEND 3.5-7 Amendment No. &+,
| |
| | |
| ECCS- Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.5.2.2 Verify, for the required High Pressure Core Spray 12 hours <II:"----~
| |
| (HPCS) System, the:
| |
| : a. Suppression pool water level is ~ 13 ft 3 inches; or
| |
| : b. Condensate storage tank water level is ~ 11 ft 1 inch.
| |
| SR 3.5.2.3 Verify, for each required ECCS injection/spray 63+1-fdiaawyss<r-----1 subsystem, locations susceptible to gas accumulation are sufficiently filled with water.
| |
| SR 3.5.2.4 -------------------------------NOTES------------------------------
| |
| : 1. One low pressure coolant injection (LPCI) subsystem may be considered OPERABLE during 1
| |
| soace> alignment and operation for decay heat
| |
| *~ removal, if capable of being manually realigned and not otherwise inoperable.
| |
| : 2. Not required to be met for system vent flow paths opened under administrative control.
| |
| 31 days Verify each required ECCS injectionispray subsyste~
| |
| manual, power operated, and automatic valve int cf*
| |
| flow path, that is not locked, sealed, or otherwi secured in position, is in the correct position (continued)
| |
| <Align Frequency SR text>
| |
| In Surveillance Frequency Control Program
| |
| ('
| |
| RIVER BEND 3.5-8 Amendment No. 81, 188,
| |
| | |
| ECCS- Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify each required ECCS pump develops the In accordance with specified flow rate with the specified pump differential the lnservice pressure. Testing Program PUMP DIFFERENTIAL SYSTEM FLOW RATE PRESSURE LPCS ;::,: 5010 gpm 2 282 psid LPCI 2 5050 gpm 2 102 psid HPCS 2 5010 gpm ;::,: 415 psid SR 3.5.2.6 -----------------------------NOTE--------------------------------
| |
| Ves se I injection/spray may be excluded.
| |
| Verify each required ECCS injection/spray subsystem 24 months~----.....,
| |
| actuates on an actual or simulated automatic initiation signal.
| |
| RIVER BEND 3.5-9 Amendment No. 81, 168,
| |
| | |
| RCIC System*
| |
| 3.5.3 SURVEILLANCE REQUIREMENTS I SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify *the RCIC System locations susceptible to gas. 31 days accumulation are sufficiently filled with water.
| |
| SR 3.5.3.2 -----------------------------NOTE--------------------------------
| |
| Not required to be met for system vent flow paths opened under administrative control.
| |
| Verify each RCIC System manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.
| |
| SR 3.5.3.3 -----------------------------NOTE---- .---------------------------
| |
| Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test.
| |
| Verify, with RCIC steam supply pressure ::s; 1075 psig ~92;;24d~a)\/.$'S~~*- - - - - i and;::,: 920 psig, the RCIC pump can develop a flow rate ;::,: 600 gpm against a system head corresponding to reactor pressure.
| |
| SR 3.5.3.4 -----------------------------NO TE---. -----. ----------------------
| |
| Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test.
| |
| Verify, with RCIC steam supply pressure ::s; 165 psig 24 monthS"'Ji-----1 and ;::,: 150 psig, the RCIC pump can develop a flow rate ;::,: 600 gpm against a system head corresponding
| |
| \
| |
| to reactor pressure.
| |
| (continued)
| |
| In accordance the Surveillance Frequency Control Program RIVER BEND 3.5-11 Amendment No. 81114168, 188,
| |
| | |
| RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.5.3.5 ------------------------------NOTE-------------------------------
| |
| Vessel injection may be excluded.
| |
| * Verify the RCIC System actuates on an actual or 24 months--------.
| |
| simulated automatic initiation signal.
| |
| RIVER BEND 3.5-12 Amendment No. 81, 168,
| |
| | |
| Primary Containment Air Locks 3.6.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.2.1 --------------------------NOTES-----------------------------
| |
| : 1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.
| |
| : 2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.1.
| |
| Perform required primary containment air lock leakage rate testing in accordance with the Primary In accordance with Containment Leaka~e Rate Testing Program. the Primary Containment Leakage Rate-Testing Program SR 3.6.1.2.2 Verify primary containment air lock seal 7 days~
| |
| air flask pressure is ~ 90 psig.
| |
| I SR 3.6.1.2.3 ----------------------------NOTE-----------------------------
| |
| 0 nIy required to be performed upon entry or exit through the primary containment air lock.
| |
| Verify only one door in the primary containment air 184 days4i------1 lock can be opened at a time.
| |
| (continued)
| |
| !n accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-7 Amendment No. 81 84, 132,
| |
| | |
| Primary Containment Air Locks 3.6.1.2 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE . FREQUENCY
| |
| ,SR 3.6.1.2.4 Verify, from an initial pressure of 24 months----~
| |
| 90 psig, the primary containment air lock seal pneumatic system pressure does not decay at a rate equivalent to
| |
| > 1.50 psig for a period of 24 hours.
| |
| <Change to double lino> / ' in accordance Survell!ance Program RIVER BEND 3.6-8 Amendment No. 81 1J2, 168,
| |
| | |
| PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.1 --------------------------N OTES-----------------------------
| |
| : 1. Only required to be met in MODES 1, 2, and 3.
| |
| : 2. Not required to be met when the 36 inch primary containment purge valves are open for pressure control, ALARA or air quality considerations for personnel entry. Also, not required to be met during Surveillances, or special testing on the purge system that requires the valves to be open,
| |
| : 3. If one Standby Gas Treatment (SGT) subsystem is in the primary containment purge flow path, both SGT subsystems must be OPERABLE. In addition only one SGT subsystem may be operating in the primary containment purge flow path.
| |
| Verify each 36 inch primary containment pu rge ays -
| |
| valve is closed.
| |
| (continued)
| |
| !n accordance with the Sun.1eillance Frequency Control Program RIVER BEND 3.6-15 Amendment No. &'.I-,
| |
| | |
| PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.1.3.2 ----------------------------NOTES---------------------------
| |
| : 1. Only required to be met in, MODES 1, 2, and 3.
| |
| : 2. Valves and blind flanges in high radiation areas may be verified by use of administrative means.
| |
| : 3. Not required to be met for PCIVs that are open under administrative controls.
| |
| Verify each primary containment isolation manual 31 days-----~
| |
| valve and blind flange that is located outside primary containment, drywell, and steam tunnel and is required to be closed during accident conditions is closed.
| |
| \
| |
| (continued)
| |
| \
| |
| RIVER BEND 3.6-16 Amendment No'. 81, 116,
| |
| | |
| PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.1.3.4 Verify the isolation time of each power operated In accordance and each automatic PCIV, except MSIVs, is within with the lnservice limits. - Testing Program SR 3.6.1.3.5 ----------------------------NOTE-----------------------------
| |
| 0 n ly required to be met in MODES 1, 2, and 3.
| |
| -Perform leakage rate testing for each primary In accordance with containment purge valve with resilient seals. the Primary Containment Leakage Rate Testing Program SR 3.6.1.3.6 Verify the isolation time of each MSIV is In accordance with the lnservice
| |
| ::::: 3 seconds and ::::; 5 seconds. Testing Program SR 3.6.1.3.7 Verify each automatic PCIV actuates to the 24 months+--:-----.
| |
| isolation position on an actual or simulated isolation
| |
| \. signal.
| |
| (continued)
| |
| In accordance with the Surveillance Frequency Control Program
| |
| \
| |
| RIVER BEND 3.6-17 Amendment No. 81 152, 168,
| |
| | |
| PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.1.3.8 Verify in-leakage rate of :s; 340 scfh for each of the 24 months...-~----~
| |
| following valve groups when tested at 11.5 psid for MS-PLCS valves.
| |
| : a. Division I MS-PLCS valves
| |
| : b. Division II MS-PLCS valves SR 3.6.1.3.9 ----------------------------NOTE-----------------------------
| |
| Only required to be met in 'MODES 1, 2, and 3.
| |
| Verify the combined leakage rate for all secondary In accordance with containment bypass leakage paths is :s; 580,000 the Primary cc/hr when pressurized to::?: Pa. Containment Leakage Rate Testing Program (continued)
| |
| In accordance the Surveillance Frequency Control Program RIVER BEND 3.6-18 Amendment No. 81 84 98 132, 168,
| |
| | |
| Primary Containment Pressure
| |
| . 3.6.1.4 3.6 CONTAINMENT SYSTEMS 3.6.1.4 Primary Containment Pressure LCO 3.6.1.4 Primary containment pressure shall be~ -0.3 psig and ::; 0.3 psig.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore primary 1 hour pressure not within limits. containment pressure to within limits.
| |
| B. Required Action and 8.1 Be in MODE 3. 12 hours associated Completion Time not met. AND 8.2 Be in MODE4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.4.1 Verify primary containment pressure is with in limits. ~2 R91;1FS ~
| |
| In accordance with the Surveillance Frequency Control r:irogram RIVER BEND 3.6-21 Amendment No. &::I-,
| |
| | |
| Primary Containment Air Temperature 3.6.1.5 3.6 CONTAINMENT SYSTEMS 3.6.1.5 Primary Containment Air Temperature LCO 3.6.1.5 Primary containment average air temperature shall be:-:::; 90°F.
| |
| APPLICABILITY: MODES 1, 2, and 3.'
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore primary 8 hours average air temperature containment average air not within limit. temperature to within limit.
| |
| B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.5.1 Verify primary containment average air temperature 24 hours----~
| |
| is within limit.
| |
| RIVER BEND 3.6-22 Amendment No. 84,
| |
| | |
| LLS Valves 3.6.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.6.1 ---------------------------NOTE---- , ------------------------
| |
| Not required to fie performed until 12 hours after reactor steam pressure and flow are adequate to perform the test.
| |
| Verify each LLS valve relief mode actuator strokes In accordance with when manually actuated. the lnservice Testing Program on a STAGGERED TEST BASIS for each valve solenoid SR 3.6.1.6.2 ----------------------------NOTE-----------------------------
| |
| Va Ive actuation may be excluded.
| |
| Verify the LLS System actuates on an actual or
| |
| * 24 months~
| |
| simulated automatic initiation signal.
| |
| In accordance with tile Surveillance Frequency Control Program RIVER BEND 3.6-24 Amendment No. 81 130, 168,
| |
| | |
| Primary Containment Unit Coolers 3.6.1.7 SURVEILLANCE REQUIREMENTS
| |
| /,
| |
| SURVEILLANCE FREQUENCY SR 3.6.1.7.1 Verify each required primary containment un it 31 days ~
| |
| cooler pressure relief and backdraft damper in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position.
| |
| SR 3.6.1.7.2 Verify each required primary containment un it 92 days~
| |
| cooler develops a flow rate of :2:: 50,000 cfm on recirculation flow through the unit cooler.
| |
| SR 3.6.1.7.3 Verify each required primary containment un it 24 FA8RtAS ,
| |
| cooler actuates throughout its emergency op erating sequence on an actual or simulated automatic initiation signal.
| |
| ln accordance with tt'le Surveii!ance Frequency Control Program RIVER BEND 3.6-26 Amendment No. 81, 168,
| |
| | |
| MS-PLCS 3.6.1.9 3.6 CONTAINMENT SYSTEMS 3.6.1.9 Main Steam-Positive Leakage Control System (MS-PLCS)
| |
| LCO 3.6.1.9 Two MS-PLCS subsystems shall be OPERABLE.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One MS-PLCS subsystem A.1 Restore MS-PLCS 30 days inoperable. subsystem to OPERABLE status.
| |
| B. Two MS-PLCS B.1 Restore one MS-PLCS 7 days subsystems inoperable. subsystem to I
| |
| OPERABLE status.
| |
| C. Required Action and C.1 ----------NOTE--.--------
| |
| associated Completion LCO 3.0.4.a is not Time not met. applicable when entering MODE 3.
| |
| Be in MODE 3. 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE *FREQUENCY SR 3.6.1.9.1 Verify air pressure in each associ ~ted PVLCS 24 R91::lFS ~
| |
| subsystem is~ 101 psig.
| |
| (continued)
| |
| In accordancewith the Sur.1eiilance Frequency Control Program RIVER BEND 3.6-29 Amendment No. 81 185,
| |
| | |
| MS-PLCS 3.6.1.9 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.6.1.9.2 Operate each PVLCS compressor~ 15 min utes. ays J SR 3.6.1.9.3 Perform a system functional test of each MS -PLCS ~4 A=18AtAS ~
| |
| subsystem.
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-30 Amendment No. 81, 168;
| |
| | |
| Primary Containment-Shutdown 3.6.1.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.10.1 ---------------------------N OT E------------------------------
| |
| N ot required to be met for vent and drain line pathways provided the total calculated flow rate through open vent and drain pathways is :s; 70.2 cfm.
| |
| Verify each penetration flow path, required to be 31 days-----~
| |
| closed during accident conditions, is closed.
| |
| ln accordance with the Surveillance Frequency Control Program
| |
| .I RIVER BEND 3.6-32 Amendment No. &1-,
| |
| | |
| Suppression Pool Average Temperature 3.6.2.1*
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1.1 Verify suppression pool average temperature is 24 *hours:.::.
| |
| within the applicable limits.
| |
| AND 5 minutes when performing testing that adds heat to the suppression pool In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-35 Amendment No. &:I-,
| |
| | |
| Suppression Pool Water Level 3.6.2.2 3.6 CONTAINMENT SYSTEMS 3.6.2.2 Suppression Pool Water Level LCO 3.6.2.2 Suppression pool water level shall be ~ 19 ft 6 inches and ~ 20 ft O inches.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS I CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool water A.1 Restore suppression 2 hours level not within limits. pool water level to within limits.
| |
| : 8. Required Action and 8.1 Be in MODE 3. 12 hours associated Completion Time not met. .AND 8.2 Be in MODE4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.2.1 Verify suppression pool water level is within limits. 24 A9!:lFS ~
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-36 Amendment No. 84,
| |
| | |
| RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling 31 days, subsystem manual, power operated, and auto matic valve in the flow path that is not locked, sealed , or otherwise secured in position is in the correct position or can be aligned to the correct positi on.
| |
| Verify RHR suppression pool cooling subsyste m
| |
| ' 31 Elays
| |
| * SR 3.6.2.3.2 locations susceptible to gas accumulation are sufficiently filled with water.
| |
| SR 3.6.2.3.3 Verify each RHR pump develops a flow rate In accordance
| |
| ::::: 5050 gpm through the associated heat with the lnservice exchangers to the suppression pool. Testing Program in accordance 1.AJith the Surveillance Frequency Control Program .
| |
| RIVER BEND 3.6-38 Amendment No. 81, 188,
| |
| | |
| Primary Containment and Drywell Hydrogen lgniters 3.6.3.2 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time not met.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.2.1 Energize each primary containment and drywell 184 days -
| |
| hydrogen igniter division and perform curren t versus voltage measurements to verify requ ired igniters in service.
| |
| SR 3.6.3.2.2 -----------------------NOTE--------------------------- -------
| |
| Not required to be performed until 92 days after discovery of four or more igniters in the divis ion inoperable.
| |
| Energize each primary containment and drywell 92 days-::
| |
| hydrogen igniter division and perform curren t versus voltage measurements to verify requ ired igniters in service.
| |
| SR 3.6.3.2.3 Verify each required igniter in inaccessible a reas 24 Ffl9AtAS develops sufficient current draw for a ~ 1700°F surface temperature.
| |
| (continued)
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-42 Amendment No. 81, 168,
| |
| | |
| Primary Containment and Drywell Hydrogen lgniters 3.6.3.2 SURVEILLANCE REQUIREMENTS (continued SURVEILLANCE FREQUENCY SR 3.6.3.2.4 Verify each required igniter in accessible areas 24 months , q , . ~ - - - - - - - - ,
| |
| develops a surface temperature of;:::: 1700°F.
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-43 Amendment No. 81, 168,
| |
| | |
| Primary Containment/Drywell Hydrogen Mixing System 3.6.3.3 ACTIONS (continued)
| |
| COND.ITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be'in MODE 3. 12 hours associated Completion Time not met.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.3.1 Operate each primary containment/drywell Every COLD hydrogen mixing subsystem for~ 15 minutes. SHUTDOWN, if not performed within the previous 92 days.
| |
| SR 3.6.3.3.2 Verify each primary containment/drywell hydrogen 24 months, mixing subsystem flow rate is ~ 600 cfm.
| |
| In accordance with tile Surveillance Frequency Control Program RIVER BEND 3.6-45 Amendment No. 81 8Q, 168,
| |
| | |
| Secondary Containment-a perating
| |
| ~.6.4.1 3.6 CONTAINMENT SYSTEMS
| |
| . 3.6.4.1 Secondary Containment-Operating LCO 3.6.4.1 The shield building and auxiliary building shall be OPERABLE.
| |
| APPLIOABILITY: MODES 1, 2, and 3.
| |
| \
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore 'secondary 4 hours inoperable. containment to OPERABLE status.
| |
| B. Required Action and B.1 ----------NO TE-----------
| |
| associated Completion LCO 3.0.4.a is not Time not met. applicable when entering MODE 3.
| |
| Be in MODE 3. 12 hours \
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY
| |
| ~
| |
| SR 3.6.4.1.1 Verify shield building annulus and auxiliary b uilding 24 hours vacuum is;::,: 3.0 and;::,: 0.0 inch of vacuum wa ter gauge, respectively.
| |
| (continued)
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-46 Amendment No. 84, 113, 185,
| |
| | |
| Secondary Containment-Operating 3.6.4.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.4.1'.2 Verify all secondary containment equipment 31 days ,
| |
| hatches are closed and sealed and loop sea Is filled.
| |
| SR 3.6.4.1.3 Verify each secondary containment access d oar is 31 days :::
| |
| closed, except when the access opening is b eing used for entry and exit.
| |
| SR 3.6.4.1.4 Verify each standby gas treatment (SGT) 24 ffieRtl:!s eR -
| |
| subsystem will draw down the shield building a S+AGGeReQ annulus and auxiliary building to 2 0.5 and +ea+ 13ASIS 2 0.25 inch of vacuum water gauge in :,; 18.5 and
| |
| :,; 34.5 seconds, respectively.
| |
| SR 3.6.4.1.5 Deleted Not Applicable
| |
| <.Add a line space to 2iign with SR text>
| |
| SR 3.6.4.1.6 Verify each SGT subsystem can maintain 2 0 .5 and
| |
| "" ~
| |
| 24 ffieRtl:!s en a ~
| |
| S+AGGeReQ 2 0.25 inch of vacuum water gauge in the sh ield +eS+ 13ASIS building annulus and auxiliary building, respectively, for 1 hour.
| |
| SR 3.6.4 .1.7 Qeleted Net A1313lieasle
| |
| ~=========
| |
| <Delete SR rovv>
| |
| in accordance INith the Surveillance Frequency Control Program
| |
| , RIVER BEND 3.6-47 Amendment No. 81 95 113 132, 168,
| |
| | |
| SCI Os/FBI Os 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.2.1 Verify the isolation time of each required power 92 days ~ - - - - - - .
| |
| operated automatic SCIO and FBIO is within limits.
| |
| SR 3.6.4.2.2 Verify each required automatic SCIO and FBIO 24 months-----1 actuates to the isolation position on an actual or simulated automatic isolation signal.
| |
| !n accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-50 Amendment No. 81 95 113, 168,
| |
| | |
| SGT System 3.6.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT subsystem for :?: 10 continu OLIS ays:
| |
| hours with heaters operating.
| |
| SR 3.6.4.3.2 Perform required SGT filter testing in accordan ce In accordance with with the Ventilation Filter Testing Program (VF TP). the VFTP
| |
| ~
| |
| SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual 24 R'l9RtAS or simulated initiation signal.
| |
| SR 3.6.4.3.4 Verify each SGT filter cooling bypass ~4 R'l9RtAS C:::
| |
| damper can be opened and the fan started.
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-52 Amendment No. 81, 168,
| |
| | |
| Fuel Building 3.6.4.5 3.6 CONTAINMENT SYSTEMS I
| |
| 3.6.4.5 Fuel Building LCO 3.6.4.5 The fuel building shall be OPERABLE.
| |
| APPLICABILITY: During movement of recently irradiated fuel assemblies in the fuel building.
| |
| ACTIONS
| |
| ------------------------------------------------------NOTE--------------------------------------------------------------
| |
| LCO 3.0.3 is not applicable.
| |
| CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel building inoperable. A.1 Suspend movement of Immediately recently irradiated fuel assemblies in the fuel building.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.5.1 Verify fuel building vacuum is ::::: 0.25 2:4 R8l:IFS ,
| |
| inch of vacuum water gauge.
| |
| SR 3.6.4.5.2 Verify all fuel building equipment hatch cove rs are d1 Elays ~
| |
| installed.
| |
| SR 3.6.4.5.3 Verify each fuel building access door is clos ed, d1 Elays" except when the access opening is being us ed for entry and exit.
| |
| ln accordance vvith the Surveillance Frequency Control Program RIVER BEND 3.6-55 Amendment No. 81 95, 11 d,
| |
| | |
| Fuel Building Ventilation System-Fuel Handling 3.6.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.7.1 Verify one fuel building ventilation charcoal fi ltration 12R9l::IFS.:'.
| |
| subsystem in operation.
| |
| SR 3.6.4.7.2 Operate each fuel building ventilation charco al 31 days ~
| |
| filtration subsystem for ~ 10 continuous hours with heaters operating.
| |
| SR 3.6.4.7.3 Perform fuel building ventilation charcoal filtra tion In accordance with filter testing in accordance with the Ventilatio n Filter the VFTP Testing Program (VFTP).
| |
| ~
| |
| SR 3.6.4.7.4 Verify each fuel building ventilation charcoal 24 FH9RtRS filtration subsystem actuates on an actual or simulated initiation signal.
| |
| SR 3.6.4.7.5 Verify each fuel building ventilation charcoal 24 FH9Rths C:::
| |
| filtration filter cooling bypass damper can be opened and the fan started. C
| |
| !n accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-59 Amendment No. 81, 168,
| |
| | |
| Drywell 3.6.5.1 3.6 CONTAINMENT SYSTEMS 3.6.5.1 Drywell LCO 3.6.5.1 The drywell shall be OPERABLE.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell inoperable. A.1 Restore drywell to 1 hour OPERABLE status.
| |
| : 8. Required Action and 8.1 Be in MODE 3. 12 hours associated Completion Time not met. AND 8.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS
| |
| (
| |
| SURVEILLANCE FREQUENCY SR 3.6.5.1.1 Verify personnel door inflatable seal air flask +Elays ,
| |
| pressure ~ 75 psig.
| |
| SR 3.6.5.1.2 Verify from an initial pressure of 75 psig, -the 24 months::::
| |
| personnel door inflatable seal pneumatic system pressure does not decay at a rate equival~nt to
| |
| ~ 20.0 psig for a period of 24 hours. \
| |
| (continued) ln accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-60 Amendment No. 81 132, 168,
| |
| | |
| Drywell 3.6.5.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.5.1.3 Verify bypass leakage is less than or equal to the --------NO TE-------
| |
| bypass leakage limit. S R 3.0.2 is not applicable for However, during the first unit startup following extensions > 9 bypass leakage testing performed in accordance months with this SR, the acceptance criterion is :,; 10% of the drywell bypass leakage limit.
| |
| 24 months following 2 consecutive tests with bypass leakage greater than the bypass leakage limit until 2 consecutive tests are less than or equal to the bypass leakage limit 48 months following a test with bypass leakage greater than the bypass leakage limit 180 months-------,
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-61 Amendment No. 81 87144, 191,
| |
| | |
| Drywell 3.6.5.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.5.1.4 Visually inspect the exposed accessible interior and Once prior to exterior surfaces of the drywell. performance of each Type A test required by SR 3.6.1.1.1 SR 3.6.5.1.5 Verify seal leakage rate when the gap between the door Once within 72 seals is pressurized to~ 3 psid. hours after each drywell air lock door closing SR 3.6.5.1.6 Verify drywell air lock leakage by performing an air lock 24 months~:::---......
| |
| barrel leakage test at~ 3 psid.
| |
| In accordance vvith the Surveillance Frequency Control Program RIVER BEND 3.6-62 Amendment No.~,
| |
| | |
| Drywell Air Lock 3.6.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.2.1 Deleted SR 3.6.5.2.2 Verify drywell air lock seal air flask pressure is 7 Elays ~
| |
| ?. 75 psig.
| |
| SR 3.6.5.2.3 -----* ---------------------NOTE------------------------------
| |
| Only required to be performed upon entry into drywelL Verify only one door in the drywell air lock ca n be 24 months c:::
| |
| opened at a time.
| |
| SR 3.6.5.2.4 Deleted I,
| |
| SR 3.6.5.2.5 Verify, from an initial pressure of 75 psig, the 24 months~
| |
| drywell air lock seal pneumatic system press ure does not decay at a rate equivalent to > 20.0 psig for a period of 24 hours.
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-66 Amendment No. 81 87 132, 168,
| |
| | |
| Drywell Isolation Valves 3.6.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.3.1 Verify each 24 inch drywell purge isolation va Ive is d~ says '
| |
| sealed closed.
| |
| SR 3.6.5.3.2 --------------------------NOTE-------------------------------
| |
| N ot required to be met when the primary containment/drywell hydrogen mixing inlet or o utlet valves are open for pressure control.
| |
| * Verify each primary containment/drywell hydro gen d~ says ~
| |
| mixing isolation valve is closed.
| |
| SR 3.6.5.3.3 ---------------------------NOTES---------------------------- '
| |
| : 1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. C
| |
| : 2. Not required to be met for drywell isolatio n valves that are open under administrative controls.
| |
| Verify each drywell isolation manual valve and blind Prior to entering flange that is required to be closed during ace ident MODE 2 or 3 from conditions is closed. MODE 4, if not performed in the previous 92 days (continued)
| |
| !n accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-69 Amendment No. ~ ,
| |
| | |
| .Drywell Isolation Valves 3.6.5.3 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.5.3.4 Verify the isolation time of each power operated In accordance and each automatic drywell isolation valve is within with the lnservice limits. Testing Program SR 3.6.5.3.5 Verify each automatic drywell isolation valve 24 months J actuates to the isolation position on an actu al or simulated isolation signal.
| |
| SR 3.6.5.3.6 Verify the cumulative time that the primary 31 days ~
| |
| containment/drywell hydrogen mixing inlet o r outlet penetrations are open to be :.:; 5 hours per 365 days in Modes 1 and 2, and :.:; 90 hours per 365 d aysin Mode 3.
| |
| I In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-70 Amendment No. 81 89, 168,
| |
| | |
| Drywell Pressure 3.6.5.4 3.6 CONTAINMENT SYSTEMS 3.6.5.4 Drywell Pressure LCO 3.6.5.4 Drywell-to-primary containment differential pressure shall be :2: -0.3 psid and :-: :; 1.2 psid.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A Drywell-to-primary A.1
| |
| * Restore drywell-to- 1 hour containment differential primary containment pressure not within limits. differential pressure to within limits.
| |
| B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met. AND B.2 Be in MODE4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.4.1 Verify drywell-to-primary containment differe ntial ~2 A9~FS pressure is within limits.
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-71 Amendment No. &:I-,
| |
| | |
| Drywell Air Temperature 3.6.5.5 3.6 CONTAINMENT SYSTEMS 3.6.5.5 Drywell Air Temperature LCO 3.6.5.5 Drywell average air temperature shall be:,; 145°F.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell average air A.1 Restore drywell average 8 hours temperature not within air temperature to within limit. limit.
| |
| B. Required Action and 8.1. Be in MODE 3. 12 hours associated Completion Time not met. AND 8.2 Be in MODE4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY
| |
| ~
| |
| SR 3.6.5.5.1 Verify drywell average air temperature is with in 24 A9t1FS limit.
| |
| in accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-72 Amendment No. 84,
| |
| | |
| SSW System and UHS 3.7.1 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME H. RequiredAction and H.1 ----------NOTE-----------
| |
| associated Completion LCO 3.0.4.a is not Time of Condition A, E, or applicable when G not met. entering MODE 3.
| |
| Be in MODE 3. 12 hours I. Required Action and 1.1 Be in MODE 3. 12 hours associated Completion Time of Condition B, D or AND F not met. I 0
| |
| 1.2 Be in MODE4. 36 hours OR Both SSW subsystems inoperable for reasons other than Condition F.
| |
| OR Three or four UHS cooling tower fan cells inoperable.
| |
| In accordance with the Surveillance Frequency Control Program SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY A
| |
| SR 3.7.1.1 Verify the water level of UH S cooling tower basin is 24 Fl81::lFS
| |
| ?: 78%.
| |
| SR 3.7.1.2 Verify the average water te mperature of UHS is ~4 Fl81::lFS:.:
| |
| < 88°F.
| |
| <Move SR row to next page>
| |
| [ SR 3.7.1.3 Operate each cooling towe r fan cell for ?: 15 minutes. ".>'1
| |
| - --J- . . .
| |
| (continued)
| |
| RIVER BEND 3.7-3 Amendment No~ 81 185,
| |
| | |
| SSW System and UHS 3.7.1 SURVEILLANCE REQUIREMENTS (continued SURVEILLANCE FREQUENCY SR 3.7.1.4 Verify each required SSW subsystem manual, po wer 31 days~
| |
| operated, and automatic valve in the flow path servicing safety related systems or components, t hat is not locked, sealed, or otherwise secured in position, is in the correct position. '
| |
| SR 3.7.1.5 Verify each SSW subsystem actuates on an actu al or ~4 ffi9RtRS ~
| |
| simulated initiation signal.
| |
| In accordance with the Surveiiiance Frequency Control Program RIVER BEND 3.7-4 Amendment No. 81, 168,
| |
| | |
| CRFA System 3.7.2 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME F. Two CRFA subsystems F.1 Suspend movement of Immediately inoperable during recently irradiated fuel movement of recently assemblies in the primary irradiated fuel assemblies containment and fuel in the primary containment building.
| |
| or fuel building, or during OPDRVs.
| |
| F.2 Initiate action to suspend Immediately OPDRVs.
| |
| One or more CRFA subsystems inoperable due to inoperable CRE boundary during movement of recently irradiated fuel assemblies in the primary containment or fuel building, or during OPDRVs.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 Operate each CRFA subsystem fo r:::: 1O continuous 31 Elays ~
| |
| hours with the heaters operating.
| |
| SR 3.7.2.2 Perform required CRFA filter testin g in accordance In accordance with with the Ventilation Filter Testing P rogram (VFTP). the VFTP SR 3.7.2.3 Verify each CRFA subsystem actu ates on an actual -'"lA - -* - -
| |
| or simulated initiation signal.
| |
| (continued)
| |
| In accordance with the Surveillance -
| |
| Frequency Control Program RIVER BEND 3.7-7 Amendment No. 81119 132154 165, 168,
| |
| | |
| Control Room AC System 3.7.3 ACTIONS (continued)
| |
| CONDITION. REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Suspend movement of Immediately associated Completion recently irradiated fuel Time of Condition B not assemblies in the primary met during movement of containment and fuel recently irradiated fuel building.
| |
| assemblies in the primary containment or fuel AND building, or during OPDRVs. E.2 Initiate action to suspend Immediately OPDRVs.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify each control room AC. subsystem has the* 24 months~
| |
| capability to remove the assumed heat load.
| |
| in accordance with the Surveillance Frequency Control Program RIVER BEND 3.7-11 Amendment No. 81 119 132, 168,
| |
| | |
| Main Condenser Offgas 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY
| |
| *----------------**----------------------------------------------------------------------------------------------------------------------1*---------------------------- -----*-**********---------------**********--****
| |
| SR 3.7.4.1 Verify the gross gamma activity rate of the noble Once within gases is :<,:; 290 ,mCi/second after decay of 30 minutes. 4 hours after a
| |
| :2: 50% increase in the nominal steady state fission gas release rate after factoring out increases due to changes in THERMAL POWER level SR 3.7.4.2 -----------------------------NOTE--------------------------------
| |
| N ot required to be performed until 31 days after any main steam line not isolated and SJAE in operation.
| |
| Verify the gross gamma activity rate of the noble 31 days------.
| |
| gases is :<,:; 290 mCi/second after decay of 30 minutes.
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND* 3.7-13 Amendment No. &:I-,
| |
| | |
| Main Turbine Bypass System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify one complete cycle of each main turbine 31 Elays ~
| |
| bypass valve.
| |
| SR 3.7.5.2 Perform a system functional test. 24 FR9RtAS SR 3.7.5.3 Verify the TURBINE BYPASS SYSTEM RESPONSE 24 FR9RtAS ~
| |
| TIME is within limits.
| |
| in accordance with the Surveillance Frequency Control Program RIVER BEND 3.7-14a Amendment No. 81 114 163, 168,
| |
| | |
| Fuel Pool Water Level 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Fuel Pool Water Level LCO 3.7.6 The fuel pool water level shall be 2 23 ft over the top of irradiated fuel assemblies seated in the spent fuel storage pool and upper containment fuel storage pool racks.
| |
| APPLICABILITY: During movement of irradiated fuel assemblies in the associated fuel storage pool.
| |
| ACTIONS I
| |
| CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel pool water level not A.1 ------------NOTE-----------
| |
| within limit. LCO 3.0.3 is not applicable.
| |
| Suspend movement of Immediately irradiated fuel assemblies in the associated fuel storage pool(s).
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the fuel pool water level is 2 23 ft over the top 7 days~::::-_----~
| |
| of irradiated fuel assemblies seated in the storage racks.
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.7-15 Amendment No. &:I-,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power 7 Elays ~
| |
| availability for each required offsite circuit.
| |
| SR 3.8.1.2 -----------------------------NOTES-------------------------------
| |
| : 1. Performance of SR 3.8.1. 7 satisfies this SR.,,
| |
| : 2. All DG starts may be preceded by an engine prelube period and followed by a warmup*peri od prior to loading.
| |
| : 3. A modified DG start involving gradual acceleration to synchronous speed may be us ed for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.
| |
| Verify each DG starts from standby conditions and 31 days ~
| |
| achieves:
| |
| : a. For DG 1A and DG 1B, steady state voltage
| |
| ~ 3740 Vand ~ 4368 V and frequency~ 58.8 Hz and ~ 60.2 Hz.
| |
| : b. For DG 1C: --
| |
| : 1. Maximum of 5400 V, and 66. 75 Hz, and
| |
| : 2. Steady state voltage ~ 3740 V and
| |
| ~ 4580 V and frequency~ 58.8 Hz and
| |
| ~ 60.2 Hz.
| |
| (continued)
| |
| In accordance with the Surveiilance Frequency Control Program RIVER BEND 3.8-5 Amendment No. 8190121, 187,
| |
| | |
| l AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.3 ------------------------------NOTES------------------------------
| |
| : 1. DG loadings may include gradual loading as recommended by the manufacturer.
| |
| : 2. Momentary transients outside the load range do not invalidate this test.
| |
| : 3. This Surveillance shall be conducted on only one DG at a time.
| |
| : 4. This SR shall be preceded by, and immediately follow, without shutdown, a successful performance of SR 3.8.1.2 or SR 3.8.1.7 Verify each DG operates for:::: 60 minutes at a load 31 days,
| |
| :::: 3050 kW ands 3100 kW for DG 1A and DG 18, and
| |
| :::: 2525 kW and s 2600 kW for DG 1C.
| |
| SR 3.8.1.4 Verify each day tank contains :::: 316.3 gal of fuel oil. 31 days -0~-------1 SR 3.8.1.5 Check for and remove accumulated water from each 31 days <r~-------1 day tank.
| |
| SR 3.8.1.6 Verify the fuel oil transfer system operates to 31 days ~
| |
| automatically transfer fuel oil from the storage tank to the day tank. *
| |
| (continued)
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.8-6 Amendment No. 8190121, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.7 -------------------------NOTE-------------------------------------
| |
| All DG starts may be preceded by an engine prelube I period.
| |
| Verify each DG starts from standby conditions and 184 days::.
| |
| achieves:
| |
| : a. For DG 1A and DG 1B:
| |
| : 1. In :c:::; 10 seconds, voltage;::: 3740 V and frequency;::: 58.8 Hz; and
| |
| : 2. Steady state voltage ;::: 3740 V and
| |
| :c:::; 4368 V and frequency;::: 58.8 Hz and
| |
| <Mo ve SR row to next paqe> :c:::; 60.2 Hz.
| |
| : b. For DG 1C:
| |
| : 1. Maximum of 5400 V, and 66. 75 Hz, and Ai...
| |
| < c.,1 l!ne space>\ 2. In~ 13 seconds, voltage;::: 3740 V and frequency;::: 58.8 Hz; and
| |
| !n accordance vvitJ1 the Survsiilance Frequency Control Steady state voltage ;::: 3740 V and
| |
| ~ 4580 V and frequency;::: 58.8 Hz and
| |
| :c:::; 60.2 Hz.
| |
| SR 3.8.1.8 -------------------------------NOTES-------------------------------
| |
| : 1. This Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.
| |
| : 2. SR 3.8.1.8.b is only required to be met if 22 kV onsite circuit is supplying Division Ill safety related bus E22-S004 from normal power transformer STX-XNS 1C.
| |
| I
| |
| ~
| |
| , for required '
| |
| unit p ower a. Verify mManual transfer of unit power supply 24 months
| |
| * suppl ies: from the normal offsite circuit to required alternate offsite circuit~; and
| |
| : b. Verify aAutomatic transfer of bus E22-S004 24 months through NNS-SWG1A or NNS-SWG1B from thej22 kV onsite circuit to required offsite circuit.
| |
| I
| |
| <Adel space>
| |
| (continued)
| |
| RIVER BEND 3.8-7 Amendment No. 81 121 165 168 176, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.1.9 ------------------------------NOTE-------------------------------
| |
| : 1. Credit may be taken for unplanned events that satisfy this SR.
| |
| : 2. If performed with DG synchronized with offsite power, it shall be performed at a power factor
| |
| :s; 0.9 Verify each DG rejects a load greater than or equal to 24 months its associated single largest post accident load and following load rejection, the engine speed is maintained le s than nominal plus 75% of the 1
| |
| difference between nominal speed and the overspeed trip setpoint or 15% above nominal, whichever is lower.
| |
| SR 3.8.1.10 ------------------------------NOTE-----------------------------
| |
| C red it may be taken for unplanned events that satisfy this SR.
| |
| Verify each DG operating at a power factor :s; 0.9 does 24 months--~---1 not trip and voltage is maintained :s; 4784 V for DG 1A and DG 1B and :s; 5400 V for DG 1C during and following a load rejection of a load ~ 3050 kW and
| |
| :s; 3130 kW for DGs 1A and 18 and~ 2525 kW and
| |
| :s; 2600 kW for DG 1C.
| |
| (continued)
| |
| <Move SR row to next pao,e>,
| |
| In accordance with the Survei!iance Frequency Control Program RIVER BEND 3.8-8 Amendment No. 81 121 133 137 168, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.11 ---------------- .---------------NOTES-- *-----------------------
| |
| : 1. All DG starts may be preceded by an engine prelube period.
| |
| In accordance with
| |
| : 2. This Surveillance shall not be performed in the Surveillance MODE 1, 2, or 3. (Not applicable to DG 1C) Frequency Control However, credit may be taken for unplanned Program events that satisfy this SR.
| |
| Verify on an actual or simulated loss of offsite power 24 months+"'..---
| |
| signal:
| |
| : a. De-energization of emergency buses;
| |
| : b. Load shedding from emergency buses for Divisions I and 11; and (continued)
| |
| ~
| |
| SR 3.8. i .-1 *1 (continued)
| |
| : c. DG auto-starts from standby condition and:
| |
| : 1. energizes permanently connected loads in
| |
| ~ 10 seconds for DG 1A and DG 18 and
| |
| ~ 13 seconds for DG ~C,
| |
| : 2. energizes auto-connected shutdown loads,
| |
| : 3. maintains steady state voltage
| |
| : i. for DG 1A and DG 18 ~ 3740 Vand
| |
| ~4368 V, ii. for DG 1C ~ 3740 Vand ~ 4580 V
| |
| : 4. maintains steady state frequency~ 58.8 Hz and ~ 60.2 Hz, and
| |
| : 5. supplies permanently connected and auto-connected shutdown loads for
| |
| ~ 5 minutes.
| |
| (continued)
| |
| ~ <Spiit SR row and move SR 3.8.1. *11.c to Page 3.8-1 O>
| |
| RIVER BEND 3.8-9 Amendment No. 81 121 133 168, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.12 -------------------------------NOTES--------------------. --------
| |
| : 1. All DG starts may be preceded by an engine prelube period.
| |
| : 2. This Surveillance shall._oot be performed in MODE 1 or 2. (Not applicable to DG 1C)
| |
| However, credit may be taken for unplanned events that satisfy this SR.
| |
| I Verify on an actual or simulated Emergency Core 24 months-------.
| |
| Cooling System (ECCS) initiation signal each DG auto-starts from standby condition and:
| |
| : a. For DG 1C during the auto-start maintains voltage :s; 5400 V and frequency :s; 66.75 Hz;
| |
| : b. In :s; 10 seconds for DG 1A and DG 18 and
| |
| :s; 13 seconds for DG 1C after auto-start and during tests, achieves voltage~ 3740 V and frequency~ 58.8 Hz.
| |
| : c. Achieves steady state voltage
| |
| : 1. For DG 1A and DG 18 ~ 3740 V and
| |
| :,;;4368 V,
| |
| : 2. For DG 1C ~ 3740 V and :s; 4580 V, and
| |
| : 3. For DG 1A, 18, and 1C, frequency of
| |
| ~ 58.8 and :s; 60.2 Hz; and
| |
| : d. Operates for~ 5 minutes.
| |
| (cpntinued)
| |
| In accordance with U1e Survelilance Frequency Control Progran1 RIVER BEND 3.8-4-01, Amendment No. 81 121 133 165 168, 187,
| |
| | |
| AC Sources-Operating
| |
| <Chanqe Frequencv column width to 1.45">\ 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.13 ---------------------. -----NOTE---------------------------
| |
| This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C)
| |
| However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify each DG's automatic trips are bypassed on 24 months an actual or simulated ECCS initiation signal except:
| |
| : a. Engine overspeed; and
| |
| : b. Generator differential current.
| |
| SR 3.8.1.14 --------------------------NO TES---------------------------
| |
| : 1. Momentary transients outside the load and power factor ranges do not invalidate this test.
| |
| : 2. Credit may be taken for unplanned events
| |
| ( '
| |
| that satisfy this SR.
| |
| Verify each DG operating at a power factor~ 0.9, 24 months"'.!
| |
| operates for ~ 24 hours: I
| |
| : a. For DG 1A and DG 18 loaded~ 3050 kW and~ 3130 kW; and
| |
| : b. For DG 1C:
| |
| In accordance vvith
| |
| : 1. For ~ 2 hours loaded ~ 2750 kW and the Sunieillance
| |
| ~ 2850 kW, and Frequency Control Program
| |
| : 2. For the remaining hours of the test loaded ~ 2525 kW and ~ 2600 kW.
| |
| (continued)
| |
| RIVER BEND 3.84412 Amendment No. 81 94 121133 168, 187,
| |
| | |
| AC Sources-Operating l I 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| /
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.15 -----------------------------NOTES--- ,---------------------------
| |
| : 1. This SuNeillance shall be performed within 5 minutes of shutting down the DG after the DG has operated 2 1 hour loaded 2 3050 kW and
| |
| :;;; 3100 kW for DG 1A and DG 18, and 2 2525 kW and :5: 2600 for DG 1C, or operating temperatures have stabilized, which ever is longer.
| |
| Momentary transients outside of the load range do not invalidate this test.
| |
| : 2. All DG starts may be preceded by an engine prelube period.
| |
| Verify each DG starts and achieves:
| |
| 24 months
| |
| : 1. In :;;; 1O seconds for DG 1A and DG 1B and
| |
| :;;; 13 seconds for DG 1C voltage 2 3740 Vand frequency 2 58.8 H2:, and
| |
| : 2. Steady state voltage a) For DG 1A and DG 18 2 3740 V and
| |
| :5:4368 V b) For DG 1C 2 3740 V and:;;; 4580 V and c) For DG 1A, 18, and 1C frequency 2 58.8 Hz and:;;; 60.2 Hz.
| |
| (continued)
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.8-=R'13 Amendment No. 81 121 133 165 168, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.16 ------------------------- *. -NOTE---------------------------------
| |
| Th is Surveillance shall not be performed in MODE 1, 2,
| |
| , or 3. (Not applicable to DG 1C) However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify each DG: 24 months-:::
| |
| : a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;
| |
| : b. Transfers loads to offsite power source; and
| |
| : c. Returns to ready-to-load operation.
| |
| SR 3.8.1.17 ------------------------------NOTE--------------------------------
| |
| Th is Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C) However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify, with a DG operating in test mode and 24 months~
| |
| connected to its bus, an actual or simulated ECCS initiation signal overrides the test mode by:
| |
| In accordance with the Survei!lance
| |
| : a. Returning DG to ready-to-load operation; and Frequency Control Program
| |
| : b. Automatically energizing the emergency loads from offsite power.
| |
| SR 3.8.1.18 -----------------------------NOTE--------- . --------------------
| |
| Th is Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C) However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify sequence time is within+/- 10% of design for 24 months::.
| |
| each load sequencer timer. *
| |
| (continued)
| |
| RIVER BEND 3.8~14 Amendment No. 81 95 121 133 168, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.19 -------------------------------NOTES-* ---------------------------
| |
| : 1. All DG starts may be preceded by an engine prelube period.
| |
| : 2. This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C)
| |
| However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify, on an actual or simulated loss of offsite power 24 months ~
| |
| signal in conjunction with an actual or simulated ECCS initiation signal:
| |
| : a. De-energization of emergency buses;
| |
| : b. Load shedding from emergency buses for In accordance Divisions I and 11; and Surveiliance Frequency Control C. DG auto-starts from standby condition and: Prograrn
| |
| : 1. energizes permanently connected loads in
| |
| ~ 10 seconds for DG 1A and DG 1B and
| |
| ~ 13 seconds for DG 1C,
| |
| : 2. energizes auto-connected emergency loads,
| |
| : 3. achieves steady state voltage
| |
| : i. for DG 1A and DG 18 ~ 3740 Vand
| |
| ~4368 V, ii. for DG 1C ~ 3740 V and~ 4580 V,
| |
| : 4. achieves steady state frequency~ 58.8 Hz and~ 60.2 Hz, and
| |
| : 5. supplies permanently connected and auto-connected emergency loads for
| |
| ~ 5 minutes.
| |
| (continued)
| |
| RIVER BE:ND 3.8-4415 Amendment No. 81 121133 168, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.20 ------------------------------NOTE---------- ., --------------------
| |
| A II DG starts may be preceded by an engine prelube period.
| |
| Verify, when started simultaneously from standby 10 years:::
| |
| condition, each DG achieves:
| |
| : 1. In :s; 10 seconds for DG 1A and DG 1B and
| |
| :s; 13 seconds for DG 1C voltage ~ 3740 V and frequency~ 58.8 Hz, and
| |
| : 2. Steady state voltage a) For DG 1A and DG 1B ~ 3740 V and
| |
| :s; 4368 V, b) For DG 1C ~ 3740 V and :s; 4580 V, and c) For DG 1A, 1B, and 1C a frequency
| |
| ~ 58.8 Hz and :s; 60.2 Hz.
| |
| In accordance with the Surveill;:mce Frequency Control Program RIVER BEND 3.8-4§16 Amendment No. 81 121 165, 187,
| |
| | |
| AG Sources Oper~
| |
| Table 3.8. 1 1 has been deleted
| |
| /
| |
| RIVER BEND 3.8 16 nm t-. endment No. 81, 90
| |
| | |
| Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains ~ 45,495 gaI 3~ Elays ~
| |
| of fuel.
| |
| SR 3.8.3.2 Verify lube oil inventory is: 3~ Elays:::
| |
| : a. ~ 367 gal for DGs 1A and 1B; and
| |
| : b. ~ 295 gal for DG 1C.
| |
| SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are In accordance with tested in accordance with, and maintained within the the Diesel Fuel Oil limits of, the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.4 Verify each required DG air start receiver pressure is 31 Elays:::
| |
| : a. ~ 160 psig for DGs 1A and 1B; and
| |
| : b. ~ 200 psig for DG 1C.
| |
| SR 3.8.3.5 Check for and remove accumulated water from each 31 Elays ~
| |
| fuel oil storage tank.
| |
| SR 3.8.3.6 Deletes
| |
| ~
| |
| - =~=====
| |
| <Delete SR row> In accordance with tl1e Surveillance Frequency Control Program RIVER BEND 3.8-23 Amendment No. 81 91, 160,
| |
| | |
| DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is ;::>: 130.2 V on float 7 Elays J charge.
| |
| SR 3.8.4.2 Verify no visible corrosion at battery terminals and 92 Elays ~
| |
| connectors.
| |
| Verify battery connection resistance is
| |
| ::; 1.5 E-4 ohm for inter-cell connections,
| |
| ::; 1.5 E-4 ohm for inter-rack connections,
| |
| ::; 1.5 E-4 ohm for inter-tier connections, and
| |
| ::; 1.5 E-4 ohm for terminal connections.
| |
| SR 3.8.4.3
| |
| * Verify battery cells, cell plates, and racks show no 24 FA9RtRS ~
| |
| visual indication of physical damage or abnormal deterioration.
| |
| SR 3.8.4.4 Remove visible corrosion, and verify battery cell to 24 rneRtRS ~
| |
| cell and terminal connections are coated with anti-corrosion material.
| |
| SR 3.8.4.5 Verify battery connection resistance is 24 rneRtRS ~
| |
| 1
| |
| ::; 1.5 E-4 ohm for inter-cell connections,
| |
| ::; 1.5 E-4 ohm for inter-rack connections,
| |
| ::; 1.5 E-4 ohm for inter-tier connections, and
| |
| \::; 1.5 E-4 ohm for terminal connections.
| |
| (continued)
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.8-25 Amendment No. 81, 168,
| |
| | |
| DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.4.6 Verify each battery charger supplies ~ 300 amps fo r 24 months~
| |
| chargers 1A and 1B and ~ 50 amps for charger 1C at
| |
| ~ 130.2 V for~ 8 hours.
| |
| SR 3.8.4.7 -----------------------------NOTES---------------------------- --
| |
| : 1. SR 3.8.4.8 may be performed in lieu of SR 3.8.4. 7 once per 60 months.
| |
| : 2. This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division II I).
| |
| However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify battery capacity is adequate to supply, and - ~--*t..
| |
| "lA maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.
| |
| (continued)
| |
| In accordance with -
| |
| tt1e Surveillance Frequency Control Program RIVER BEND 3.8-26 Amendment No. 81 141, 168,
| |
| | |
| DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.4.8 -------------------------------NOTE------------------------------
| |
| T his Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division Ill). However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify battery capacity is ~ 80% of the manufacturer's 60 months-----.
| |
| rating when subjected to a performance discharge test. AND
| |
| ---------NOTE-------
| |
| Only applicable when battery shows degradation or has reached 85% of expected life.
| |
| <Chanqe to double line>
| |
| t 18 months In accordance with H1e Sun1eii!ance Frequency Control Program RIVER BEND 3.8-27 Amendment No. 81, 141,
| |
| | |
| Battery Cell Parameters 3.8.6 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and 8.1 Declare associated Immediately associated Completion battery inoperable.
| |
| Time of Condition A not met.
| |
| OR One or more batteries with average electrolyte temperature of the representative cells
| |
| < 60°F.
| |
| OR
| |
| /
| |
| One or more batteries with one or more battery cell parameters not within Category*C limits.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet Table 3.8.6-1 7 days:::.
| |
| Category A limits.
| |
| (continued)
| |
| In accordance with the Surveiiiance Frequency Control Program RIVER BEND 3.8-32 Amendment No. &+,
| |
| | |
| Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6-1 Category B limits.
| |
| Once within 72 hours after battery overcharge
| |
| > 144 V SR 3.8.6.3 Verify average electrolyte temperature of 92 days~
| |
| representative cells is~ 60°F.
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.8-33 Amendment No. M,
| |
| | |
| Inverters-0 perating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8. 7 Inverters-Operating LCO 3.8.7 The Division I and Division II inverters shall be OPERABLE.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS
| |
| ---------------------------------------------------NOTE-----------------------------------------------------------------
| |
| Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution Systems-Operating," with any AC vital bus ~e-energized.
| |
| CONDITION REQUIRED ACTION COMPLETION TIME A. Division I or 11 inverter A.1 Restore Division I and 11 . 24 hours inoperable. inverters to OPERABLE status.
| |
| B. Required Action and B.1 ------------NOTE-------------
| |
| associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when entering met. MODE 3.
| |
| Be in MODE 3. 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, frequency, and 7 days alignment to required AC vital buses.
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.8-35 Amendment No. 81 185,
| |
| | |
| Inverters-Shutdown 3.8.8 ACTIONS (continued)
| |
| CONDITIONS REQUIRED ACTION . COMPLETION TIME A. (continued) A.2.3 Initiate action to Immediately suspend operations with a potential for draining the reactor vessel.
| |
| A.2.4 Initiate action to restore Immediately required inverters to OPERABLE status.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 , Verify correct inverter voltage, frequency, and 7 days ...,.A-------,
| |
| alignments to required AC vital buses.
| |
| In accordance with ,__
| |
| the Surveii!ance*
| |
| Frequency Control Program RIVER BEND 3.8-37 Amendment No. 84-,
| |
| | |
| Distribution Systems-a perating 3.8.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to 7 days~
| |
| required AC, DC, and AC vital bus electrical power distribution subsystems.
| |
| in accordance with the Surveillance Frequency Control Program RIVER BEND 3.8-40 Amendment No. -84,
| |
| | |
| Distribution Systems-Shutdown 3.8.10 ACTIONS (continued)
| |
| CONDITIONS REQUIRED ACTIONS COMPLETION TIME A. (continued) A.2.3 Initiate action to Immediately suspend operations with a potential for draining the reactor vessel.
| |
| A.2.4 Initiate actions to Immediately restore required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.
| |
| AND A.2.5 Declare associated Immediately required shutdown cooling subsystem(s) inoperable and not in operation.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to 7 days <<-<------,
| |
| required AC, DC, and AC vital bus electrical power distribution subsystems.
| |
| in accordance with -
| |
| the Surveillance Frequency Control Program RIVER BEND 3.8-42 Amendment No, ~.
| |
| | |
| Refueling Equipment Interlocks 3.9.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Perform CHANNEL FUNCTIONAL TEST on each of 7 days * : : : - - - - -
| |
| the following required refueling equipment interlock inputs:
| |
| : a. All-rods-in,
| |
| : b. Refuel platform position, and
| |
| : c. Refuel platform main hoist, fuel loaded.
| |
| In accordance with -
| |
| the Surveillance Frequency Control Program RIVER BEND 3.9-1a Amendment No. 4G4,
| |
| | |
| Refueling Position One - Rod - Out Interlock 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Refuel Position One-Rod-Out Interlock LCO 3.9.2 The refuel position one-rod-out interlock shall be OPERABLE.
| |
| APPLICABILITY: MODE 5 with the reactor mode switch in the refuel position and any control rod withdrawn.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refuel position one- rod- A.1 Suspend control rod Immediately out interlock inoperable. withdrawal.
| |
| A.2 Initiate action to fully insert all Immediately insertable control rods in core cells containing one or more fuel assemblies.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify reactor mode switch locked in refuel position. 12 hours-~----~
| |
| (continued)
| |
| !n accordance with the Surveillance Frequency Control Program RIVER BEND 3.9-2 Amendment No. g.:i.,
| |
| | |
| Refueling Position One - Rod - Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.9.2.2 -----------------------------NOTE--------------------------------
| |
| Not required to be performed until 1 hour after any control rod is withdrawn.
| |
| Perform CHANNEL FUNCTIONAL TEST. 7 days +-------,
| |
| In accorciance with -
| |
| the Surveillance Frequency Control Program RIVER BEND 3.9-3 Amendment No. &i,
| |
| | |
| Control Rod Position 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Control Rod.Position LCO 3.9.3 All control rods shall be fully inserted. 1 APPLICABILITY: When loading fuel assemblies into the core.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more control rods A.1 Suspend loading fuel Immediately not fully inserted. assemblies into the core.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify all control rods are fully inserted. 12 hours In accordance with tl1e Surveillance Frequency Control Program RIVER BEND 3.9-4 Amendment No. 8--1-,
| |
| | |
| Control Rod OPERABILITY - Refueling 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Control Rod OPERABILITY - Refueling LCO 3.9.5 Each withdrawn control rod shall be OPERABLE.
| |
| APPLICABILITY: MODE 5.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more withdrawn A.1 Initiate action to fully insert Immediately control rods inoperable. inoperable withdrawn control rods.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 ----------------------------NOTE---------------------------------
| |
| Not required to be performed until 7 days after the control rod is withdrawn.
| |
| Insert each withdrawn control rod at least one notch. +Elays ~
| |
| SR 3.9.5.2 Verify each withdrawn control rod scram accumulator +Elays :::
| |
| pressure is;:::,: 1540 psig.
| |
| in accordance with -
| |
| the Surveillance Frequency Control Program RIVER BEND 3.9-7 Amendment No. 81, 114,
| |
| | |
| RPV Water Level -Irradiated Fuel 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Reactor Pressure Vessel (RPV) Water Level - Irradiated Fuel LCO 3.9.6 RPV water level shall be ~ 23 ft above the top of the RPV flange.
| |
| APPLICABILITY: During movement of irradiated fuel assemblies within the RPV.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not within A.1\. Suspend movement of Immediately limit. irradiated fuel assemblies within the RPV.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify RPV water level is ~ 23 ft above the top of the 24 hours - < r , ~ - - - - - - .
| |
| RPVflange.
| |
| ln accordance with -
| |
| the Sur,;eillance Frequency Control Program RIVER BEND 3.9-8 Amendment No. M,
| |
| | |
| RPV Water Level - New Fuel or Control Rods 3.9.7 3.9 REFUELING OPERATIONS 3.9. 7 Reactor Pressure Vessel (RPV) Water Level - New Fuel or Control Rods LCO 3.9.7 RPV water level shall be 2:: 23 ft above the top of irradiated fuel assemblies seated within the RPV.
| |
| APPLICABILITY: During movement of new fuel assemblies or handling of control rods within the RPV when. irradiated fuel assemblies are seated within the RPV.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not within A.1 Suspend movement of new Immediately limit. fuel assemblies and handling of control rods within the RPV.
| |
| <Change F,equencv column width to 1.45">
| |
| SURVEILLANCE REQUIREMENTS \
| |
| SURVEILLANCE FREQUENCY SR 3.9.7.1
| |
| * Verify RPV water level is ;::: 23 ft above the top of 24 hours+.:::--------.
| |
| irradiated fuel assemblies seated within the RPV.
| |
| In accordance with the Surveiliance Frequency Control Program RIVER BEND 3.9-9 Amendment No. g.:J..,
| |
| | |
| RHR - High Water Level 3.9.8 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) 8.3 -----------NOTE------------
| |
| Entry and exit is permissible under administrative control.
| |
| Initiate .action to close Immediately one door in each primary containment air lock.
| |
| C. No RHR shutdown cooli'ng C.1 Verify reactor coolant 1 hour from subsystem in operation. circulation by an discovery of no alternate method. reactor coolant circulation AND Once per 12 hours thereafter AND
| |
| ' C.2 Monitor reactor coolant Once per hour temperature.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem is 1~ R9tlFS J operating.
| |
| SR 3.9.8.2 Verify required RHR shutdown cooling subsystem :31 Elays ~
| |
| locations susceptible to gas accumulation are sufficiently filled with water. r ln accordance with the Surveillance Frequency Control Program RIVER BEND 3.9-11 Amendment No. 81, 188,
| |
| | |
| RHR - Low Water Level 3.9.9 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 -----------NO TE-----------
| |
| Entry and exit is "
| |
| permissible under administrative control.
| |
| Initiate action to close Immediately one door in each (
| |
| primary containment air lock.
| |
| C. No RHR shutdown cooling C.1 Verify reactor coolant 1 hour from discovery subsystem in operation. circulation by an of no reactor coolant alternate method. circulation AND Once per 12 hours thereafter AND C.2 Monitor reactor coolant Once per hour
| |
| <Deiete extra space> ___
| |
| ~ temperature.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.9.1 Verify one RHR shutdown cooling subsystem is 12 hours-----~
| |
| operating.
| |
| SR 3.9.9.2 Verify required RHR shutdown cooling subsystem 31 days - - - - - - - i locations susceptible to gas accumulation are sufficiently filled with water.
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.9-13 Amendment No. 81, 188,
| |
| | |
| Reactor Mode Switch Interlock Testing 3.10.2 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3.1 Place the reactor mode 1 hour switch in the shutdown position ..
| |
| OR A.3.2 -----------NOTE----------
| |
| Only applicable in MODE 5.
| |
| Place the reactor mode 1 hour switch in the refuel position.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.2.1 Verify all control rods are fully inserted in core cells ~~ 1:191:lFS ~
| |
| containing one or more fuel assemblies.
| |
| SR 3.10.2.2 Verify no CORE ALTERATIONS are in progress. ~
| |
| *~~*~
| |
| In accordance with ,___
| |
| the Surveillance Frequency Control Program RIVER BEND 3.10-5 Amendment No. at,
| |
| | |
| - I Single Control Rod Withdrawal - Hot Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.3.1 Perform the applicable SRs for the required LCOs. According to the applicable SRs SR 3.10.3.2 ---------------------------N OT E-----------------------------------
| |
| N ot required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.d.1 requirements.
| |
| Verify all control rods, other than the control rod being 24 hours+~-.---,--~-.
| |
| withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed. '
| |
| SR 3.10.3.3 Verify all control rods, other than the control rod being 24 hours < 1 1 1 ' ~ - - - - - - 1 withdrawn, are fully inserted.
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.10-8 Amendment No. g4,
| |
| | |
| Single Control Rod Withdrawal - Cold Shutdown 3.10.4 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME B. One or more of the above B.1 Suspend withdrawal of Immediately requirements not met with the control rod and the affected control rod not removal of associated insertable. CRD.
| |
| AND B.2.1 Initiate action to fully Immediately insert all control rods.
| |
| B.2.2 Initiate action to satisfy Immediately the requirements of this LCO.
| |
| <Add line space>
| |
| . SURVEILLANCE REQUIREMENTS \
| |
| SURVEILLANCE FREQUENCY
| |
| * SR 3.10.4.1 Perform the applicable SRs for the required LCOs. According to i:la plicable SRs SR 3.10.4.2 ---------------------------NOTE----------------------------------
| |
| Not required to be met if SR 3.10.4.1 is satisfiedfor LCO 3.10.4.c.1 requirements:
| |
| Verify all control rods, other than the control rod being 24 hours<<-------,
| |
| withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed.
| |
| (continued)
| |
| In accordance *vvith the Surveiliance Frequency Control Program RIVER BEND 3.10-11 Amendment No. 3=1-,
| |
| | |
| Single Control Rod Withdrawal - Cold Shutdown 3.10.4 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.10.4.3 Verify all control rods, other than the control rod being 24 REll::IFS ~
| |
| withdrawn, are fully inserted.
| |
| SR 3.10.4.4 -----------------------------NOTE-------------------------------
| |
| N ot required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.b.1 requirements.
| |
| Verify a control rod withdrawal block is inserted. 24 R01::1FS I
| |
| In accorda:ice witr1 -
| |
| the Surveillance Frequency Control Program RIVER BEND 3.10-12 Amendment No. &+,
| |
| | |
| Single CRD Removal - Refueling 3.10.5 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.1 Initiate action to fully Immediately insert all control rods.
| |
| A.2.2 Initiate action to satisfy Immediately the requirements of this LCO.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.5.1 Verify all controls rods, other than the control rod 24 hours~
| |
| withdrawn for the removal of the associated CRD, are fully inserted.
| |
| SR 3.10.5.2 Verify all control rods, other than the control rod 24 hours<!
| |
| withdrawn for the removal of the associated CRD, in a five by five array centered on the control rod withdrawn for the removal of the associated CRD, are disarmed.
| |
| SR 3.10.5.3 Verify a control rod withdrawal block is inserted.
| |
| * 24 hourn<l (continued)
| |
| In accordance with -
| |
| the Surveiliance F(equency Control Program RIVER BEND 3.10-14 Amendment No. 3+,
| |
| | |
| Single CRD Removal - Refueling 3.10.5 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.10.5.4 Perform SR 3.1.1.1. According to SR 3.1.1.1 SR 3.10.5.5 Verify no CORE ALTERATIONS are in progress. 24 hours ~~------,
| |
| In accordance vvith -
| |
| the Survei!iance Frequency Controi Program RIVER BEND 3.10-15 Amendment No. g..:i..,
| |
| | |
| Multiple Control Rod Withdrawal - Refueling 3.10.6 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3.1 Initiate action to fully Immediately insert all control rods in core cells containing one or more fuel assemblies.
| |
| A.3.2 Initiate action to satisfy
| |
| * Immediately the requirements of this LCO.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.6.1 Verify the four fuel assemblies are removed from 24 A9l:IFS, core cells associated with each control rod or CRD removed.
| |
| SR 3.10.6.2 Verify all other control rods in core cells containing 24 A81:1FS, one or more fuel assemblies are fully inserted.
| |
| SR 3.10.6.3 --------. ------------------NOTE-------------------------------
| |
| 0 n ly required to be met during fuel loading.
| |
| Verify fuel assemblies being loaded are in 24 A91:1FS:::
| |
| compliance with an approved spiral reload sequence.
| |
| In accordance with the Surveillance Frequency Control Program ii RIVER BEND 3.10-17 Amendment No. 84,
| |
| | |
| SOM Test-Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.10.8.2 ---------------------------NOTE-----------------------------* ----
| |
| Not required to be met if SR 3.10.8.3 satlsfied.
| |
| Perform the MODE 2 applicable SRs for LCO 3.3.2.1, According to the Function 1.b of Table 3.3.2.1-1. applicable SRs SR 3.10.8.3 ----------------------------NOTE---------------------------- .----
| |
| Not required to be met if SR 3.10.8.2 satisfied.
| |
| I Verify movement of control rods is in compliance with During control rod the approved control rod sequence for the SOM test movement by a second licensed operator or other qualified member of the technical staff.
| |
| SR 3.10.8.4 Verify no other CORE ALTERATIONS are in 12 hours progress.
| |
| (continued)
| |
| In accordance with the Surveillance Frequency Control Program RIVER BEND 3.10-21 Amendment No. &+-,
| |
| *',1
| |
| \
| |
| | |
| SOM Test-Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.10.8.5 Verify each withdrawn control rod does not go to the Each time the withdrawn overtravel position. control rod is withdrawn to "full out" position Prior to satisfying LCO 3.10.8.c requirement after work on control rod or CRD System that could affect coupling SR 3.10.8.6 Verify CRD charging water header pressure :2:: 1540 7 days psig.
| |
| ln accordance with the Surveillance Frequency Control Program RIVER BEND 3.10-22 Amendment No. 81, 114,
| |
| \
| |
| | |
| Programs and Manuals 5.5 in accordance with the Surveillance 5.5 Programs and Manuals Frequency Control Program ASME OM Code and applicable Addenda terminology for Required frequencies inservice testing for performing inservice activities testing activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days
| |
| : b. The provisions of SR 3.0.2 are applicable to the above required frequencies and to other normal and accelerated frequencies specified as 2 years or less in the lnservice Testing Program for performing inservice testing activities;
| |
| : c. The provisions of SR 3.0.3 are applicable to inservice testing activities; and
| |
| : d. Nothing in the ASME OM Code shall be cohstrued to supersede the requirements of any TS.
| |
| 5.5.7 Ventilation Filter Testing Program (VFTP)
| |
| A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in Regulatory Guide 1.52, Revision 2, except that testing specified at a frequency of 18 months is required at a frequency of 24 months . <&-~---------'
| |
| . . . - - - - - - - ~ a. Demonstrate for each of the ESF systems that an inplace test of the high efficiency particulate air (HEPA) filters shows a penetration and system bypass < 0.05% when tested in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989 at the system flowrate specified below
| |
| +/- 10%:
| |
| ESF Ventilation System Flowrate SGTS 12,500 cfm FBVS 10,000 cfm CRFAS 4,000 cfm
| |
| . (continued)
| |
| RIVER BEND 5.0-11 Amendment No. 81 165 167, 168,
| |
| <Move 5.5.7.a to Page s.o-*12>
| |
| | |
| Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP) (continued)
| |
| : b. Demonstrate for each of the ESF systems that an in place test of the charcoal adsorber shows a penetration and system bypass< 0.05% when tested in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989 at the system flowrate specified below+/- 10%:
| |
| ESF Ventilation System Flowrate SGTS 12,500 cfm FBVS 10,000 cfm CRFAS 4,000 cfm
| |
| : c. Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52, Revision 2, shows the methyl iodide penetration less than the value specified below when tested in accordance with ASTM 03803-1989 at a temperature of 30°C and the relative humidity specified below:
| |
| ESF Ventilation System Penetration SGTS 5.0% 95%
| |
| FBVS 5.0% 95%
| |
| CRFAS 1.0% 95%
| |
| Demonstrate for each of the ESF systems that the pressure drop across the combined HEPAfilters, the prefilters, and the charcoal adsorbers is less than the value specified below when tested in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989 at the system flowrate specified below+/- 10%:
| |
| ESF Ventilation System Delta P Flowrate SGTS <8"WG 12,500 .cfm FBVS <8"WG. 10,000 cfm CRFAS <8"WG 4,000 cfm (continued)
| |
| <Move 5.5.7.d to Page 5.0-i3>
| |
| RIVER BEND 5.0-12 Amendment No. 81115 132, 165, 183,
| |
| | |
| Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP) (continued)
| |
| : e. Deleted The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.
| |
| 5.5.8 Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the main condenser offgas treatment system and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks.
| |
| The program shall include:
| |
| : a. The limits for concentrations of hydrogen in the main condenser offgas treatment system and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion);aand
| |
| : b. A surveillance program to ensure that the quantity of radioactive material contained in any unprotected outdoor tank is limited to ::;; 10 curies, excluding tritium and dissolved or entrained noble gases.
| |
| The provisions of SR 3.0.2 and SR 3.0.3 c1re applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies.
| |
| 5.5.9 Diesel Fuel Oil Testing Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The (continued)
| |
| J RIVER BEND 5.0-13 Amendment No. 84, 159 183,
| |
| | |
| Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Diesel Fuel Oil Testing Program (continued) program shall include sampling and testing requirements, and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following:
| |
| : a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has:
| |
| : 1. an API gravity or an absolute specific gravity within limits,
| |
| : 2. a flash point and kinematic viscosity within limits for ASTM 20 fuel oil,and
| |
| : 3. a clear and bright appearance with proper color;
| |
| : b. Other properties of the new fuel oil are within limits for ASTM 20 fuel oil within 31 days of addition to storage tanks; and
| |
| : c. Total particulate concentration of the fuel oil in the storage tanks is
| |
| < 10 mg/I when tested every 31 days in accordance with ASTM D-2276, Method A-2 or A-3. < ! - A - - - - - - - - - - - - - - - - - - - - - .
| |
| 5.5.10 Safety Function Determination Program (SFDP)
| |
| This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate limitations and remedial or compensatory actions may be identified to be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:
| |
| : a. Provisions for cross division checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected;
| |
| : b. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists; (continued)
| |
| I at a frequency in accordance witi1 the Surveillance Frequency Control Program RIVER BEND 5~0-14 Amendment No. &t,
| |
| | |
| Programs and Manuals
| |
| ....---------------------------'-~
| |
| .----ti S.5.14 Primarv Containment Leal<aqe Rate Testinq Program (continued) I 5 .5 5.5 Programs and Manuals 5.5.11 Technical Specifications (TS) Bases Control Program (continued)
| |
| C. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the USAR.
| |
| : d. Proposed changes that do not meet the criteria of either Specification 5.5.11.b.1 or Specification 5.5.11.b.2 above shall be reviewed and
| |
| <Insert 5.5.12> approved by the NRC prior to implementation. Changes to the Bases
| |
| \
| |
| implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e).
| |
| 5.5.12 DELETED 5.5.13 Primary Containment Leakage Rate Testing Program A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(0) ,and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program sh.all be in accordance with the guidelines contained in NEI 94-01, "Industry Guideline for Implementing Performance-Based Option of 10 CFR 50, Appendix J," Revision 3-A, dated July 2012, and the conditions and limitations specified in NEI 94-01, Revision 2-A, Section 4.1, dated October 2008.
| |
| The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa, is 7.6 psig .
| |
| .--------?;-
| |
| ~
| |
| The maximum allowable primary containment leakage rate, La, at Pa, sh.all be 0.325% of primary containment air weight per day.
| |
| The Primary Containment leakage rate acceptance criterion is :.: :; 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are :.: :; 0.60 La for the Type B and Type C tests and :.: :; 0. 75 La for Type A tests.
| |
| The provisions of SR 3.0.2 do not apply to test frequencies specified in the Primary Containment Leakage Rate Testing Program.
| |
| The provisions of SR 3.0.3 are applicable to the Primary Containment Leakage Rate Testing Program.
| |
| 5.5.14 Control Room Envelope Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensure that CRE habitability is maintained such that, with an
| |
| ,(continl!ed)
| |
| RIVER BEND 5.0-16 Amendment No. 81 84 95 131132 150 154 155, 191,
| |
| <Split 5.5.13 and move portion of 5.5. 13 and 5.5.14 to Page 5.0-i6a>
| |
| | |
| Insert 5.5.12 Surveillance Frequanc1,: Control F?.r.ooram This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met. *
| |
| : a. Surveillance Frequency Control Prograrn shall contain a list of Frequencies o'f those Surveillance Requirements for which the Frequency ls controlled by the program.
| |
| : b. Changes to the Frequencies listed in fr1e Sunrel!!ance Frequency Control Program sha!I made in accordance with f\JEi 04--10. "Risk-Informed Method for Controi o"f Surveillance Frequencies," Revision 1.
| |
| a:-c. The provisions of Surveillance Requirements 3.0.2 ancl 3.0.3 are app!icabie to the Frequencies established in the Surveillance Frequency Control Program.
| |
| I I
| |
| I *
| |
| | |
| < Move 5.5.14.d, e, and f to new Page 5.0-16b> ims and Manuals 5.5 in accordance with the Surveillance Frequency Control Program 5.5.14 Control Room Envelope Habitabilitv Program (continued)
| |
| OPERABLE Control Room Fresh Air (CRFA) System, CRE occupants can control the reactor safely under normal conditions and maintain it in a safe.
| |
| condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (OBA) conditions without personnel receiving radiation exposures in excess of 5 rem total effective dose equivalent (TEDE) for the duration of the accident. The program shall include the following elements:
| |
| .a. The definition of the CRE and the CRE boundary.
| |
| : b. Requirements for maintaining the CRE boundary, in its design condition including configuration control and preventive maintenance.
| |
| .)
| |
| : c. Requirements for (i) determining the unfiltered air inleakage past the CRE boundary into the CRE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulate~ Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and, (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0, except that testing specified at a frequency of 18 months is required at a frequency--to*f~2~4-1m-tteottnt1:t-hP.::iS,.<11.1-------------1 5.5.14 Control Room Envelope Habitabilit~m (continued)
| |
| : d. Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation by one subsystem of the CRFA System, operating at the flow rate required by the VFTP, at a Frequency of 24 months on a - - - ~
| |
| STAGGERED TEST BASIS. The results shall be trended and used as part of th~ 24 month assessment of the CRE boundary.---------.
| |
| : e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c.
| |
| The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of OBA consequences. Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the.licensing basis.
| |
| : f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.
| |
| * RIVER BEND 5.0-16a Amendment No. 154, 168, assessment specified in 5.5.14.c (ii)
| |
| | |
| Attachment 4 RBG-47799 Revised Technical Specification Pages
| |
| /
| |
| | |
| Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Determine the position of eac_h control rod. In accordance with the Surveillance Frequency Control Program SR 3.1.3.2 DELETED SR 3.1.3.3 ---------------------------N OT E----------------~---------------
| |
| Not required to be performed until 31 days after the control rod is withdrawn and THERMAL POWER is greater than the LPSP of the RPCS.
| |
| Insert each withdrawn control rod at least one notch. In accordance with the Surveillance Frequency Control Program SR 3.1.3.4 Verify each control rod scram time from fully In accordance with withdrawn to notch position 13 is :,; 7 seconds. SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4 (continued)
| |
| RIVER BEND 3.1-9 Amendment No. 84, 4e4,
| |
| | |
| Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS
| |
| ---------------------------------------------------------N OT E-- *---------------------------------------------------------
| |
| During single control rod scram time Surveillances, the control rod drive (CRD) pumps shall be isolated from the associated scram accumulator.
| |
| SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify each control rod scram time is within the limits Prior to exceeding of Table 3.1.4-1 with reactor steam dome pressure 40% RTP after 2 950 psig. each reactor shutdown 2 120 days SR 3.1.4.2 -** Verify, for a representative sample, each tested In accordance with control rod scram time is within the limits of the Surveillance Table 3.1.4-1 with reactor steam dome pressure Frequency Control 2 950 psig. Program SR 3.1.4.3 Verify each affected control rod scram time is within Prior to declaring the limits of Table 3.1.4-1 with any reactor steam control rod dome pressure. OPERABLE after work on control rod or CRD System that could affect scram time (continued)
| |
| RIVER BEND 3.1-12 Amendment No. 81 126, ea,
| |
| | |
| Control Rod Scram Accumulators 3*.1.5 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME C.
| |
| )
| |
| (continued) C.2 Declare the associated 1 hour control rod inoperable.
| |
| D. Required Action and D.1 ----------NOTE-----------
| |
| associated Completion Not applicable if all Time of Required Action inoperable control rod B.1 or C.1 not met. scram accumulators are associated with fully inserted control ~ods.
| |
| Place the reactor mode
| |
| \ switch in the shutdown Immediately position.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each control rod scram accumulator pressure In accordance with is :2:: 1540 psig. the Surveillance Frequency Control Program RIVER BEND 3.1-17 Amendment No. 84, 444,
| |
| | |
| Control Rod Pattern 3.1,6 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME B. Nine or more OPERABLE B.1 ----------NO TE---------
| |
| control rods not in Affected control rods compliance with BPWS. may be bypassed in RAGS in accordance with SR 3.3.2.1.9 for insertion only.
| |
| Suspend withdrawal of Immediately control rods.
| |
| B.2 Place the reactor mode 1 hour switch in the shutdown position.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify all OPERABLE control rods comply with In accordance with BPWS. the Surveillance Frequency Control Program RIVER BEND 3.1-19 Amendment No. 84-,
| |
| | |
| SLC System 3.1-7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 -----------------------------NO TE-----------------------------
| |
| T he minimum required available solution volume is determined by the performance of SR 3.1.7.5.
| |
| Verify available volume of sodium pentaborate In accordance with solution is greater than or equal to the minimum the Surveillance required available solution volume. Frequency Control Program SR 3.1.7.2 Verify temperature of sodium pentaborate In accordance with solution is~ 45°F. the Surveillance Frequency Control Program SR 3.1.7.3 -------------. --------------NOTE---------------------------------
| |
| S odium Pentaborate Concentration (C), in weight percent, is determined by the performance of SR 3.1.7.5. Boron-10 enrichment (E), in atom percent, is determined by the performance of SR 3.1.7.9.
| |
| Verify that the SLC System satisfies the following In accordance with equation: the Surveillance Frequency Control (C)(E) ~ 570 Program SR 3.1.7.4 Verify continuity of explosive charge. In accordance with the Surveillance Fr_equency Control Program (continued)
| |
| RIVER BEND 3.1-21 Amendment No. ~. 444,
| |
| | |
| SLC System 3.1.7 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.1.7.5 Verify the available weight of Boron-10 is ~ 143 lbs, In accordance with and the percent weight concentration of sodium the Surveillance pentaborate in solution is '.S; 9.5% by weight, and Frequency Control*
| |
| determine the minimum required available solution Program volume.
| |
| * Once within 24 hours after water or boron is added to solution Once within 24 hours after solution temperature is restored to ~ 45°F SR 3.1.7.6 Verify each SLC subsystem manual, power operated, In accordance with and automatic valve in the flow path that is not the Surveillance locked, sealed, or otherwise secured in position, is in Frequency Control the correct position, or can be aligned to the correct Program position.
| |
| SR 3.1.7.7 Verify each pump develops a flow rate ~ 41.2 gpm at In accordance with a discharge pressure ~ 1250 psig. the lnservice Testing Program SR 3.1.7.8 Verify flow through one SLC subsystem from pump
| |
| * In accordance with into reactor pressure vessel. the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.1-22 Amendment No. 81 114,488,
| |
| | |
| SDV Vent and Drain Valves 3.1.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 ---------------------------NOTE-----------------* ---------------
| |
| Not required to be met on vent and drain. valves closed during performance of SR 3.1.8.2.
| |
| Verify each SDV vent and drain valve is open. In accordance with the Surveillance Frequency Control Program SR 3.1.8.2 Cycle each SDV vent and drain valve to the fully In accordance with closed and fully open position.
| |
| * the Surveillance Frequency Control Program*
| |
| SR 3.1.8.3 Verify each SDV vent and drain valve: In accordance with the Surveillance
| |
| : a. Closes in:,;; 30 seconds after receipt of an Frequency Control actual or simulated scram signal; and Program
| |
| : b. Opens when the actual or simulated scram signal is reset.
| |
| RIVER BEND 3.1-25 Amendment No. ~. eS,
| |
| | |
| APLHGR 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)
| |
| LCO 3.2.1 All APLHGRs shall be less than or equal to the limits specified in the COLR.
| |
| APPLICABILITY: THERMAL POWER~ 23.8% RTP.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any APLHGR not within A.1 Restore APLHGR(s) to within 2 hours limits. limits.
| |
| : 8. Required Action and 8.1 Reduce THERMAL POWER 4 hours associated Completion to< 23.8% RTP.
| |
| Time not met.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify all APLHGRs are less than or equal to the Once within limits specified in the COLR. 12 hours after
| |
| ~ 23.8% RTP In accordance with the Surveillance Frequency Control Program j
| |
| RIVER BEND 3.2-1 Amendment No. M, 444,
| |
| | |
| MCPR 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)
| |
| LCO 3.2.2 All* MCPRs shall be greater than or equal to the MCPR operating limits specified in the COLR APPLICABILITY: THERMAL POWER~ 23.8% RTP.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any MCPR not within A.1 Restore MCPR(s) to within 2 hours limits. limits.
| |
| B. Required Action and B.1 Reduce THERMAL POWER 4 hours associated Completion to < 23.8% RTP.
| |
| Time not met.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify all MCPRs are greater than or equal to the Once within limits specified in the COLR. 12 hours after
| |
| ~ 23.8% RTP In accordance with the Surveillance Frequency Control Program RIVER BEND 3.2-2 J Amendment No. 84, 444, I
| |
| | |
| LHGR 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 LINEAR HEAT GENERATION RATE (LHGR)
| |
| LCO 3.2.3 All LHGRs shall be less than or equal to the limits specified in the COLR.
| |
| * APPLICABILITY: THERMAL POWER 2 23.8% RTP.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any LHGR not within limits. A.1 Restore LHGR(s) to within 2 hours limits.
| |
| B. Required Action and B.1 Reduce THERMAL POWER 4 hours associated Completion to < 23.8% RTP.
| |
| Time not met.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify all LHGRs are less than or equal to the limits Once within specified in the COLR. 12 hours after 223.8% RTP In accordance with the Surveillance Frequency Control Program RIVER BEND 3.2-3 Amendment No. 84-, 444,
| |
| | |
| FCBB 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 ---------------------------NOTE ----------------------------------
| |
| Not required to be performed until 15 minutes after entry into the Restricted Region if entry was the result of an unexpected transient.
| |
| Verify FCBB :s; 1.0. In accordance with the Surveillance Frequency Control Program Once within 15 minutes following unexpected transient RIVER BEND 3.2-6 Amendment No. 400,
| |
| | |
| RPS Instrumentation 3.3.1.1 SURVEILLANCE Rl=QUIREMENTS
| |
| ----------------------------------------------------------NOTES---------------------------------------------------------
| |
| : 1. Refer to Table 3.3.1.1-1 to determine ~hich SRs apply for each RPS Function.
| |
| : 2. yvhen a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains RPS trip capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.2 -----------------------------N OT E----------------------------
| |
| N ot required to be performed until 12 hours after THERMAL POWER~ 23.8% RTP.
| |
| Verify the absolute difference between the average In accordance power range monitor (APRM) channels and the with the calculated power::;; 2% RTPCa>. Surveillance Frequency Control Program SR 3.3.1.1.3 Adjust the flow control trip reference card to Once within conform to reactor flowCbl. 7 days after reaching equilibrium conditions following refueling outage.
| |
| (a) For a period of 30 days beginning with uprate COLR implementation and corresponding plant monitoring computer data bank changes the difference between the average pow~r range monitor (APRM) channels and the calculated power rr1ust be within -2% RTP to
| |
| +7% RTP.
| |
| (b) Within 30 days of uprate COLR implementation and corresponding plant monitoring computer data bank changes the flow control trip reference card will be verified to conform to reactor flow in accordance with the uprated COLR.
| |
| (continued)
| |
| RIVER BEND 3.3-3 A.mendment No. 81 100 106, 114,
| |
| | |
| RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.3.1.1.4 ------------------------------N OT E----------------------------
| |
| N ot required to be performed when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2.
| |
| Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.5 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.6 Verify the source range monitor (SRM) and Prior to intermediate range monitor (IRM) channels overlap. withdrawing SRMs from the fully inserted position SR 3.3.1.1.7 ------------------------------NOTE----------------------------
| |
| 0 n Iy required to be met during entry into MODE 2 from MODE 1.
| |
| Verify the IRM and APRM channels overlap. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.8 Calibrate the local power range monitors. In accordance with the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.3-5 Amendment No. 81106114, 168,
| |
| | |
| RPS Instrumentation
| |
| !
| |
| * 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.3.1.1.9 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.10 Calibrate the trip units. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.11 -------------------------------NOTES-------------------------- .
| |
| : 1. Neutron detectors and flow reference transmitters are excluded.
| |
| : 2. For Function 2,a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2.
| |
| : 3. For Function 2.b. the digital components of the flow control trip reference cards are excluded.
| |
| Perform CHANNEL CALIBRATION. , In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.12 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.3-5 Amendment No. 81106114, 168,
| |
| | |
| RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS, (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.3.1.1.13 ---------------------------------NOTES------------------------
| |
| : 1. Neutron detectors are excluded.
| |
| : 2. . For IRMs, not required to be performed when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2.
| |
| Perform CHANNEL CALIBRATION. In accordance with the Surveillance FrequeQCY Control Program SR 3.3.1.1.14 Verify the APRM Flow Biased Simulated Thermal In accordance Power-High time constant is within the limits with the specified in the COLR. Surveillance Frequency Control Program SR 3.3.1.1.15 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.16 Verify Turbine Stop Valve Closure and Turbine In accordance Control Valve Fast Closure Trip Oil Pressure-Low with the Functions are not bypassed when THERMAL Surveillance POWER is :::c: 40% RTP. Frequency Control Program SR 3.3.1.1.17 Calibrate the flow reference transmitters. In accordance with the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.3-6 Amendment No. 81 106 114, 168,
| |
| | |
| RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.3.1.1.18 ---------------------------NOTES------------------------------
| |
| : 1. Neutron detectors are excluded.
| |
| : 2. For Functions 3, 4, and 5 in Table 3.3.1.1-1, the channel sensors are excluded.
| |
| Verify the RPS RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-6a Amendment No.
| |
| | |
| SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS
| |
| -------------------------------------------------NOTE---------------------------------------------------------------
| |
| Refer to Table 3.3.1.2-1 to determine which SRs apply for each applicable MODE or other specified conditions.
| |
| SURVEILLANCE FREQUENCY SR 3.3.1.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2.2 ---------------------------NOTES-----------------------------
| |
| : 1. Only required to be met during CORE ALTERATIONS.
| |
| : 2. One SRM may be used to satisfy more than one of the following.
| |
| \
| |
| Verify a_n OPERABLE SRM detector is located in: In accordance with the Surveillance
| |
| : a. The fueled region; Frequency Control Program
| |
| : b. The core quadrant where CORE ALTERATIONS are being performed when 1 the associated SRM is included in the fueled region; and
| |
| : c. A core quadrant adjacent to where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region.
| |
| SR 3.3.1.2.3 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.3-12 Amendment No. 84-,
| |
| | |
| SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS (continued)
| |
| ' SURVEILLANCE FREQUENCY SR 3.3.1.2.4 ------------- .--------------NOTE------------------------------
| |
| N ot required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant.
| |
| Verify count rate is: In accordance with the Surveillance
| |
| : a. ::::: 3.0 cps, or Frequency Control Program
| |
| : b. ::::: 0.7 cps with a signal to noise ratio::::: 2:1.
| |
| SR 3.3.1.2.5 ---------------------------N OT E-------------------------------
| |
| N ot required to be performed until 12 hours after IRMs on Range 2 or below.
| |
| Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2.6 ------------------------NOTES--------------------------------
| |
| : 1. Neutron detectors are excluded.
| |
| : 2. Not required to be performed until 12 hours after IRMs on Range 2 or'below.
| |
| Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-13 Amendment No. 81, 168,
| |
| | |
| PBDS 3.3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.3.1 Verify each OPERABLE channel of PBDS In accordance with instrumentation not in Hi-Hi DR Alarm. the Surveillance Frequency Control Program SR 3.3.1.3.2 Perform CHANNEL CHECK. In accordance with the Surveillancra Frequency Control Program SR 3.3.1.3.3 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control
| |
| * Program RIVER BEND 3.3-14c Amendment No. 400,
| |
| | |
| (
| |
| Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS
| |
| ------------------------------- *-------------------NOTES----------------------------------------------------------------
| |
| : 1. Refer to Table 3.3.2.1-1 to determine which SRs apply for each Control Rod Block Function.
| |
| : 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains control rod block capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.2.1.1 --------------------------NOTE------ *-------------------------
| |
| Not required to be performed until 1 hour after THERMAL POWER is greater than the RWL high power setpoint (HPSP).
| |
| Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.2 --------------------------N OT E---------- *---------------------
| |
| Not required to be performed until 1 hour after THERMAL POWER is > 35% RTP and less than or equal to the RWL HPSP.
| |
| Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.3 ---------- *------------------NOTE-----------------------------
| |
| N ot required to be performed until 1 hour after any control rod is withdrawn in MODE 2.
| |
| Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.3-16 Amendment No. 84,
| |
| | |
| Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY
| |
| \
| |
| SR 3.3.2.1.4 ----------------------------NOTE------------------------------
| |
| Not required to be performed until 1 hour after THERMAL POWER is ::; 10% RTP in MODE 1.
| |
| Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.5 Calibrate the low power setpoint trip units. The In accordance with Allowable Value shall be > 10% RTP and the Surveillance
| |
| ::; 35% RTP. Frequency Control Program SR 3.3.2.1.6 Verify the RWL high power Function is not In accordance with bypassed when THERMAL POWER is the Surveillance
| |
| > 68.2% RTP. Frequency Control Program SR 3.3.2.1.7 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.8 ------------------------------NOTE----------------------------
| |
| N ot required to be performed until 1 hour after reactor mode switch is in the shutdown position.
| |
| Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.9 Verify the bypassing and movement of control rods Prior to and during required to be bypassed in Rod Action Control the movement of System (RACS) is in conformanc~ with applicable control rods analyses by a .second licensed operator or other bypassed in RACS qualified member of the technical staff.
| |
| RIVER BEND 3.3-17 Amendment No. 81 118, 168,
| |
| | |
| PAM Instrumentation 3.3.3.1 SURVEILLANCE REQUIREMENTS
| |
| ------------*---------------------------.-----------------NOTE-----------------------------------------------------------
| |
| These SRs apply to each Function in Table 3.3.3.1-1.
| |
| SURVEILLANCE FREQUENCY SR 3.3.3.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3,.3.3.1.2 Deleted SR 3.3.3.1.3 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-21 Amendment No. 81 142, 168,
| |
| | |
| Remote Shutdown System 3.3.3.2 3.3 INSTRUMENTATION 3.3.3.2 Remote Shutdown System LCO 3.3.3.2 The Remote Shutdown System Functions shall be OPERABLE.
| |
| APPLICABILITY: MODES 1 and 2.
| |
| ACTIONS
| |
| ----------------------------------------------------------NOTE-----------------------------------------------------------
| |
| Separate Condition entry is allowed for each Function.
| |
| CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required Function 30 days Functions inoperable. to OPERABLE status.
| |
| B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.3.2.1 Perform CHANNEL CHECK for each required In accordance with instrumentation channel that is normally energized. the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.3-23 Amendment No. 81, 156,
| |
| | |
| Remote Shutdown System
| |
| ,3.3.3.2 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.3.3.2.2 Verify each required control circuit and transfer In accordance with switch is capable of performing the intended the Surveillance functions. Frequency Control Program SR 3.3.3.2.3 Perform CHANNEL CALIBRATION for each In accordance with required instrumentation channel, except valve the Surveillance position instrumentation. Frequency Control Program RIVER BEND 3.3-24 Amendment No. 81, 168,
| |
| | |
| EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS
| |
| ---------------------------------------------------NOTE------------------------------------------------------------------
| |
| When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains EOC-RPT trip capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.4.1.1
| |
| * Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.4.1.2 Calibrate the trip units. In accordance with the Surveillance Frequency Control Program ,
| |
| SR 3.3.4.1.3 Perform CHANNEL CALIBRATION. The Allowable In accordance with Values shall be: the Surveillance Frequency Control
| |
| : a. TSV Closure:::; 7% closed. Program
| |
| , b. TCV Fast Closure, Trip Oil Pressure -
| |
| Low: :::c: 465 psig.
| |
| SR 3.3.4.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST, In accordance with including breaker actuation. the Surveillance Frequency Control Program SR 3.3.4.1.5 Verify TSV Closure and TCV Fast. Closure, Trip Oil " In accordance with Pressure - Low Functions are not bypassed when the Surveillance THERMAL POWER is :::c: 40% RTP. Frequency Control Program (continued)
| |
| RIVER BEND 3.3-27 Amendment No .. 81, 168,
| |
| | |
| EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.3.4.1.6 ---------------------------N OT E-------------------------------
| |
| 8 rea ke r interruption time may be assumed fro*m the most recent performance of SR 3.3.4.1.7.
| |
| Verify the EOC-RPT SYSTEM RESPONSE TIME In accordance with is within limits. the Surveillance Frequency Control Program SR 3.3.4.1. 7 Determine RPT breaker interruption time. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-28 Amendment No. 81, 168,
| |
| | |
| ATWS-RPT Instrumentation 3.3.4.2 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME
| |
| \
| |
| B. One Function with B.1 Restore ATWS-RPT trip 72 hours A TWS-RPT trip capability capability.
| |
| not maintained.
| |
| C. Both Functions with C.1 Restore A TWS-RPT trip 1 hour A TWS-RPT trip capability capability for one Function.
| |
| not maintained.
| |
| D. Required Action and D.1 Remove the associated 6 hours associated Completion recirculation pump from Time not met. service.
| |
| OR D.2 Be in MODE 2. 6 hours SURVEILLANCE REQUIREMENTS
| |
| -------------------------------------------------------NOTE-------------------------------------------------------------
| |
| When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains ATWS-RPT trip capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.4.2.1 Perform CHANNEL CHECK. In accordance with I
| |
| the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.3-30 Amendment No. 84,
| |
| | |
| A TWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE FREQUENCY SR 3.3.4.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.4.2.3 Calibrate the trip L!nits. In accordance with the Surveillance Frequency Control Program SR 3.3.4.2.4 Perform CHANNEL CALIBRATION. The Allowable In accordance with Values shall be: the Surveillance Frequency Control
| |
| : a. Reactor Vessel Water Level-Low Low, Program Level 2: ~-47inches; and
| |
| : b. Reactor Steam Dome Pressure-High:
| |
| :,:; 1165 psig.
| |
| SR 3.3.4.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST, In accordance with including breaker actuation. the Surveillance Frequency Control Program RIVER BEND* 3.3-31 Amendment No*: 81 114, 168,
| |
| | |
| ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS
| |
| ------------------------------------------------------------NOTES----------------------'--------------------------------
| |
| : 1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function.
| |
| : 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours for Functions 3.c, 3.f, 3.g, and 3.h; and (b) for up to 6 hours for Functions other than 3.c, 3.f, 3.g, and 3.h, provided the associated Function or the redundant Function maintains ECCS initiation capability.
| |
| SURVEILLANCE FREQUENCY
| |
| *SR 3.3.5.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.3 Calibrate the trip unit. In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.5 Perform CHANNEL CALIBRATION. In accordance with the Surveillance
| |
| ,I Frequency Control Program SR 3.3.5.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-38 Amendment No. 81, 168,
| |
| | |
| RCIC System Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS
| |
| ---------------------------------------------------NOTES--------------------------------------------------------------
| |
| : 1. Refer to Table 3.3.5.2-1 to determine which SRs apply for each RCIC Function.
| |
| : 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions) may be delayed as follows: (a) for up to 6 hours for Functions 2 and 5; and (b) for up to 6 hours for Functions 1, 3, and 4 provided the associated Function maintains RCIC initiation capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.3 - Calibrate the trip units. In accordance with the Surveillance
| |
| *Frequency Control Program SR 3.3.5.2.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Cootrol Program SR 3.3.5.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-46 Amendment No. 81, 168,
| |
| | |
| Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS
| |
| ---------------------------------------------------NOTES------------------------------------------------------------
| |
| : 1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Function.
| |
| : 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains isolation capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with
| |
| ' the Surveillance Frequency Control Program SR 3.3.6.1.3 Calibrate the trip unit. In accordance with the Surveillance Frequency Control I Program SR 3.3.6.1.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.5 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.3-52 Amendment No. 81, 168,
| |
| | |
| Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.3.6.1. 7 -----------------------------NOTE-----------------------------
| |
| C ha n neI sensors are excluded.
| |
| Verify the ISOLATION SYSTEM RESPONSE TIME In accordance with for the Main Steam Isolation Valves is within limits. the Surveillance Frequency Control Program RIVER BEND 3.3-52a Amendment No.
| |
| | |
| Secondary Containment and Fuel Building Isolation Instrumentation 3.3.6.2 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.1.2 Declare associated -, 1 hour isolation dampers inoperable.
| |
| C.2.1 Place the associated 1 hour ventilation subsystem in operation.
| |
| OR C.2.2 Declare associated 1 hour ventilation subsystem inoperable.
| |
| SURVEILLANCE REQUIREMENTS
| |
| -----------------------------------------------------NOTES------------------------------------------------------------
| |
| : 1. Refer to Table 3.3:6.2-1 to determ_ine which SRs apply for each Isolation Function.
| |
| : 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains secondary containment isolation capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.6.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.6.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.3-59 Amendment No. 81, 113,
| |
| | |
| Secondary Containment and Fuel Building Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.3.6.2.3 Calibrate the trip unit. In accordance with the Surveillance Frequency Control Program SR 3.3.6.. 2.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-60 Amendment No. 81113, 168,
| |
| | |
| Containment Unit Cooler System Instrumentation 3.3.6.3 SURVEILLANCE REQUIREMENTS
| |
| -------------------------------------------------------N OTES-----------------------------------------------------------
| |
| : 1. Refer to Table 3.3.6.3.-1 to determine which SRs apply for each Containment Unit Cooler System Function.
| |
| : 2. When a channel is placed in an inoperable status solely for performance of required.
| |
| * Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains containment unit cooler initiation capability.
| |
| SURVEILLANCE FREQUENCY SR 3.3.6.3.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.6.3.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.3.3 Calibrate the trip unit. In accordance with the Surveillance Frequency Control Program SR 3.3.6.3.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.3.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-64 Amendment No. 81, 168,
| |
| | |
| Relief and LLS Instrumentation 3.3.6.4 SURVEILLANCE REQUIREMENTS
| |
| ------------------------------------------------------NOTE---------------------------------------------------------------
| |
| When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains LLS or relief initiation capability, as applicable.
| |
| SURVEILLANCE FREQUENCY SR 3.3.6.4.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.4.2 Calibrate the trip unit. In accordance with the Surveillance Frequency Control Program SR 3.3.6.4.3 Perform CHANNEL CALIBRATION. The Allowable In accordance with Values shall be: the Surveillance Frequency Control
| |
| : a. Relief Function Program Low: 1133 +/- 15 psig Medium: 1143 +/- 15 psig High: 1153 +/- 15 psig
| |
| : b. LLS Function Low open: 1063 +/- 15 psig close: 956 +/- 15 psig Medium open: 1103 +/- 15 psig close: 966 +/- 15 psig High open: 1143 +/- 15 psig close: 976 +/- 15 psig SR 3.3.6.4.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control ~
| |
| Program RIVER BEND 3.3-67 Amendment No. 81 114, 168,
| |
| | |
| CRFA System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS
| |
| ------------------------------------------------------NOTES-------------------------------------------------------------
| |
| : 1. Refer to Table 3.3.7.1-1 to determine which SRs apply for each Function.
| |
| : 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains CRFA initiation capabiHty.
| |
| SURVEILLANCE FREQUENCY SR 3.3.7.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.3 Calibrate the trip units. In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-70 Amendment No. 81, 168,
| |
| | |
| LOP Instrumentation 3.3.8.1 SURVEILLANCE REQUIREMENTS
| |
| ---------------------------------------------------------NOTES----------------------------------------------------------
| |
| : 1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function.
| |
| : 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 2 hours provided the associated Function maintains DG initiation capability. -
| |
| SURVEILLANCE FREQUENCY SR 3.3.8.1.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.3 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.8.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-73 Amendment No. 81 168, 179,
| |
| | |
| RPS Electric Power Monitoring 3.3.8.2 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Initiate action to fully insert all Immediately associated Completion insertable control rods in core Time of Condition A or B cells containing one or more not met in MODE 4 or 5 fuel assemblies.
| |
| with any control rod withdrawn from a core cell containing one or more fuel assemblies.
| |
| * SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.2.1 --------------------------NOTE-------------------------------
| |
| Only required to be performed prior to entering MODE 2 or 3 from MODE 4, when in MODE 4 for
| |
| ~ 24 hours.
| |
| Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.3-76 Amendment No. ~.
| |
| | |
| RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.3.8.2.2 Perform CHANNEL CALIBRATION. The Allowable In accordance with Values shall be: the Surveillance Frequency Control
| |
| : a. Overvoltage Program Bus A :s; 132 V Bus B :s; 132 V
| |
| : b. Undervoltage Bus A 2 115 V Bus B 2115 V
| |
| : c. Underfrequency (with time delay set to :s; 4.0 seconds.)
| |
| Bus A 2 57 Hz Bus B 2 57 Hz SR '3.3.8.2.3 Perform a system functional test. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-77 Amendment No. 81, 168,
| |
| | |
| Recirculation Loops Operating 3.4.1 ACTIONS (continued)
| |
| CONDITION
| |
| )
| |
| REQUIRED ACTION COMPLETION TIME C. Requirements 8.3, 8.4, or C.1 Satisfy the requirements of 24 hours 8.5 of the LCO not met. the LCO.
| |
| D. Required actions and D.1 Be in Mode 3. 12 hours associated completion times of conditions A, B, or C not met.
| |
| No recirculaUon loops in operation.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 ----------------------) -----NOTE------------ *-------------------
| |
| Not required to be performed until 24 hours after both recirculation loops are in operation.
| |
| Verify recirculation loop jet pump flow mismatch with In accordance with both recirculation loops in operation is: the Surveillance Frequency Control
| |
| : a. :s; 10% of rated core flow when operating at Program
| |
| < 70% of rated core flow; and
| |
| : b. :s; 5% of rated core flow when operating at
| |
| ~ 70% of rated core flow.
| |
| RIVER BEND 3.4-2 Amendment No. 84 97, 106,
| |
| | |
| FCVs
| |
| *3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3A.2 Flow Control Valves (FCVs)
| |
| LCO 3.4.2 A recirculation loop FCV shall be OPERABLE in each operating.
| |
| recirculation loop.
| |
| APPLICABILITY: . MODES 1 and 2.
| |
| ACTIONS
| |
| ------------------------------------------------------NOTE--------------------------------------------------------------
| |
| Sepa rate Condition entry is allowed for each FCV.
| |
| CONDITION REQUIRED ACTION COMPLETION TIME A. One or two required FCVs A.1 Lock up the FCV. 4 hours inoperable. ,
| |
| B. Required Action and 8.1 Be in MODE 3. 12 hours associated Completion Time not met.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 Verify each FCV fails "as is" on loss of hydraulic In accordance with pressure at the hydraulic unit. the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.4-6 Amendment No. 81, 168,
| |
| | |
| FCVs 3.4.2 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.4.2.2 Verify average rate of each FCV movement is: In accordance with I
| |
| the Surveillance
| |
| : a. s 11% of stroke per second for opening; and Frequency Control Program
| |
| : b. s 11 % of stroke per second for closing.
| |
| RIVER BEND 3.4-7 Amendment No. 81, 168,
| |
| | |
| Jet Pumps 3.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 ------------------------------NOTES-----------------------------
| |
| : 1. Not required to be performed until 4 hours after associated recirculation loop is in operation.
| |
| : 2. Not required to be performed until 24 hours after> 23.8% RTP.
| |
| Verify at least two of the following criteria In accordance with (a, b, and c) are satisfied for each operating the Surveillance recirculation loop: Frequency Control Program
| |
| : a. Recirculation loop drive flow versus flow control valve position differs by :.:; 10% from established patterns.
| |
| : b. Recirculation loop drive flow versus total core flow differs by:.:; 10% from established patterns.
| |
| : c. Each jet pump diffuser to lower plenum differential pressure differs by:.:; 20% from established patterns, or each jet pump flow differs by :.:; 10% from established patterns.
| |
| RIVER BEND 3.4-9 Amendment No. 81,114,
| |
| | |
| S/RVs 3.4.4 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.4.4.2 ------------------------------NO TE-------------------------------
| |
| Va Ive actuation may be excluded.
| |
| Verify each required relief function S/RV actuates on In accordance with an actual or simulated automatic initiation signal. the Surveillance Frequency Control Program r
| |
| SR 3.4.4.3 -----------------------. ------NOTE-------------------------------
| |
| Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test.
| |
| Verify each required S/RV relief mode actuator In accordance with strokes when manually actuated. the lnservice Testing Program on a STAGGERED TEST BASIS for each valve solenoid RIVER BEND 3.4-11 Amendment No. 81 130, 168,
| |
| | |
| RCS Operational LEAKAGE 3.4.5 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time of Condition A or B AND not met.
| |
| C.2 Be in MODE4. 36 hours Pressure boundary LEAKAGE exists.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify RCS unidentified LEAKAGE, total LEAKAGE, In accordance with and unidentified LEAKAGE increase are within limits. the Surveillance Frequency Control Program RIVER BEND 3.4-13 Amendment No. 84,
| |
| | |
| I RCS Leakage Detection Instrumentation 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Perform CHANNEL CHECK of required drywell In accordance with atmospheric monitoring system. the Surveillance Frequency Control Program SR 3.4.7.2 Perform CHANNEL FUNCTIONAL TEST of required In accordance with leakage detection instrumentation. the Surveillance Frequency Control Program SR 3.4.7.3 Perform CHANNEL CALIBRATION of required In accordance with leakage detection instrumentation. the Surveillance Frequency Control Program RIVER BEND 3.4-19 Amendment No. 81, 168,
| |
| | |
| RCS Specific Activity 3.4.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 ----------------------------NOTE---------------------------------
| |
| Only required to be performed in MODE 1.
| |
| Verify reactor coolant DOSE EQUIVALENT 1-131 In accordance with specific activity is s 0.2 µCi/gm. the Surveillance Frequency Control Program RIVER BEND 3.4-21 Amendment No. ~.
| |
| | |
| RHR Shutdown Cooling System - Hot Shutdown 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 ----------------------------NOTE---------------------------------
| |
| Not required to be met until 2 hours after reactor steam dome pressure is less th,~n the RHR cut in permissive pressure.
| |
| Verify one RHR shutdown cooling subsystem or In accordance with recirculation pump is operating. the Surveillance Frequency Control Program SR 3.4.9.2 ----------------------------NOTE---------------------------------
| |
| Not required to be performed until 12 hours after reactor steam dome pressure is less than the RHR cut in permissive pressure.
| |
| Verify RHR shutdown cooling subsystem locations In accordance with susceptible to gas accumulation are sufficiently filled the Surveillance with water. Frequency Control Program RIVER BEND 3.4-24 Amendment No. 81, 188,
| |
| | |
| RHR Shutdown Cooling System - Cold Shutdown 3.4.10 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPELETION TIME B. No RHR shutdown cooling B.1 Verify reactor coolant 1 hour from discovery subsystem in operation. circulating by an of no reactor coolant alternate method. circulation No recirculation pump in operation. Once per 12 hours thereafter B.2 Monitor reactor coolant Once per hour temperature and pressure.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify one RHR shutdown cooling subsystem or In accordance with
| |
| * recirculation pump is operating. the Surveillance Frequency Control Program SR 3.4.10.2 Verify RHR shutdown cooling subsystem locations In accordance with susceptible to gas accumulation are sufficiently filled the Surveillance with water. Frequency Control Program RIVER BEND Amendment No. 81, 188,
| |
| | |
| RCS PIT Limits 3.4.11 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME C. -------------NOTE------------- C.1 Initiate action to restore Immediately Req uired Action C.2 shall parameter(s) to within limits.
| |
| be completed if this Condition is entered.
| |
| C.2 Determine RCS is acceptable Prior to entering Requirements of the LCO for operation. MODE 2 or 3 not met in other than MODES 1, 2, and 3.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY .
| |
| SR 3.4.11.1 -----------------------------NOTE--------------------------------
| |
| 0 nly required to be performed during RCS heatup and cooldown operations, and RCS inservice leak and hydrostatic testing.
| |
| Verify: In accordance with the. Surveillance
| |
| : a. RCS pressure and RCS temperature are within Frequency Control the limits of Figure 3.4.11-1, and Program
| |
| : b. RCS heatup and cooldown rates are:;:; 100°F in any one hour period for core not critical and core critical limits.
| |
| : c. RCS heatup and cooldown rates are :;:; 20°F in any one hour period for inservice leak and hydrostatic testing limits.
| |
| (continued)
| |
| RIVER BEND 3.4-28 Amendment No. 81,114,
| |
| | |
| RCS PIT Limits 3.4.11 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.4.11.5 ----------------------------NOTE---------------* -----------------
| |
| Only required to be performed when tensioning the reactor vessel head bolting studs.
| |
| Verify reactor vessel flange and head flange In accordance with temperatures are ~ 70°F. the Surveillance Frequency Control Program SR 3.4.11.6 ----------------------------NOTE---------------------------------
| |
| Not required to be performed until 30 minutes after RCS temperature ::;; 80°F in MODE 4.
| |
| Verify reactor vessel flange and head flange In accordance with temperatures are~ 70°F. the Surveillance Frequency Control Program SR 3.4.11.7 ----------------------------NOTE---------------------------------
| |
| Not required to be performed until 12 hours after RCS temperature ::;; 100°F in MODE 4.
| |
| Verify reactor vessel flange and head flange In accordance with temperatures are~ 70°F. the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.4-30 Amendment No. 34-,
| |
| | |
| Reactor Steam Dome Pressure 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Reactor Steam Dome Pressure LCO 3.4.12 The reactor steam dome pressure shall be s 1075 psig.
| |
| APPLICABILITY: MODES 1 and 2.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor steam dome A.1 Restore reactor steam dome 15 minutes pressure not within limit. pressure to within limit.
| |
| B. Required Action and 8.1 Be in MODE 3. 12 hours associated Completion Time not met.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify reactor steam dome pressure is s 1075 psig. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.4-33 Amendment No. 81, 114,
| |
| | |
| ECCS- Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray subsystem, In accordance with locations susceptible to gas accumulation are the Surveillance sufficiently filled with water. Frequency Control Program SR 3.5.1.2 -----------------------------NOTES--------------------------------
| |
| : 1. Low pressure coolant jnjection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the residual heat removal cut in permissive pressure in MODE 3, if capable of being manually realigned and not otherwise inoperable.
| |
| : 2. Not required to be met for system vent flow paths opened under administrative controL Verify each ECCS injection/spray subsystem manual, In accordance with power operated, and automatic valve in the flow path, the Surveillance that is not locked, sealed, or otherwise secured in Frequency Control position, is in the correct position. Program SR 3.5.1.3 Verify ADS accumulator supply pressure is In accordance with
| |
| ~ 131 psig. the Surveillance Frequency Control Program SR 3.5.1:4 Verify each ECCS pump develops the specified flow . In accordance with
| |
| . rate with the specified pump differential pressure. the lnservice Testing Program PUMP DIFFERENTIAL SYSTEM FLOW RATE PRESSURE LPCS . ~ 5010 gpm ~ 282 psid LPCI ~ 5050 gpm ~ 102 psid HPCS ~ 5010 gpm ~ 415 psid (continued)
| |
| RIVER BEND 3.5-4
| |
| * Amendment No. 81, 188,
| |
| | |
| r ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.5.1.5 -----------------------------NOTE----------------------------. ---
| |
| \\
| |
| Vessel injection/spray may be excluded.
| |
| Verify each ECCS injection/spray subsystem actuates In accordance with on an actual or simulated automatic initiation signal. the Surveillance Frequency Control Program SR 3.5.1.6 -------------------------------NOTE------------------------------
| |
| Va Ive actuation may be excluded.
| |
| Verify the ADS actuates on an actual or simulated In accordance with automatic initiation signal. the Surveillance Frequency Control
| |
| * Program SR 3.5.1.7 ------------------ .-----------NOTE-------------------------------
| |
| N ot required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test.
| |
| Verify each ADS valve relief mode actuator strokes In accordance with when manually actuated. the lnservice Testing Program on a STAGGERED TEST BASIS for each valve solenoid (continued)
| |
| RIVER BEND 3.5-5 Amendment No. 81 130, 168,
| |
| | |
| ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS continued)
| |
| SURVEILLANCE FREQUENCY SR 3.5.1.8. -------------------------------NOTE--------------------'---------
| |
| ECCS actuation instrumentation is excluded.
| |
| Verify the ECCS RESPONSE TIME for each ECCS In accordance with injection/spray subsystem is within limits. the Surveillance Frequency Control Program RIVER BEND 3.5-5a Amendment No.
| |
| I I
| |
| | |
| ECCS- Shutdown 3.5.2 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action C.2 and D.1
| |
| * Initiate action to restore Immediately associated Completion " primary containment to Time not met. OPERABLE status.
| |
| D.2 Initiate action to isolate Immediately required primary containment penetration flow paths.
| |
| AND D. 3 ------------NOTE-----------
| |
| Entry and exit_is permissible under administrative control.
| |
| Initiate action to close Immediately one door in each primary containment air lock.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify, for each required low pressure ECCS In accordance with injection/spray subsystem, the suppression pool the Surveillance water level is ;::,: 13 ft 3 inches. ' Frequency Control Program (continued)
| |
| RIVER BEND 3.5-7 Amendment No, 84,
| |
| | |
| ECCS- Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS* (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.5.2.2 Verify, for the required High Pressure Core Spray In accordance with (HPCS) System, the: the Suryeillance Frequency Control
| |
| : a. Suppression pool water level is ~ 13 ft 3 Program inches; or
| |
| : b. Condensate storage tank water level is ~ 11 ft 1 inch.
| |
| SR 3.5.2.3 Verify, for each required ECCS injection/spray In accordance with subsystem, locations susceptible to gas accumulation the Surveillance are sufficiently filled with water. Frequency Control Program SR 3.5.2.4 -------------------------------NOTES------------------------------
| |
| : 1. One low pressure coolant injection (LPCI) subsystem may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned and not otherwise inoperable.
| |
| : 2. Not required to be met for system vent flow paths opened under administrative control.
| |
| Verify each required ECCS injection/spray subsystem In accordance with manual, power operated, and automatic valve in the the Surveillance
| |
| * flow path, that is~not locked, sealed, or otherwise Frequency Control secured in position, is in the correct position. Program (continued)
| |
| RIVER BEND 3.5-8 Amendment No. 81, 188,
| |
| | |
| ECCS- Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS continued)
| |
| SURVEILLANCE FREQUENCY ,,
| |
| SR 3.5.2.5 Verify each required ECCS pump develops the In accordance with specified flow rate with the specified pump differential the Inservice pressure. Testing Program PUMP DIFFERENTIAL SYSTEM FLOW RATE* PRESSURE LPCS 2 5010 gpm 2 282 psid LPCI 2 5050 gpm 2102 psid HPCS 2 5010 gpm 2 415 psid SR 3.5.2.6 -------------- .. -------------NO TE--------------------------------
| |
| Ves se I injection/spray may be excluded.
| |
| Verify each required ECCS injection/spray subsystem In accordance with actuates on an actual or simulated automatic initiation the Surveillance signal. Frequency Control Program
| |
| /
| |
| RIVER BEND 3.5-9 Amendment No, 81, 168,
| |
| | |
| RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify the RCIC System locations susceptible to gas In accordance with accumulation are sufficiently filled with water. the Surveillance Frequency Control I
| |
| Program SR 3.5.3.2 -----------------------------NO TE-------------------------------.
| |
| Not required to be met for system vent flow paths opened under administrative control.
| |
| Verify each RCIO System manual, power operated, In accordance with and automatic valve in the flow path, that is not the Surveillance
| |
| * locked, sealed, or otherwise secured in position, is in Frequency Control the correct position. Program SR 3.5.3.3 -----------------------------NOTE--------------------------------
| |
| Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test.
| |
| Verify, with RCIC steam supply pressure :s; 1075 psig In accordance with and ~ 920 psig, the RCIC pump can develop a flow the Surveillance rate ~ 600 gpm against a system.head corresponding Frequency Control to reactor pressure. Program SR 3.5.3.4 -----------------------------NOTE-------------------------------.
| |
| Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test.
| |
| Verify, with RCIC steam supply pressure :,; 165 psig In accordance with and ~ 150 psig, the RCIC pump can develop a flow the Surveillance rate ~ 600 gpm against a system head corresponding Frequency Control to reactor pressure. Program (continued)
| |
| RIVER BEND 3.5-11 Amendment No. 81 114 168, 188,
| |
| | |
| RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.5.3.5 ------------------------------NOTE-------------------------------
| |
| Vesse I injection may be excluded.
| |
| Verify the RCIC System actuates on an actual or In accordance with simulated automatic initiation signal. the Surveillance Frequency Control Program RIVER BEND 3.5-12 Amendment No. 81, 168,
| |
| | |
| Primary Containment Air Locks 3.6.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.2.1 --------------------------N OTES-----------------------------
| |
| : 1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.
| |
| : 2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.1.
| |
| Perform required primary containment air lock leakage rate testing in accordance with the Primary In accordance with Containment Leakage Rate Testing Program. the Primary Containment Leakage Rate Testing Program SR 3.6.1.2.2 Verify primary containment air lock seal In accordance with air flask pressure is ;::,; 90 psig. the Surveillance Frequency Control Program SR 3.6.1.2.3 ----------------------------NOTE-----------------------------
| |
| 0 n ly required to be performed upon entry or exit through the primary containment air lock.
| |
| Verify only one door in the primary containment air In accordance with lock can be opened at a time. the Surveillance Frequency Control Program (continued)
| |
| \
| |
| I RIVER BEND 3.6-7 Amendment No. 81 84, 132,
| |
| | |
| Primary Containment Air Locks 3.6.1.2 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.1.2.4 Verify, from an initial pressure of In accordance with 90 psig, the primary containment air the Surveillance lock seal pneumatic system pressure does Frequency Control not decay at a rate equivalent to Program
| |
| > 1.50 psig for a period of 24 hours. J RIVER BEND 3.6-8 Amendment No. 81 132, 168,
| |
| | |
| PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.1 _ --------------------------N OTES-----------------------------
| |
| : 1. Only required to be met in MODES 1, 2, and 3.
| |
| : 2. Notrequired to be met when the 36 inch
| |
| - primary containment purge valves are open for pressure control, ALARA or air quality considerations for personnel entry. Also, not required to be rr;iet during Surveillances, or special testing on the purge system that requires the valves to be open.
| |
| : 3. If one Standby Gas Treatment (SGT) subsystem is in the primary containment purge flow path, both SGT subsystems must be OPERABLE. In addition only one SGT subsystem may be operating in the primary containment purge flow path.*
| |
| Verify each 36 inch primary containment purge In accordancewith valve is closed. the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.6-15 Amendment No. 84-, I
| |
| | |
| PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.1.3.2 ----------------------------N OTES---------------------------
| |
| : 1. Only required to be met in MODES 1, 2, and 3.
| |
| : 2. Valves and blind flanges in high radiation areas may be verified by use of administrative means.
| |
| : 3. Not required to be met for PCIVs that are open under administrative controls.
| |
| Verify each primary containment isolation manual In accordance with valve and blind flange that is located outside the Surveillance primary containment, drywell, and steam tunnel Frequency Control and is required to be closed during accident Program conditions is closed.
| |
| (continued)
| |
| RIVER BEND 3.6-16 Amendment No. 81, 116,
| |
| | |
| PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.1.3.4 \ Verify the isolation time of each power operated In accordance and each automatic PCIV, except MSIVs, is within with the lnservice limits. Testing Program SR 3.6.1.3.5 ----------------------------N OT E-----------------------------
| |
| 0 n Iy required to be met in MODES 1, 2, and 3.
| |
| Perform leakage rate testing for each primary In accordance with containment purge valve with resilient seals. the Primary Containment Leakage Rate Testing Program SR 3.6.1.3.6 Verify the isolation time of each MSIV is In accordance with the lnservice
| |
| ~ 3 seconds and :,:; 5 seconds. Testing Program SR 3.6.1.3. 7 Verify each automatic PCIV actuates to the In accordance with isolation position on an actual or simulated isolation the Surveillance signal. Frequency Control Program (continued)
| |
| RIVER BEND 3.6-17 Amendment No. 81 152, 168,
| |
| | |
| PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.1.3.8 Verify in-leakage rate of~ 340 scfh for each of the In accordance with following valve groups when tested at 11.5 psid for the Surveillance MS-PLCS valves. Frequency Control Program
| |
| : a. Division I MS-PLCS valves
| |
| : b. Division II MS-PLCS valves SR 3.6.1.3.9 ----------------------------NOTE-----------------------------
| |
| Only required to be met in MODES 1, 2, and 3.
| |
| Verify the combined leakage rate for all secondary In accordance with containment bypass leakage paths* is ~ 580,000 the Primary cc/hr when pressurized to;:;:: Pa. Containment Leakage Rate Testing Program (continued)
| |
| RIVER BEND 3.6-18 Amendment No. 81 84 98 132, 168,
| |
| | |
| Primary Containment Pressure 3.6.1.4 3.6 CONTAINMENT SYSTEMS 3.6.1.4 Primary Containment Pressure LCO 3.6.1.4 Primary containment pressure shall be~ -0.3 psig and :s; 0.3 psig.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore primary 1 hour pressure not within limits. containment pressure to '
| |
| within limits.
| |
| B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.4.1 Verify primary containment pressure is within limits. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-21 Amendment No. 34-,
| |
| | |
| Primary Containment Air Temperature 3.6.1.5 3.6 CONTAINMENT SYSTEMS 3.6.1.5 Primary Containment Air Temperature LCO 3.6.1.5 Primary containment average air temperature shall be:;; 90°F.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore primary 8 hours average air temperature containment average air not within limit. temperature to within limit.
| |
| B. Required Action and 8.1 Be in MODE 3. 12 hours associated Completion Time not met. AND 8.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.5.1 Verify primary containment average air temperature In accordance with is within limit. the Surveillance Frequency Control Program RIVER BEND 3.6-22 Amendment No. 84,
| |
| | |
| LLS Valves 3.6.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.6.1 ---------------------------NOTE------------------------------
| |
| N ot required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test.
| |
| Verify each LLS valve* relief mode actuator strokes In accordance with when manually actuated. the lnservice Testing Program on a STAGGERED TEST BASIS for each valve solenoid SR 3.6.1.6.2 ----------------------------NOTE-----------------------------
| |
| Va Ive actuation may be excluded.
| |
| Verify the LLS System actuates on an actual or In accordance with simulated automatic initiation signal. the Surveillance Frequency Control Program RIVER BEND 3.6-24 Amendment No. 81 130, 168,
| |
| | |
| Primary Containment Unit Coolers 3.6.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.7.1 Verify each required primary containment unit In accordance with cooler pressure relief and backdraft damper in the the Surveillance flow path that is not locked, sealed, or otherwise Frequency Control secured in position, is in the correct position. Program SR 3.6.1.7.2 Verify each required primary containment unit In accordance with cooler develops a flow rate of~ 50,000 cfm on the Surveillance recirculation flow through the unit cooler. Frequency Control Program SR 3.6.1.7.3 Verify each required primary containment unit In accordance with cooler actuates throughout its emergency operating the Surveillance sequence on an actual or simulated automatic Frequency Control initiation signal. Program RIVER BEND. 3.6-26 Amendment No. 81, 168,
| |
| | |
| MS-PLCS 3.6.1.9 3.6 CONTAINMENT SYSTEMS 3.6.1.9 Main Steam-Positive Leakage Control System (MS-PLCS)
| |
| LCO 3.6.1.9 Two MS-PLCS subsystems shall be OPERABLE.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One MS-PLCS subsystem inoperable.
| |
| . A.1 Restore MS-PLCS subsystem to 30 days OPERABLE status.
| |
| : 8. Two MS-PLCS 8.1 Restore one MS-PLCS 7 days subsystems inoperable. subsystem to OPERABLE status.
| |
| C. Required Action and C.1 ----------NOTE-----------
| |
| associated Completion LCO 3.0.4.a is not Time not met. applicable when I
| |
| entering MODE 3.
| |
| Be in MODE 3. 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.9.1 Verify air pressure in each associated PVLCS In accordance with subsystem is ~ 101 psig. the Surveillance Frequency Control Program ,
| |
| (continued)
| |
| RIVER BEND 3.6-29 Amendment No. 81 185,
| |
| | |
| MS-PLCS 3.6.1.9 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.1.9.2 Operate each PVLCS compressor 2 15 minutes. In accordance with the Surveillance Frequency Control Program SR 3.6.1.9.3 Perform a system functional test of each MS-PLCS In accordance with subsystem. the Surveillance Frequency Control Program RIVER BEND 3.6-30 Amendment No. 81, 168, i
| |
| | |
| Primary Containment-Shutdown 3.6.1.10
| |
| - SURVEILLANCE REQUIREMENTS SURVEILLANCE -- FREQUENCY SR 3.6.1.10.1 ---------------------------NOTE------------------------------
| |
| N ot required to be met for vent and drain line pathways_ provided the total calculated flow rate through open vent and drain pathways is :o; 70.2 cfm.
| |
| Verify each penetration flow path, required to be In accordance with closed during accident conditions, is closed. the Surveillance Frequency Control Program RIVER BEND 3.6-32 Amendment No. 84,
| |
| | |
| Suppression Pool Average Temperature 3.6.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1.1 Verify suppression pool average temperature is In accordance with within the applicable limits. - the Surveillance Frequency Control Program 5 minutes when performing testing that adds heat to the suppression pool r
| |
| RIVER BEND 3.6-35 Amendment No. 84,
| |
| (
| |
| | |
| Suppression Pool Water Level 3;6.2.2 3.6 CONTAINMENT SYSTEMS 3.6.2.2 Suppression Pool Water Level
| |
| "\
| |
| LCO 3.6.2.2 Suppression pool water level shall be ;:::: 19 ft 6 inches and :s; 20 ft O inches.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool water A.1 Restore suppression 2 hours level not within limits. pool water level to within limits.
| |
| B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.2.1 Verify suppression pool water level is within limits. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-36 Amendment No. ~.
| |
| | |
| RHR Suppression I
| |
| Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY
| |
| (
| |
| SR 3.6.2.3.1 Verify each RHR suppression pool cooling In accordance with subsystem m~nual, power operated, and automatic the Surveillance valve in the flow path that is not locked, sealed, or Frequency Control otherwise secured in position is in the correct Program position or can be aligned to the correct position.
| |
| SR 3.6.2.3.2 Verify RHR suppression pool cooling subsystem In accordance with locations susceptible to gas accumulation are the Surveillance sufficiently filled with water. Frequency Control Program SR 3.6.. 2.3.3 Verify each RHR pump develops a flow rate In accordance
| |
| ~ 5050 gpm through the associated heat with the lnservice exchangers to the suppression pool. Testing Program RIVER BEND 3.6-38 Amendment No. 81, 188, I
| |
| | |
| Primary Containment and Drywell Hydrogen lgniters 3.6.3.2 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time not met.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.2.1 Energize each primary containment and drywell In accordance with hydrogen igniter division and perform current the Surveillance versus voltage measurements to verify required Frequency Control igniters in service. Program SR 3.6.3.2.2 -----------------------NOTE-------------------- .-------------
| |
| Not required to be performed until 92 days after discovery of four or more igniters in the division inoperable.
| |
| Energize each primary containment and drywell In accordance with hydrogen igniter division and perform current the Surveillance versus voltage measurements to verify required Frequency Control igniters in service. Program SR 3.6.3.2.3 Verify each required igniter in inaccessible areas In accordance with develops sufficient current draw for a ~ 1700°F the Surveillance surface temperature. Frequency Control Program (continued)
| |
| RIVER BEND 3.6-42 Amendment No. 81, 168,
| |
| | |
| Primary Containment and Drywell Hydrogen lgniters 3.6.3.2 SURVEILLANCE REQUIREMENTS (continued SURVEILLANCE FREQUENCY SR 3.6.3.2.4 Verify each required igniter in accessible areas In accordance with develops a surface temperature of::::>: 1700°F. the Surveillance Frequency Control Program RIVER BEND 3.6-43 Amendment No. 81, 168,
| |
| | |
| Primary Containment/Drywell Hydrogen Mixing System 3.6.3.3 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time not met.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.3.1 Operate each primary containment/drywell Every COLD hydrogen mixing subsystem for::::: 15 minutes. SHUTDOWN, if not performed within the previous 92 days.
| |
| SR 3.6.3.3.2 Verify each primary containment/drywell hydrogen In accordance with mixing subsystem flow rate is::::: 600 cfm. the Surveillance Frequency Control Program
| |
| (
| |
| RIVER BEND 3.6-45 Amendment No. 81 89, 168,
| |
| | |
| Secondary Containment-Operating 3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment-Operating LCO 3.6.4.1 The shield building and auxiliary building shall be OPERABLE.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours inoperable. containment to OPERABLE status.
| |
| B. Required Action and B.1 ----------NOTE-----------
| |
| associated Completion LCO 3.0.4.a is not '
| |
| Time not met. applicable when entering MODE 3.
| |
| Be in MODE 3. 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY.
| |
| SR 3.6.4.1.1 Verify shield building annulus and auxiliary building In accordance with vacuum is ~ 3.0 and ;: , : 0.0 inch of vacuum water the Surveillance gauge, respectively. Frequency Control Program (continued)
| |
| RIVER BEND 3.6-46 Amendment No. 34, 113, 185,
| |
| | |
| Secondary Containment-Operating 3.6.4.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.4.1.2 Verify all secondary containment equipment In accordance with hatches are closed and sealed and loop seals the Surveillance filled. Frequency Control Program SR 3.6.4.1.3 Verify each secondary containment access door is In accordance with closed, except when the access opening is being the Surveillance used for entry and exit. Frequency Control Program SR 3.6.4.1.4 Verify each standby gas treatment (SGT) In accordance with subsystem will draw down the shield building the Surveillance annulus and auxiliary building to ~ 0.5 and Frequency Control
| |
| ~ 0.25 inch of vacuum water gauge in :s; 18.5 and Program
| |
| :s; 34.5 seconds, respectively.
| |
| SR 3.6.4.1.5 Deleted Not Applicable SR 3.6.4.1.6 Verify each SGT subsystem can maintain ~ 0.5 and In accordance with
| |
| ~ 0.25 inch of vacuum water gauge in the shield the Surveillance building annulus and auxiliary building, Frequency Control respectively, for 1 hour. Program RIVER BEND 3.6-47 Amendment No. 8195113132, 168,
| |
| | |
| SCI Os/FBI Os 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.q.4.2.1 Verify the isolation time of each required power In accordance with operated automatic SCIO and FBID is within limits. the Surveillance Frequency Control Program SR 3.6.4.2.2 Verify each required automatic SCIO and FBID In accordance with actuates to the isolation position on an actual or the Surveillance simulated automatic isolation signal. Frequency Control Program RIVER BEND 3.6-50 Amendment No. 81 95113, 168,
| |
| | |
| SGT System 3.6.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT subsystem for~ 1O continuous In accordance with hours with heaters operating. the Surveillance Frequency Control, Program SR -3.6.4.3.2 Pertprm required SGT filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual In accordance with or simulated initiation signal. the Surveillance Frequency Control Program SR 3.6.4.3.4 Verify each SGT filter cooling bypass In accordance with damper can be opened and the fan the Surveillance started. Frequency Control Program RIVER BEND 3.6-52 Amendment No. 81, 168,
| |
| | |
| Fuel Building 3.6.4.5 3.6 CONTAINMENT SYSTEMS 3.6.4.5 Fuel Building LCO 3.6.4.5 The fuel building shall be OPERABLE.
| |
| APPLICABILITY: During movement of recently irradiated fuel assemblies in the fuel building.
| |
| ACTIONS
| |
| ------------------------------------------------------NOTE--------------------------------- * ---------------------------
| |
| LCO 3.0.3 is not applicable.
| |
| CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel building inoperable. A.1 Suspend movement of Immediately recently irradiated fuel assemblies in the fuel b'uilding.
| |
| I SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.5.1 Verify fuel building vacuum is :?: 0.25 In accordance with inch of vacuum water gauge. the Surveillance Frequency Control Program SR 3.6.4.5.2 Verify all fuel building equipment hatch covers are In accordance with installed.* the Surveillance Frequency Control Program SR 3.6.4.5.3 Verify each fuel building access door is closed, In accordance with except when the access opening is being used for the Surveillance entry and exit. Frequency Control Program RIVER BEND 3.6-55 Amendrpent No. 81 95, 11 J,
| |
| | |
| Fuel Building Ventilation System-Fuel Handling 3.6.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.7.1 Verify one fuel building ventilation charcoal filtration In accordance with subsystem in operation. the Surveillance Frequency Control Program SR 3.6.4.7.2 Operate each fuel building ventilation charcoal In accordance with filtration subsystem for~ 1O continuous hours with the Surveillance heaters operating. Frequency Control Program SR 3.6.4.7.3 Perform fuel building ventilation charcoal filtration In accordance with filter testing in accordance with the Ventilation Filter the VFTP Testing Program (VFTP).
| |
| SR 3.6.4.7.4 Verify each fuel building ventilation charcoal In accordance with filtration subsystem actuates on an actual or the Surveillance simulated initiation signal. Frequency Control Program SR 3.6.4.7.5 Verify each fuel building ventilation charcoal In accordance with filtration filter cooling bypass damper can be the Surveillance opened and the fan started. Frequency Control Program RIVER BEND 3.6-59 Amendment No. 81, 168,
| |
| | |
| Drywell 3.6.5.1 3.6 CONTAINMENT SYSTEMS 3.6.5.1 Drywell LCO . 3.6.5.1 The drywell shall be OPERABLE.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell inoperable. A.1 Restore drywell to 1 hour OPERABLE status.
| |
| B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours I SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1.1 Verify personnel door inflatable seal air flask In accordance with pressure 2 75 psig. the Surveillance Frequency Control Program SR 3.6.5.1.2 Verify from an initial pressure of 75 psig, the In accordance with personnel door inflatable seal pneumatic system the Surveillance
| |
| __ press~re does not decay at a rate equivalent to Frequency Control 2 20.0 psig for a period of 24 hours. Program (continued)
| |
| RIVER BEND 3.6-60 Amendment No. 81132, 168,
| |
| | |
| Drywell 3.6.5.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.5.1.3 Verify bypass leakage is less than or equal to the --------NOTE-------
| |
| bypass leakage limit. SR 3.0.2 is not applicable for However, during the first unit startup following extensions > 9 bypass leakage-testing performed in accordance months with this SR, the acceptance criterion is :;; 10% of the drywell bypass leakage limit.
| |
| 24 months following 2 consecutive tests with bypass leakage greater than the bypass leakage limit until 2 consecutive tests are less than or equal to the bypass leakage limit 48 months following a test with bypass leakage greater than the bypass leakage limit In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-61 Amendment No. 81 87144, 191,
| |
| | |
| Drywell 3.6.5.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.5.1.4 Visually inspect the exposed accessible interior and Once prior to exterior surfaces of the drywell. performance of each Type A test required by SR 3.6.1.1.1 SR 3.6.5.1.5 Verify seal leakage rate when the gap between the door Once within 72 seals is pressurized to 2 3 psid. hours after each drywell air lock door closing SR 3.6.5.1.6 Verify drywell air lock leakage by performing an air lock In accordance with barrel leakage test at 2 3 psid. the Surveillance Frequency Control Program RIVER BEND 3.6-62 Amendment No.~.
| |
| | |
| Drywell Air Lock 3.6.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.2.1 Deleted SR 3.6.5.2.2 Verify drywell air lock seal air flask pressure is In accordance with
| |
| ;::: 75 psig. the Surveillance Frequency Control Program SR 3,.6.5.2.3 ---------------------------NOTE------------------------------
| |
| 0 nly required to be performed upon entry into drywell.
| |
| Verify only one door in the drywell air lock can be In accordance with opened at a time. the Surveillance Frequency Control Program SR 3.6.5.2.4 Deleted SR 3.6.5.2.5 Verify, from an initial pressure of 75 psig, the In accordance with drywell air lock seal pneumatic system pressure the Surveillance does not decay at a rate equivalent to > 20.0 psig Frequency Control for a period of 24 hours. Program RIVER BEND 3.6-66 Amendment No. 81 87 132, 168,
| |
| | |
| Drywell Isolation Valves 3.6.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.3.1 Verify each 24 inch drywell purge isolation valve is In accordance with sealed closed. the Surveillance Frequency Control Program SR 3.6.5.3.2 --------------------------NOTE-------------------------------
| |
| N ot required to be met when the primary containment/drywell hydrogen mixing inlet or outlet valves are open for pressure control.
| |
| Verify each primary containment/drywell hydrogen In accordance with mixing isolation valve is closed. the Surveillance Frequency Control Program SR 3.6.5.3.3 ---------------------------N OTES----------------------------
| |
| : 1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.
| |
| : 2. Not required to be met for drywell isolation valves that are open under administrative controls.
| |
| Verify each drywell isolation manual valve and blind Prior to entering flange that is required to be closed during accident MODE 2 or 3 from conditions is closed. MODE 4, if not performed in the previous 92 days (continued)
| |
| RIVER BEND 3.6-69 Amendment No. 84-,-8Q.,
| |
| | |
| Drywell Isolation Valves 3.6.5.3 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.6.5.3.4 Verify the isolation time of each power operated In accordance and each automatic drywell isolation valve is within with the lnservice limits. Testing Program SR 3.6.5.3.5 Verify each automatic drywell isolation valve In accordance with actuates to the isolation position on an actual or the Surveillance simulated isolation signal. Frequency Control Program SR 3.6.5.3.6 Verify the cumulative time that the primary In accordance with containment/drywell hydrogen mixing inlet or outlet the Surveillance penetrations are open to be :s: 5 hours per 365 days Frequency Control in Modes 1 and 2, and S:-90 hours per 365 days in Program Mode 3.
| |
| RIVER BEND 3.6-70 Amendment No. 81 89, 168,
| |
| | |
| Drywell Pressure 3.6.5.4 3.6 CONTAINMENT SYSTEMS 3.6.5.4 Drywell Pressure
| |
| \
| |
| i I
| |
| LCO 3.6.5.4 Drywell-to-primary containment differential pressure shall be ~ -0.3 psid I and~ 1.2 psid. -I I
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS CONDl"~ION REQUl~ED ACTION COMPLETION TIME j
| |
| A. Drywell-to-primary A.1 Restore drywell-to- I 1 hour containment differential primary containment pressure not within limits. differential pressure to within limits.
| |
| B. Required Action and 8.1 Be in MODE 3. 12 hours associated Completion Time not met. AND 8.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.4.1 Verify drywell-to-primary containment differential In accordance with pressure is within limits. the Surveillance Frequency Control Program RIVER BEND 3.6-71 Amendment No. 3t,
| |
| | |
| *J Drywell Air Temperature 3.6.5.5 3.6 CONTAINMENT SYSTEMS 3.6.5.5 Drywell Air Temperature LCO 3.6.5.5 Drywell average air temperature shall be~ 1~5°F.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell average air A.1 Restore drywell average 8 hours temperature not within air temperature to within limit. limit.
| |
| B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not inet. AND B.2 Be in MODE 4. 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.5.1 Verify drywell average air temperature is within In accordance with limit. the Surveillance Frequency Control Program RIVER BEND 3.6-72 Amendment No. 34-,
| |
| | |
| SSW System and UHS 3.7.1 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME H. Required Action and H.1 ----------NOTE-----------
| |
| associated Completion LCO 3.0.4.a is not Time of Condition A, E, or applicable when G not met. entering MODE 3.
| |
| Be in MODE 3. 12 hours I. Required Action and 1.1 Be in MODE 3. 12 hours associated Completion Time of Condition B, D or AND
| |
| * F not met.
| |
| 1.2 Be in MODE 4. 36 hours OR I
| |
| Both SSW subsystems inoperable for reasons other than Condition F.
| |
| OR Three or four UHS cooling tower fan cells inoperable.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 Verify the water level of UHS cooling tower basin is In accordance with
| |
| ~78%. the Surveillance Frequency Control Program SR 3.7.1.2 Verify the average water temperature of UHS is In accordance with
| |
| ::; 88°F. the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.7-3 Amendment No. 81 185, j
| |
| | |
| SSW System and UHS 3.7.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.7.1.3 Operate each cooling tower fan cell for;:=:: 15 minutes. In accordance with the Surveillance Frequency Control Program SR 3.7.1.4 Verify each required SSW subsystem manual, power In accordance with operated, and automatic valve in the flow path the Surveillance servicing safety related systems or coniponents, that Frequency Control is not locked, sealed, or otherwise secured in Program position, is in the correct position.
| |
| SR 3.7.1.5 Verify each SSW subsystem actuates on an actual or In accordance with simulated initiation signal. the Surveillance Frequency Control Program
| |
| /
| |
| RIVER BEND 3.7-4 Amendment No. 81, 168,
| |
| | |
| CRFA System 3.7.2 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME F. Two CRFA subsystems F.1 Suspend movement of Immediately inoperable during recently irradiated fuel movement of recently assemblies in the primary irradiated fuel assemblies containment and fuel in the primary containment building.
| |
| or fuel building, or during OPDRVs.
| |
| F.2 Initiate action to suspend Immediately OPDRVs.
| |
| One or more CRFA subsystems inoperable due to inoperable CRE boundary during
| |
| * movement of recently irradiated fuel assemblies in the primary containment or fuel building, or during OPDRVs.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 Operate each CRFA subsystem for:::::: 10 continuous In accordance with hours with the heaters operating. the Surveillance Frequency Control Program SR 3.7.2.2 Perform required CRFA filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.7.2.3 Verify each CRFA subsystem actuates on an actual In accordance with or simulated initiation signal. the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.7-7 Amendment No. 81 11 Q 132 154 165,
| |
| | |
| Control Room AC System 3.7.3 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Suspend movement of Immediately associated Completion recently irradiated fuel Time of Condition B not assemblies in the primary met during movement of containment and fuel recently irradiated fuel building.
| |
| assemblies in the primary containment or fuel AND building, or during OPDRVs. E.2 Initiate action to suspend Immediately OPDRVs.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify each control room AC subsystem has the In accordance with capability to remove the assumed heat load. the Surveillance Frequency Control Program RIVER BEND 3.7-11 Amendment No. 81 11 Q 132, 168,
| |
| | |
| Main Condenser Offgas 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify the gross gamma activity rate of the noble Once within gases is s 290 mCi/second after decay of 30 minutes. 4 hours after a
| |
| :2: 50% increase in the nominal steady state fission gas release rate after factoring out increases due to changes in THERMAL POWER level SR 3.7.4.2 -----------------------------NOTE--------------------------------
| |
| Not required to be performed until 31 days after any
| |
| .main steam line not isolated and SJAE in operation.
| |
| Verify the gross gamma activity rate of the noble In accordance with gases is s 290 mCi/second after decay of 30 minutes. the Surveillance Frequency Control Program RIVER BEND 3.7-13 Amendment No. 34-,
| |
| | |
| Main Turbine Bypass System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify one complete cycle of each main turbine In accordance with bypass valve. the Surveillance Frequency Control Program SR 3.7.5.2 Perform a system functional test. In accordance with the Surveillance Frequency Control Program SR 3.7.5.3 Verify the TURBINE BYPASS SYSTEM RESPONSE In accordance with TIME is within limits. the Surveillance Frequency Control Program RIVER BEND 3.7-14a Amendment No. 81 ~14163, 168,
| |
| | |
| Fuel Pool Water Level 3.7.6
| |
| : 3. 7 PLANT SYSTEMS 3.7.6 Fuel Pool Water Level LCO 3. 7 .6 < The fuel pool water level shall be ;::: 23 ft over the top of irradiated fuel assemblies seated in the spent fuel storage pool and upper containment fuel storage pool racks.
| |
| APPLICABILITY: During movement of irradiated fuel assemblies in the associated fuel storage pool. .
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel pool water level not A.1 ------------NOTE-----------
| |
| within limit. LCO 3.0.3 is not applicable.
| |
| Suspend movement of Immediately irradiated fuel assemblies in the associated fuel storage pool(s).
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the fuel pool water level is ;::: 23 ft over the top In accordance with of irradiated fuel assemblies seated in the storage the Surveillance racks. Frequency Control Program RIVER BEND 3.7-15 Amendment No. 34-,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power In accordance with availability for each required offsite circuit. the Surveillance Frequency Control Program SR 3.8.1.2 ----------------------------NOTES--------------------------------
| |
| : 1. Performance of SR 3.8.1. 7 satisfies this SR.
| |
| : 2. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.
| |
| : 3. A modified DG start involving gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1. 7 must be met.
| |
| Verify each DG starts from standby conditions and In accordance with achieves: the Surveillance Frequency Control
| |
| : a. For DG 1A and DG 1B, steady state voltage Program 2 3740 V ands 4368 V and frequency 2 58.8 Hz ands 60.2 Hz.
| |
| : b. For DG 1C:
| |
| : 1. Maximum of 5400 V, and 66.75 Hz, and
| |
| : 2. Steady state voltage~ 3740 V and s 4580 V and frequency 2 58.8 Hz and s 60.2 Hz.
| |
| (continued)
| |
| RIVER BEND 3.8-5 Amendment No. 81 90 121, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) \
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.3 ------------------------------NOTES--------------------------* ---
| |
| : 1. DG loadings may include gradual,loading as recommended by the manufacturer.
| |
| : 2. Momentary transients outside the load range do not invalidate this test.
| |
| : 3.
| |
| * This Surveillance shall be condu'cted on only one DG at a time.
| |
| : 4. This SR shall be preceded by, and immediately follow, without shutdown, a successful performance of SR 3.8.1.2 or SR3.8.1.7 Verify each DG operates for~ 60 minutes at a load In accordance with
| |
| ~ 3050 kW and:.::; 3100 kW for DG 1A and DG 1B, and the Surveillance
| |
| ~ 2525 kW and :.::; 2600 kW for DG 1C. Frequency Control Program SR 3.8.1.4 Verify each day tank contains~ 316.3 gal of fuel oil. In accordance with the Surveillance Frequency Control Program SR 3.8.1.5 Check for and remove accumulated water from each In accordance with day tank. the Surveillance Frequency Control Program SR 3.8.1.6 Verify the fuel oil transfer system operates to In accordance with automatically transfer fuel oil from the storage tank to the Surveillance the day tank. Frequency Control Program (continued)
| |
| I RIVER BEND 3.8-6 Amendment No. 81 90 121, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.1.7 -------------------------NOTE-------------------------------------
| |
| AII DG starts may be preceded by an engine prelube period.
| |
| Verify each DG starts from standby conditions and In accordance with achieves: the Surveillance Frequency Control
| |
| : a. For DG 1A and DG 1B: Program
| |
| : 1. In s 10 seconds, voltage ~ 3740 V and frequency~ 58.8 Hz; and
| |
| : 2. Steady state voltage~ 3740 V and s 4368 V and frequency~ 58.8 Hz and s 60.2 Hz.
| |
| : b. For DG 1C:
| |
| : 1. Maximum of 5400 V, and 66. 75 Hz, and
| |
| : 2. Ins 13 seconds, voltage~ 3740 V and frequency~ 58.8 Hz; and
| |
| : 3. Steady state voltage~ 3740 V and s 4580 V and frequency~ 58.8 Hz and s 60.2 Hz.
| |
| (continued)
| |
| RIVER BEND 3.8-7 Amendment No. 81 121 165 168 176, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY
| |
| (
| |
| SR 3.8.1.8 -----------------------------NOTES------------, -----------------
| |
| : 1. This Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.
| |
| : 2. SR 3.8.1.8.b is only required to be met if 22 kV onsite circuit is supplying Division Ill safety related bus E22-S004 from normal power transformer STX-XNS 1C.
| |
| Verify, for required unit power supplies: In accordance with the Surveillance
| |
| : a. Manual transfer of unit power supply from the Frequ~ncy Control normal offsite ci.rcuit to required alternate offsite Program circuit; and
| |
| : b. Automatic transfer of bus E22-S004 through NNS-SWG1A or NNS-SWG18 from the 22 kV onsite circuit to required offsite circuit.
| |
| SR 3.8.1.9 --------- .------------------NOTE-------------------------------
| |
| : 1. Credit may be taken for unplanned events that satisfy this SR.
| |
| : 2. If performed with DG synchronized with offsite power, it shall be performed at a power factor
| |
| ::;;Q.9 Verify each DG rejects a load greater than or equal to In accordance with its associated single largest post accident load and the Surveillance following load rejection, the engine speed is Frequency Control maintained less than nominal plus 75% of the Program difference between nominal speed and the overspeed trip setpoint or 15% above nominal, whichever is lower.
| |
| (continued)
| |
| RIVER BEND 3.8-8 Amendment No. 81 121 133 137 168, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.10 -----------------------------NOTE------------------------------
| |
| Cred it may be taken for unplanned events that satisfy this SR.
| |
| Verify each DG operating at a power factor:<,:; 0.9 does In accordance with not trip and voltage is maintained:<,:; 4784 V for DG 1A the Surveillance and DG 1B and :<,:; 5400 V for DG 1C during and Frequency Control following a load rejection of a load ~ 3050 kW and Program
| |
| :<,:; 3130 kW for DGs 1A and 1B and ~ 2525 kW and
| |
| :<,:; 2600 kW for DG 1C.
| |
| SR 3.8.1.11 --------------------------------NOTES------------------------
| |
| : 1. All DG starts may be preceded by an engine prelube period.
| |
| : 2. This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C)
| |
| However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify on an actual or simulated loss of offsite power In accordance with signal: the Surveillance Frequency Control
| |
| : a. De-energization of emergency buses;
| |
| * Program
| |
| : b. Load shedding from emergency buses for Divisions I and II; and (continued)
| |
| RIVER BEND 3.8-9 Amendment No. 81 121133 168, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.11 (continued)
| |
| : c. DG auto-starts from standby condition and:
| |
| : 1. energizes permanently connected loads in *
| |
| :,:; 10 seconds for DG 1A and DG 1B and
| |
| :,:; 13 seconds for DG 1C,
| |
| : 2. energizes auto-connected shutdown loads,
| |
| : 3. maintains steady state voltage
| |
| : i. for DG 1A and DG 18 2 3740 Vand
| |
| :,:;4368 V, ii. for DG 1C 2 3740 Vand:,:; 4580 V
| |
| : 4. maintains steady state frequency 2::: 58.8 Hz and :,:; 60.2 Hz, and
| |
| : 5. supplies permanently connected and auto-connected shutdown loads for 2::: 5 minutes.
| |
| (continued)
| |
| RIVER BEND 3.8-10 Amendment No. 81121 133 165 168, 187,
| |
| /
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.12 ---- . -------------------------NOTES-----------------------------
| |
| : 1. All DG starts may be preceded by an engine prelube period.
| |
| : 2. This Surveillance shall not be performed in MODE 1 or 2. (Not applicable to DG 1C)
| |
| However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify on an actual or simulated Emergency Core In accordance with Cooling System (ECCS) initiation signal each DG the Surveillance auto-starts from standby condition and: Frequency Control Program
| |
| : a. For DG 1C during the auto-start maintains voltage s; 5400 V and frequency s; 66. 75 Hz;
| |
| : b. Ins; 10 seconds for DG 1A and DG 18 and s; 13 seconds for DG 1C after auto-start and during tests, achieves voltage~ 3740 V and frequency~ 58.8 Hz.
| |
| : c. Achieves steady state voltage
| |
| : 1. For DG 1Aand DG 18 ~ 3740 Vand s; 4368 V,
| |
| : 2. For DG 1C ~ 3740 V ands; 4580 V, and
| |
| : 3. For DG 1A, 18, and 1C, frequency of
| |
| ~ 58.8 and s; 60.2 Hz; and
| |
| : d. Operates for~ 5 minutes.
| |
| (continued)
| |
| RIVER BEND 3.8-11 Amendment No. 81 121 133 165 168, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.13 ------------------- .----------NOTE---------------------------------
| |
| This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C) However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify each DG's automatic trips are bypassed on an In accordance with actual or simulated ECCS initiation signal except: the Surveillance Frequency Control
| |
| : a. Engine overspeed; and Program
| |
| : b. Generator differential current.
| |
| SR 3.8.1.14 ------------------------------NOTES------------------------------
| |
| : 1. Momentary transients outside the load and power factor ranges do not invalidate this test.
| |
| : 2. Credit may be taken for unplanned events that satisfy this SR.
| |
| Verify each DG operating at a power factor :s; 0.9, In accordance with operates for 2 24 hours: the Surveillance Frequency Control
| |
| : a. For DG 1A and DG 18 loaded 2 3050 kW and Program
| |
| :s; 3130 kW; and
| |
| : b. For DG 1C:
| |
| : 1. For 2 2 hours loaded 2 2750 kW and
| |
| :s; 2850 kW, and
| |
| : 2. For the remaining hours of the test loaded
| |
| : 2. 2525 kW and :s; 2600 kW.
| |
| (continued)
| |
| RIVER BEND 3.8-12 Amendment No. 81 94 121 133 168, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.15 ----------------------------NOTES------------------------------
| |
| : 1. This SuNeillance shall be performed within 5 minutes of shutting down the DG after the DG has operated ;::: 1 hour loaded ;::: 3059 kW and
| |
| :::; 3100 kW for DG 1A and DG 1B, and
| |
| ;::: 2525 kW and:::; 2600 for DG 1C, or operating temperatures have stabilized, which ever is longer.
| |
| Momentary transients outside of the load range do not invalidate this test.
| |
| : 2. All DG starts may be preceded by an engine prelube period.
| |
| Verify each DG starts and achieves: In accordance with the SuNeillance
| |
| : 1. In:::; 10 seconds for DG 1A and DG 1B and Frequency Control
| |
| :::; 13 seconds for DG 1C voltage ;::: 3740 V and Program frequency;::: 58.8 Hz, and
| |
| : 2. Steady state voltage a) For DG 1A and DG 1B;::: 3740 V and
| |
| :::;4368 V b) For DG 1C ;:::. 3740 V and:::; 4580 V and c) For DG 1A, 18, and 1C frequency
| |
| ;::: 58.8 Hz and :::; 60.2 Hz.
| |
| (continued)
| |
| RIVER BEND 3.8-13 Amendment No. 81 121 133 165 168, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.16 -----------------------------NOTE--------* --------------- *-------
| |
| Th is Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C) However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify each DG: In accordance with the Surveillance
| |
| : a. Synchronizes with offsite power source while Frequency Control loaded with emergency loads upon a simulated Program restoration of offsite power;
| |
| : b. Transfers loads to offsite power source; and
| |
| : c. Returns to ready-to-load operation.
| |
| SR 3.8.1.17 ------------------------------NOTE--------------------------------
| |
| Th is Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C) However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify, with a DG operating iri test mode and In accordance with connected to its bus, an actual or simulated ECCS the Surveillance initiation signal overrides the test mode by: Frequency Control Program
| |
| : a. Returning DG to ready-to-load operation; and
| |
| : b. Automatically energizing the emergency loads from offsite power.
| |
| SR 3.8.1.18 ------------------------------NOTE--------------------------------
| |
| T his Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C) However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify sequence time is within+/- 10% of design for In accordance with each load sequencer timer. the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.8-14 Amendment No. 8195121133 168, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.1.19 -----------------------------NOTES-----------------------------
| |
| : 1. All DG starts may be preceded by an engine prelube period.
| |
| : 2. This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1C)
| |
| However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify, on an actual or simulated loss of offsite power In accordance with signal in conjunction with an actual or simulated ECCS the Surveillance initiation signal: Frequency Control Program
| |
| : a. De-energization of eniergency buses;
| |
| : b. Load shedding from emergency buses for Divisions I and 11; and
| |
| : c. DG auto-starts from standby condition and:
| |
| : 1. energizes permanently connected loads in
| |
| ::;; 1O seconds for DG 1A and DG 18 and
| |
| ::;; 13 seconds for DG 1C,
| |
| : 2. energizes auto-connected emergency loads,
| |
| : 3.
| |
| * achieves steady state voltage
| |
| : i. for DG 1A and DG 18 2 3740 Vand
| |
| . ::5:4368 V, ii. for DG 1C 2 3740 Vand::;; 4580 V,
| |
| : 4. achieves steady state frequency 2 58.8 Hz and::;; 60.2 Hz, and
| |
| : 5. supplies permanently connected and auto-connected emergency loads for 2 5 minutes.
| |
| (continued)
| |
| RIVER BEND 3.8-15 Amendment No. 81121133 168, 187,
| |
| | |
| AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
| |
| . SURVEILLANCE FREQUENCY SR 3.8.1.20 ------------------------------NOTE--------------------------------
| |
| AII DG starts may be preceded by an engine prelube period.
| |
| Verify, when started simultaneously from standby In accordance with condition, each DG achieves: the Surveillance Frequency Control
| |
| : 1. In::;; 10 seconds for DG 1A and DG 1Band Program
| |
| ::;; 13 seconds for DG 1C voltage ~ 3740 V and frequency ~ 58.8 Hz, and
| |
| : 2. Steady state voltage a) For DG 1A and DG 18 ~ 3740 V and
| |
| ::;;4368 V, b) For DG 1C ~ 3740 V and::;; 4580 V, and c) For DG 1A, 18, and 1C a frequency
| |
| ~ 58.8 Hz and ::;; 60.2 Hz.
| |
| RIVER BEND 3.8-16 AmE3ndment No . 84,--QQ,
| |
| | |
| Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains ~ 45,495 gal In accordance with of fuel. the Surveillance Frequency Control Program SR 3.8.3.2 Verify lube oil inventory is: In accordance with the Surveillance
| |
| : a. ~ 367 gal for DGs 1A and 1B; and Frequency Control Program
| |
| : b. ~ 295 gal for DG 1C.
| |
| SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are In accordance with tested in accordance with, and maintained within the the Diesel Fuel Oil limits of, the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.4 Verify each required DG air start receiver pressure is In accordance with the Surveillance
| |
| : a. ~ 160 psig for DGs 1A and 18; and Frequency Control Program
| |
| : b. ~ 200 psig for DG 1C.
| |
| SR 3.8.3.5 Check for and remove accumulated water from each In accordance with fuel oil storage tank. the Surveillance Frequency Control Program RIVER BEND 3.8-23 Amendment No. 81 91, 160,
| |
| | |
| DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is~ 130.2 Von float In accordance with charge. the Surveillance Frequency Control Program SR 3.8.4.2 Verify no visible corrosion at battery terminals and In accordance with connectors. , the Surveillance Frequency Control Program Verify battery connection resistance is s 1.5 E-4 ohm for inter-cell connections, s 1.5 E-4 ohm for inter-rack connections, s 1.5 E-4 ohm for inter-tier connections, and s 1.5 E-4 ohm for terminal connections.
| |
| SR 3.8.4.3 Verify battery cells, cell plates, and racks show no In accordance with visual indication of physical damage or abnormal the Surveillance deterioration. , Frequency Control Program
| |
| \
| |
| SR 3.8.4.4 Remove visible corrosion, and verify battery cell to In accordance with cell and terminal connections are coated with the Surveillance anti-corrosion material. Frequency I
| |
| Control Program SR 3.8.4.5 Verify battery connection resistance is In accordance with s 1.5 E-4 ohm for inter-cell connections, the Surveillance s 1.5 E-4 ohm for inter-rack connections, Frequency Control s 1.5 E-4 ohm for inter-tier connections, and Program*
| |
| s 1.5 E-4 ohm for terminal connections.
| |
| (continued)
| |
| RIVER BEND 3.8-25 Amendment No. 81, 1e8,
| |
| | |
| DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.4.6 Verify each battery charger supplies ~ 300 afnps for
| |
| * In accordance with chargers 1A and 18 and~ 50 amps for charger 1C at the Surveillance
| |
| ~ 130.2 V for~ 8 hours. Frequency Control Program SR 3.8.4.7 -----------------------------NOTES------------------- -----------
| |
| : 1. SR 3.8.4.8 may be performed in lieu of SR 3.8.4.7 once per 60 months.
| |
| : 2. This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division Ill).
| |
| However, credit may be taken for unplanned events that satisfy this SR.
| |
| Verify battery capacity is adequate to supply, and In accordance with maintain in OPERABLE status, the required the Surveillance emergency loads for the design duty cycle when Frequency Control subjected to a battery service test. Program (continued)
| |
| RIVER BEND 3.8-26 Amendment No. 81141, 168,
| |
| | |
| DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.8.4.8 -------------------------------NOTE------------------------------
| |
| This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division Ill). However, credit
| |
| .may be taken for unplanned events that satisfy this SR.
| |
| Verify battery capacity is ~ 80% of the manufacturer's In accordance with rating when subjected to a performance discharge the Surveillance test. Frequency Control Program
| |
| ---------NOTE-------
| |
| Only applicable when battery shows degradation or has reached 85% of expected life.
| |
| 18 months RIVER BEND 3.8-27 Amendment No. 81, 141,
| |
| | |
| Battery Cell Parameters 3.8.6 ACTIONS (continued)
| |
| CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Declare associated Immediately associated Completion battery inoperable.
| |
| Time of Condition A not met.
| |
| One or more batteries with average electrolyte temperature of the representative cells
| |
| < 60°F.
| |
| One or more batteries with one or more battery cell parameters not within Category C limits.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet Table 3.8.6-1 In accordance with Category A limits. the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.8-32 Amendment No. 84-,
| |
| | |
| Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)
| |
| SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6-1 In accordance with Category B limits. the Surveillance Frequency Control Program Once within 72 hours after battery overcharge
| |
| > 144 V SR 3.8.6.3 Verify average electrolyte temperature of In accordance with representative cells is~ 60°F. the Surveillance Frequency Control Program RIVER BEND 3.8-33 Amendment No. g.:J.,
| |
| | |
| Inverters-Operating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Inverters-Operating LCO 3.8.7 The Division I and Division II inverters shall be OPERABLE.
| |
| APPLICABILITY: MODES 1, 2, and 3.
| |
| ACTIONS
| |
| ---------------------------------------------------NOTE-----------------------------------------------------------------
| |
| Ente r applicable Conditions and R!::!quired Actions of LCO 3.8.9, "Distribution Systems-Operating," with any AC vital bus de-energized.
| |
| CONDITION REQUIRED ACTION COMPLETION TIME A. Division I or 11 inverter A.1 Restore Division I and 11 24 hours inoperable. inverters to OPERABLE status.
| |
| B. Required Action and B.1 ------------NOTE-------------
| |
| associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when entering met. MODE 3.
| |
| Be in MODE 3. 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, frequency, and In accordance with alignment to required AC vital buses. the Surveillance Frequency Control Program RIVER BEND 3.8-35 Amendment No. 81, 185,
| |
| | |
| Inverters-Shutdown 3.8.8 ACTIONS (continued)
| |
| CONDITIONS REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate action to Immediately suspend operations with a potential for draining the reactor vessel.
| |
| A.2.4 Initiate action to restore Immediately required inverters to OPERABLE status. /
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage, frequency, and In accordance with alignments to required AC vital buses. the Surveillance Frequency Control Program RIVER BEND 3:8-37 Amendment No. 3i,
| |
| | |
| Distribution Systems-Operating 3.8.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to In accordance with required AC, DC, and AC vital bus electrical power the Surveillance distribution subsystems. Frequency Control Program RIVER BEND 3.8-40 Amendment No. &:I-,
| |
| | |
| Distribution Systems-Shutdown 3.8.10 ACTIONS continued CONDITIONS REQUIRED ACTIONS COMPLETION TIME A. (continued) A.2.3 Initiate action to Immediately suspend operations with a potential for draining the reactor vessel.
| |
| AND A.2.4 Initiate actions to Immediately restore required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.
| |
| AND A.2.5 Declare associated Immediately required shutdown cooling subsystem(s) inoperable and not in operation.
| |
| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to In accordance with required AC, DC, and AC vital bus electrical power the Surveillance distribution subsystems. Frequency Control Program RIVER BEND 3.8-42 Amendment No. 84,
| |
| | |
| Refueling Equipment Interlocks 3.9.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Perform CHANNEL FUNCTIONAL TEST on each of In accordance with the following required refueling equipment interlock the Surveillance inputs: Frequency Control Program
| |
| : a. All-rods-in,
| |
| : b. Refuel platform position, and
| |
| . c. Refuel platform main hoist, fuel loaded.
| |
| RIVER BEND 3.9-1a Amendment No. 404,
| |
| | |
| Refueling Position One - Rod - Out Interlock 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Refuel Position One-Rod-Out Interlock LCO 3.9.2 The refuel position one-rod-out interlock shall ~e OPERABLE.
| |
| APPLICABILITY: MODE 5 with the reactor mode switch in the refuel position and any control rod withdrawn.
| |
| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refuel position one- rod- A.1 Suspend control rod Immediately out interlock inoperable. withdrawal.
| |
| A.2 Initiate action to fully insert all Immediately insertable control rods in core cells containing pne or more fuel assemblies.
| |
| SURVEILLANCE REQUIREMENTS
| |
| ===================.========
| |
| SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify reactor mode switch locked in refuel position. In accordance with the Surveillance Frequency Control Program (continued)
| |
| RIVER BEND 3.9-2 Amendmen.t No. 84,
| |
| | |
| Refueling Position One - Rod - Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS continued)
| |
| SURVEILLANCE FREQUENCY SR 3.9.2.2 -----------------------------NO TE-------- _-----------------------
| |
| Not required to be performed until 1 hour after any control rod is withdrawn.
| |
| Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program RIVER BEND .3.9-3 Amendment No. &+,
| |
| | |
| Control Rod Position 3.9.3 3 .9 REFUELING OPERATIONS 3 .9.3 Control Rod Position L co 3.9.3 All control rods shall be fully inserted.
| |
| A PPLICABILITY: When loading fuel assemblies into the core.
| |
| A CTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One-or more control rods A.1 Suspend loading fuel Immediately not fully inserted. assemblies into the core.
| |
| \
| |
| s URVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify all control rods are fully inserted. In accordance with
| |
| - the Surveillance Frequency Control Program I
| |
| \
| |
| \
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| 1 RIVER BEND 3.9-4 Amendment No. 84,
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| I Control Rc;>d OPERABILITY - Refueling 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Control Rod OPERABILITY - Refueling LCO 3.9.5 Each withdrawn control rod shall be OPERABLE.
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| APPLICABILITY: MODE 5.
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| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more withdrawn A.1 Initiate action to fully insert Immediately control rods inoperable. inoperable withdrawn control rods.
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| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY.
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| SR 3.9.5.1 ----------------------------NOTE---------------------------------
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| N ot required to be performed until 7 days after the control rod is withdrawn.
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| Insert each withdrawn control rod at least one notch. In accordance with the Surveillance Frequency Control Program SR 3.9.5.2 Verify each withdrawn control rod scram accumulator In accordance with pressure is .:2: 1540 psig. the Surveillance Frequency Control Program RIVER BEND . 3.9-7 Amendment No. 81,114,
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| RPV Water Level-Irradiated Fuel 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Reactor Pressure Vessel (RPV) Water Level - Irradiated Fuel LCO 3.9.6 RPV water level shall be ~ 23 ft above the top of the RPV flange.
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| APPLICABILITY: During movement of irradiated fuel assemblies within the RPV.
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| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not within A.1 Suspend movement of Immediately limit. irradiated fuel assemblies within the RPV.
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| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify RPV water level is ~ 23 ft above the top of the In accordance with RPVflange. the Surveillance Frequency Control Program RIVER BEND 3.9-8 Amendment No. ~.
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| RPV Water Level - New Fuel or Control Rods 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Reactor Pressure Vessel (RPV) Water Level - New Fuel or Control Rods LCO 3.9.7 RPV water level s_hall be ~ 23 ft above the top of irradiated fuel assemblies seated within the RPV.
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| APPLICABILITY: During movement of new fuel assemblies or handling of control rods within the RPV when irradiated fuel assemblies are seated within the RPV.
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| ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not within A.1 Suspend movement of new Immediately limit. fuel assemblies and handling of control rods within the RPV.
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| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify RPV water level is~ 23 ft above the top of In accordance with irradiated fuel assemblies seated within the RPV. the Surveillance Frequency Control Program RIVER BEND 3.9-9 Amendment No. g.:J..,
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| . RHR - High Water Level 3.9.8 ACTIONS (continued)
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| CONDITION REQUIRED ACTION COMPLETION TIME
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| . B. (continued) 8.3 -----------NOTE------------
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| Entry and exit is permissible under administrative control.
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| Initiate action to close Immediately r
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| one door in each primary containment air lock.
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| C. No RHR shutdown cooling C.1 Verify reactor coolant 1 hour from subsystem in operation. circulation by an discovery of no alternate method. reactor coolant circulation AND Once per 12 hours thereafter AND C.2 Monitor reactor coolant Once per hour temperature.
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| c-SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem is In accordance with
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| (
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| operating. the Surveillance Frequency Control Program SR 3.9.8.2 Verify required RHR shutdown cooling subsystem In accordance with locations susceptible to gas accumulation are the Surveillance sufficiently filled with water. Frequency Control Program RIVER BEND 3.9-11 Amendment No. 81, 188,
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| (,.
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| RHR - Low Water Level 3.9.9-ACTIONS (continued)
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| CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) 8.2 -----------NOTE-----------
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| Entry and exit is permissible under administrative control.
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| Initiate action to close Immediately one door in each primary containment air lock.
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| C. No RHR shutdown cooling C.1 Verify reactor coolant 1 hour from discovery subsystem in operation. circulation by an of no reactor coolant alternate method. circulation AND Once per 12 hours thereafter AND C.2 Monitor reactor coolant Once per hour temperature.
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| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.9.1< Verify one RHR shutdown cooling subsystem is In accordance with operating. the Surveillance Frequency Control Program SR 3.9.9.2 Verify required RHR shutdown cooling subsystem In accordance with
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| * 1ocations susceptible to gas accumulation are the Surveillance sufficiently filled with water. Frequency Control Program RIVER BEND 3.9-13 Amendment No. 81, 188,
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| Reactor Mode Switch Interlock Testing 3.10.2 ACTIONS (continued)
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| CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3.1 Place the reactor mode 1 hour switch in the shutdown position.
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| OR A.3.2 -----------NOTE----------
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| Only applicable in MODE 5.
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| Place the reactor mode 1 hour switch in the refuel position.
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| SURVEILLANCE REQUIREMENTS /
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| SURVEILLANCE FREQUENCY SR 3.10.2.1 Verify all control rods are fully inserted in core cells In accordance with containing on~.or more fuel assemblies. the Surveillance Frequency Control Program SR 3.10.2.2 Verify no CORE ALTERATIONS are in progress. In *accordance with .
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| the Surveillance Frequency Control Program RIVER BEND 3.10-5 Amendment No. M, I
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| \
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| Single Control Rod Withdrawal - Hot Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.3.1 Perform the applicable SRs for the required LCOs. According to the applicable SRs SR 3.10.3.2 ---------------------------NOTE-----------------------------------
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| Not required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.d.1 requirements.
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| Verify all control rods, other than the control rod being In accordance with withdrawn, in a five by five array centered on the the Surveillance control rod being withdrawn, are disarmed. Frequency Control Program SR 3.10.3.3 Verify all control rods, other than the control rod being In accordance with withdrawn, are fully inserted. the Surveillance Frequency Control Program RIVER BEND 3.10-8 Amendment No. g.:f.,
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| Single Control Rod Withdrawal - Cold Shutdown 3.10.4 ACTIONS (continued)
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| CONDITION REQUIRED ACTION COMPLETION TIME B. One or more of the above B.1 Suspend withdrawal of Immediately requirements not met with the control rod and the affected control rod not removal of associated insertable. CRD.
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| AND B.2.1 Initiate action to fully Immediately insert all control rods.
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| OR B.2.2 Initiate action to satisfy Immediately the requirements of this LCO.
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| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.4.1 Perform the applicable SRs for the required LCOs. According to applicable SRs SR 3.10.4.2 ---------------------------N OT E----------------------------------
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| Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.c.1 requirements.
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| Verify all control rods, other than the control rod being In accordance with withdrawn, in a five by five array centered on the the Surveillance control rod being withdrawn, are disarmed. Frequency Control Program (continued)
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| RIVER BEND 3.10-11 Amendment No. 84,
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| Single Control Rod Withdrawal - Cold Shutdown 3.10.4 SURVEILLANCE REQUIREMENTS (continued)
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| SURVEILLANCE FREQUENCY SR 3.10.4.3 Verify all control rods, other than the control rod being In accordance with withdrawn, are fully inserted. the Surveillance Frequency Control Program SR 3.10.4.4 -----------------------------NOTE-------------------------------
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| Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.b.1 requirements.
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| Verify a control rod withdrawal block is inserted. In accordance with
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| ' the Surveillance Frequency Control Program RIVER BEND 3.10-12 Amendment No. 84, I
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| Single CRD Removal - Refueling 3.10.5 ACTIONS (continued)
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| CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.1 Initiate action to fully Immediately insert all control rods.
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| A.2.2 Initiate action to satisfy Immediately the requirements of this LCO.
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| SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.5.1 Verify all controls rods, other than the control rod In accordance with withdrawn for the removal of the associated CRD, are the Surveillance fully inserted. Frequency Control Program SR 3.10.5.2 Verify all control rods; other than the control rod In accordance with.
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| withdrawn for the removal of the associated CRD, in a the Surveillance five by five array centered on the control rod Frequency Control withdrawn for the removal of the associated CRD, are Program disarmed.
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| SR 3.10.5.3 Verify a control rod withdrawal block is inserted. In accordance with the Surveillance Frequency Control Program (continued)
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| RIVER BEND 3, 10-14 Amendment No. ~.
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| Single CRD Removal - Refueling 3.10.5 SURVEILLANCE REQUIREMENTS (continued)
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| SURVEILLANCE FREQUENCY SR 3.10.5.4 Perform SR 3.1.1.1. According to SR 3.1.1.1 SR 3.10.5.5 Verify no CORE *'LTERA TIONS are in progress. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.10-15 Amendment No. 84,
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| Multiple Control Rod Withdrawal - Refueling
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| . 3.10.6 ACTIONS (continued)
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| CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3.1 Initiate action to fully Immediately insert all control rods in core cells containing one or more fuel assemblies.
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| A.3.2 Initiate action to satisfy Immediately the requirements of this LCO.
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| SURVEILLANCE REQUIREMENTS SURVEILLANCE
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| * FREQUENCY SR 3.10.6.1 Verify the four fuel ~ssemblies are removed from In.accordance with core cells associated with each control rod or CRD the Surveillance removed. Frequency Control Program SR 3.10.6.2 Verify all other control rods in core cells containing In accordance with one or more fuel assemblies are fully inserted. the Surveillance Frequency Control Program SR 3.10.6.3 ---------------------------NOTE-------------------------------
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| 0 nly required to be met during fuel loading.
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| Verify fuel assemblies being loaded are in In accordance with compliance with an approved spiral reload the Surveillance sequence. Frequency Control Program RIVER BEND 3.10-17 Amendment No. ~.
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| I SOM Test- Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued)
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| SURVEILLANCE FREQUENCY SR 3.10.8.2 ------* --------------------N'o TE----------------------------------
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| Not required to be met if SR 3.'10.8.3 satisfied.
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| --------------------------------------------------------------------7' Perform the MODE 2 applicable SRs for LCO 3.3.2.1, According to the Function 1.b of Table 3.3.2.1-1. applicable SRs SR 3.10.8.3 ----------------------------NOTE---------------------------------
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| Not required to be met if SR 3.10.8.2 satisfied.
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| Verify movement of control rods is in compliance with During control rod the approved control rod sequence for the SOM test
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| * movement by a second licensed operator or other qualified member of the technical staff.
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| SR 3.10.8.4 Verify no other CORE ALTERATIONS are in In accordance with progress. the Surveillance Frequency Control Program (continued)
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| RIVER BEND 3.10-21 Amendment No. 84,
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| SOM Test- Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued)
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| SURVEILLANCE FREQUENCY SR 3.10.8.5 Verify each withdrawn control rod does not go to the Each time the withdrawn overtravel position. control rod is withdrawn to "full out" position Prior to satisfying LCO 3.10.8.c requirement after work on control rod or CRD System that could affect coupling SR 3.10.8.6 Verify CRD charging water header pressure :2: 1540 In accordance with psig. the Surveillance Frequency Control Program RIVER BEND 3.10-22 Amendment No. 81, 114,
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| Programs and Manuals 5.5 5.5 Programs and Manuals ASME OM Code and applicable Addenda terminology for Required frequencies inservice testing for performing inservice activities testing activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per: 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days
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| : b. The provisions of SR 3.0.2 are applicable to the above required frequencies and to other normal and accelerated frequencies specified as 2 years or less in the lnservice Testing Program for performing inservice testing activities; *
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| : c. The provisions of SR 3.0.3 are applicable to inservice testing activities; and
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| : d. Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.
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| 5.5.7 Ventilation Filter Testing Program (VFTP)
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| \
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| A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in Regulatory Guide 1.52, Revision 2, except that testing specified at a frequency of 18 months is required at a frequency in accordance with the Surveillance Frequency Control Program.
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| (continued)
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| RIVER BEND 5.0-1.1 Amendment No. 81 165 167, 168,
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| Programs arid Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP) (continued)
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| : a. Demonstrate for each of the ESF systems that an inplace test of the high efficiency particulate air (HEPA) filters shows a penetration and system bypass < 0.05% when tested in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989 at the system flowrate specified below
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| +/- 10%:
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| ESF Ventilation System Flowrate SGTS 12,500 cfm FBVS 10,000 cfm CRFAS 4,000 cfm
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| * b. Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows a penetration and system bypass < 0.05% .when tested in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989 at the system flowrate specified below+/- 10%:
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| ESF Ventilation System Flowrate SGTS 12,500 cfm FBVS 10,000 cfm CRFAS 4,000 cfm
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| : c. Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52, Revision 2, shows the n,ethyl iodide penetration less than the value specified below When tested in accordanc.e with ASTM D3803-1989 at a temperature of 30°C and the relative humidity specified below:
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| ESF Ventilation System Penetration SGTS 5.0% 95%
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| FBVS 5.0% 95%
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| CRFAS 1.0% 95%
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| (continued)
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| RIVER BEND 5.0-12 Amendment No. 81 115 132, 165 183,
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| Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP) (continued)
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| : d. Demonstrate for each of the ESF systems that the pressure drop across the combined HEPA filters, the prefilters, and the charcoal adsorbers is
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| * less than the value specified below when tested in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989 at the system flowrate specified below+/- 10%:
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| ESF Ventilation System Delta P Flowrate SGTS <8"WG 12,500 cfm FBVS <8"WG 10,000 cfm CRFAS <8"WG 4,000 cfm The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.
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| 5.5.8 Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the main condenser offgas treatment system and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks.
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| The program shall include:
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| : a. The limits for concentrations of hydrogen in the main condenser'offgas treatment system and a surveillance program fo ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion); and
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| : b. A surveillance program to ensure that the quantity of radioactive material contained in any unprotected outdoor tank is limited to ~ 1O curies, excluding tritium and dissolved or entrained noble gases.
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| The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies.
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| 5.5.9 Diesel Fuel Oil Testing Program A diesel fuel oil testing. program to implement required testing of both new fuel oil and stored fuel oil shall be established. The (continued)
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| RIVER BEND 5.0-13 Amendment No. 84, 159, 183,
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| Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Diesel Fuel Oil Testing Program (continued) program shall include sampling and testing requirements, and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following:
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| : a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has:
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| : 1. an API gravity or an absolute specific gravity within limits,
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| : 2. a flash point and kinematic viscosity within limits for ASTM 20 fuel oil, and
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| : 3. a clear and bright appearance with proper color;
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| : b. Other properties of the new fuel oil are within limits for ASTM 20 fuel oil within 31 days of addition to storage tanks; and
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| : c. Total particulate concentration of the fuel oil in the storage tanks is
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| < 10 mg/I when tested in accordance with ASTM D-2276, Method A-2 or A-3 at a frequency in accordance_with the Surveillance Frequency Control Program.
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| 5.5.10 Safety Function Determination Program (SFDP)
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| This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate limitations and remedial or compensatory actions may be identified to be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:
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| : a. Provisions for cross division checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected; -
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| : b. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists; (continued)
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| RIVER BEND 5.0-14 Amendment No. 84,
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| Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Technical Specifications (TS) Bases Control Program (continued)
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| : c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the USAR.
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| : d. Proposed changes that do not meet the criteria of either Specification 5.5.11.b.1 or Specification 5.5.11.b.2 above shall be reviewed and approved by the NRC prior to implementation. Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e).
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| 5.5.12 Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.
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| : a. The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled L,
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| by .the program.
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| : b. Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, "Risk-Informed Method for Corifrol of Surveillance Frequencies," Revision 1.
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| : c. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program.
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| * 5.5.13 Primary Containment Leakage Rate Testing Program A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(0) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program shall be in accordance with the guidelines contained in NEI 94-01, "Industry Guideline for Implementing Performance-Based Option of 10 CFR 50, Appendix J," Revision 3-A, dated July 2012, and the conditions and limitations specified in NEI 94-01, Revision 2-A, Section 4.1, dated October 2008.
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| The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa, is 7.6 psig.
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| (continued)
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| RIVER BEND 5.0-16. Amendment No. 81 84 95 131 132 150 154 155, 191 I
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| Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 Primary Containment Leakage Rate Testing Program (continued)
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| The maximum allowable primary containment leakage rate, La, at Pa, shall be 0.325% of primary containment air weight per day.
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| The Primary Containment leakage rate acceptance criterion is s 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are s 0.60 La for the Type B and Type C tests and s 0. 75 La for Type A tests.
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| The provisions of SR 3.0.2 do not apply to test frequencies specified in the Primary Containment Leakage Rate Testing Program.
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| The provisions of SR 3.0.3 are applicable to the Primary Containment Leakage Rate Testing Program.
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| 5.5.14 Control Room Envelope Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensurethat CRE habitability is maintained such that, with an OPERABLE Control Room Fresh Air (CRFA) System, CRE qccupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (OBA) conditions without personnel receiving radiation exposures in .
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| excess of 5 rem total effective dose equivalent (TEDE) for the duration of the accident. The program shall include the following elements:
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| : a. The definition qf the CRE and the CRE boundary.
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| : b. Requirements for maintaining the CRE boundary in its design condition including .configuration control and preventive maintenance.
| |
| : c. Requirements for (i) determining the unfiltered air inleakage past the CRE boundary into the CRE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and, (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0, except that testing specified at a frequency of 18 months is required at a frequency in accordance with the Surveillance Frequency Control Program.
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| (continued)
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| RIVER BEND 5.0-16a Amendment No. 154, 168,
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| Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.14 Control Room Envelope Habitability Program (continued)
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| : d. Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation by one subsystem of the CRFA System, operating at the flow rate required by the VFTP, at a Frequency in accordance with the Surveillance Frequency Control Program. The results shall be trended and used as part of the CRE boundary assessment specified in 5.5.14.c (ii). *
| |
| : e. The quantitative limits on unfiltered air inleakage into the CRE. These limits:shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c.
| |
| The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of OBA consequences. Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.
| |
| : f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.
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| * RIVER BEND 5.0-16b Amendment No.
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| | |
| Attachment 5 RBG-47799 Proposed Technical Specification Bases Changes (Information only)
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| | |
| Control Rod OPERABILITY B 3.1.3 BASES (continued)
| |
| SURVEILLANCE SR 3.1.3.1 REQUIREMENTS The position of each control rod must be determined, to ensure adequate information on control rod position is available to the operator for determining control rod OPERABILITY and controlling rod patterns.
| |
| Control rod position may be determined by the use of OPERABLE position indicators, by moving control rods to a position with an OPERABLE indicator, or by the use of other appropriate methods. The 24 hour
| |
| ,----------,U Frequency of this SR is based on operating experience related to The Surveillance expected changes in control rod position and the availability of control rod Frequency is position indications in the control room.
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| controlled under the Surveiliance SR 3.1.3.2 Frequency Control Program. Deleted SR 3.1.3.3 Control rod insertion capability is demonstrated by inserting each partially or fully withdrawn control rod at least one notch and observing that the control rod moves. The control rod may then be returned to its original position. This ensures the control rod is not stuck and is free to insert on a scram signal. This Surveillance is modified by a Note identifying that the Surveillances are not required to be performed when THERMAL POWER is less than or equal to the actual LPSP of the RPC since the notch insertions may not be compatible with the requirements of the BPWS (LCO 3.1.6) and the RPC (LCO 3.3.2.1 ). This Note also provides a time allowance such that the Surveillance is not required to be performed until the next scheduled control rod testing. Partially 'Nithdrawn control rods are tested at a 31 day Frequency, based on the potential power reduction required to allm.v the control rod movement, and considering the large testing sample of SR 3.1.3.2. Furthermore, the 31 day Frequency takes into account operating experience related to changes in CRD performance. At any time, if a control rod is immovable, a f (continued)
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| ....----J The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
| |
| RIVER BEND 83.1-18 Revision No. 136
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| | |
| Control Rod OPERABILITY B 3.1.3 BASES SURVEILLANCE SR 3.1.3.2 and SR 3.1.3.3 (continued)
| |
| REQUIREMENTS determination of that control rod's trippability (OPERABILITY) must be made and appropriate action taken.
| |
| SR 3.1.3.4 Verifying the ,scram time for each control rod to notch position 13 is
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| ::; 7 seconds provides reasonable assurance that the control rod will insert when required during a OBA or transient, thereby completing its shutdown function. This SR is performed in conjunction with the control rod scram time testing of SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4. The LOGIC SYSTEM FUNCTIONAL TEST in LCO 3.3.1.1, "Reactor Protection System (RPS) Instrumentation," and the functional testing of SDV vent and drain valves in LCO 3.1.8, "Scram Discharge Volume (SDV) Vent and Drain Valves," overlap this Surveillance to provide complete testing of the assumed safety function. The associated Frequencies are acceptable, considering the more frequent testing performed to demonstrate other aspects of control rod OPERABILITY and operating experience, which shows scram times do not significantly change over an operating cycle.
| |
| SR 3.1.3.5 Coupling verification is performed to ensure the control rod is connected to the CROM and will perform its intended function when necessary. The Surveillance requires verifying that a control rod does not go to the withdrawn overtravel position when it is fully withdrawn. The overtravel position feature provides a positive check on the coupling integrity, since only an uncoupled CRD can reach the overtravel position. In addition, during this Surveillance any indicated response of the nuclear instrumentation while withdrawing the control rod is observed as a backup to the withdrawn overtravel position indication. The verification is required to be performed anytime a control rod is withdrawn to the "full out" position (notch position 48) or prior to declaring the control rod OPERABLE after work on the control rod or CRD System that could affect coupling. This includes control rods inserted one notch and then returned to the "full out" position during the performance of SR 3.1.3.2. This (continued)
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| RIVER BEND B3.1-19 Revision No. 1
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| | |
| Control Rod Scram Times B 3.1.4 BASES SURVEILLANCE SR 3.1.4.2 (continued)
| |
| REQUIREMENTS the tested sample are determined to be "slow." If more than 7Yz% of the sample is declared to be "slow" per the criteria in Table 3.1.4-1, additional control rods are tested until this 7Yz% criterion (e.g., 7Yz% of the entire sample size) is satisfied, or until the total number of "slow" control rods (throughout the core, from all surveillances) exceeds the LCO limit. For planned testing, the control rods selected for the sample should be different for each test. Data from inadvertent scrams should be used whenever possible to avoid unnecessary testing at power, even if the control rods with data were previously tested in a sample. The 7Yz% of sample size criteria is intended to align with the 7Yz% of the total control rods allowed to have scram times that exceed the specified limit. +Re 200 day Frequency is intended to allow consistency with control rod The Surveillance sequence exchanges and is based on operating experience that has Frequency is shown control rod scram times do not significantly change over an controlled under the operating cycle. This Frequency is also reasonable, based on the Surveillance additional Surveillances done on the CRDs at more frequent intervals in Frequen::::y Control accordance with LCO 3.1.3 and LCO 3.1.5, "Control Rod Scram Program. Accumulators."
| |
| SR 3.1.4.3 When work that could affect the scram insertion time is performed on a control rod or the CRD System, testing must be done to demonstrate that each affected control rod retains adequate scram performance over the range of applicable reactor pressures from zero to the maximum permissible pressure. The scram testing must be performed once before declaring the control rod OPERABLE. The required scram time testing must demonstrate that the affected control rod is still within acceptable limits. The limits for reactor pressures < 950 psig are established based on a high probability of meeting the acceptance criteria at reactor pressures~ 950 psig. Limits for~ 950 psig are found in Table 3.1.4-1. If testing demonstrates the affected control rod does not meet these limits, but is within the 7 second limit of Table 3.1.4-1 Note 2, the control rod can be declared OPERABLE and "slow."
| |
| Specific examples of work that could affect the scram times include (but are not limited to) the following: removal of any CRD for maintenance or modification; replacement of a control rod; and maintenance or modification of a scram solenoid pilot valve, scram valve, accumulator isolation valve, or check valves in the piping required for scram.
| |
| (continued)
| |
| RIVER BEND B 3.1-25 Revision No. 107
| |
| | |
| Control Rod Scram Accumulators B 3.1.5 BASES ACTIONS D.1 (continued)
| |
| The reactor mode switch must be immediately placed in the shutdown position if either Required Action and associated Completion Time associated with the loss of the CRD pump (Required Actions 8.1 and C.1) cannot be met. This ensures that all insertable control rods are inserted and that the reactor is in a condition that does not require the active function (i.e., scram) of the control rods. This Required Action is modified by a Note stating that the Required Action is not applicable if all control rods associated with the inoperable scram accumulators are fully inserted, since the function of the control rods has been performed.
| |
| SURVEILLANCE SR 3.1.5.1 REQUIREMENTS SR 3.1.5.1 requires that the accumulator pressure be checked every 7 daysperiociicaily to ensure adequate accumulator pressure exists to provide sufficient scram force. The primary indicator of accumulator OPERABILITY is the accumulator pressure. A minimum accumulator pressure is specified, below which the capability of the accumulator to perform its intended function becomes degraded and the accumulator is The Surveiilance considered inoperable. The minimum accumulator pressure of 1540 psig Frequency is is well below the expected pressure of 1750 psig (Ref. 2). Declaring the controlled under the accumulator inoperable when the minimum pressure is not maintained Surveillance ensures that significant degradation in scram times does not occur. +RB Frequency Controi 7 day Frequency has been shovm to be acceptable through operating Program_ experience and takes into account indications available in the control f9Gffh REFERENCES 1. USAR, Section 4.3.2.5.5.
| |
| : 2. USAR, Section 4.6.1.1.2.5.3.
| |
| : 3. USAR, Section 5.2.2.2.3.
| |
| : 4. USAR, Section 15.4.1.
| |
| RIVER BEND B 3.1-31 Revision No. 6-14
| |
| | |
| Control Rod Pattern B 3.1.6 BASES ACTIONS B.1 and B.2 (continued) withdrawals have. Required Action B.1 is modified by a Note that allows the affected control rods to be bypassed in RAGS in accordance with SR 3.3.2.1.9 to allow insertion only.
| |
| With nine or more OPERABLE control rods not in compliance with BPWS, the reactor mode switch must be placed in the shutdown position within 1 hour. With the reactor mode switch in shutdown, the reactor is shut down, and therefore does not meet the applicability requirements of this LCO. The allowed Completion Time of 1 hour is reasonable to allow insertion of control rods to restore compliance, and is appropriate relative to the low probability of a CRDA occurring with the control rods out of sequence.
| |
| SURVEILLANCE SR 3.1.6.1 REQUIREMENTS The control rod pattern is periociicaily verified to be in compliance with the BPWS at a 24 hour Frequency, ensuring the assumptions of the CRDA The Surveillance analyses are met. The 24 hour Frequency of this Surveillance \\*as Frequency is developed considering that the primary check of the control rod pattern controlled under the compliance with the BPVVS is performed by the RPG (LCO 3.3.2.1 ). The Surveiliance
| |
| * RPC provides control rod blocks to enforce the required control rod Frequency !:ontro! sequence and is required to be OPERABLE when operating at Program. :s:: 10% RTP.
| |
| REFERENCES 1. NEDE-24011-P-A, "GE Standard Application for Reactor Fuel, GESTAR 11" (latest approved revision).
| |
| : 2. USAR, Section 15.4.9.
| |
| : 3. NUREG-0979, "NRC Safety Evaluation Report Related to the Final Design Approval of the GESSAR II BWR/6 Nuclear Island Design, Docket No. 50-447," Section 4.2.1.3.2, April 1983.
| |
| : 4. NUREG-0800, "Standard Review Plan," Section 15.4.9, "Radiological Consequences of Control Rod Drop Accident (BWR),"
| |
| Revision 2, July 1981.
| |
| (continued)
| |
| RIVER BEND B 3.1-35 Revision No. 6-13
| |
| | |
| SLC System B 3.1.7 BASES (continued)
| |
| SURVEILLANCE SR 3.1.7.1 and SR 3.1.7.2 REQUIREMENTS SR 3.1.7.1 and SR 3.1.7.2 are 24 hour Surveillances, verify~ certain characteristics of the SLC System (e.g., the volume and temperature of the borated solution in the storage tank), thereby ensuring the SLC System OPERABILITY without disturbing normal plant operation. These Surveillances ensure the proper borated solution and temperature, including the temperature of the pump suction piping, are maintained.
| |
| Maintaining a minimum specified borated solution temperature is important in ensuring that the boron remains in solution and does not precipitate out in the storage tank or in the pump suction piping. +he 24 hour Frequency of these SRs is based on operating experience that The Surveillance has shown there are relatively slow variations in the measured parameters Frequencies are of volume and temperature.
| |
| controlled under the Surveii!ance SR 3.1.7.3 and SR 3.1.7.5 Frequency Control Program. The requirements of 10 CFR 50.62 (Ref. 1) are met by the use of a sodium pentaborate solution enriched in the 8-1 O isotope (80 atom percent 8-1 O).
| |
| SR 3.1.7.3 determines whether the sodium pentaborate concentration, in conjunction with the 8-1 O enrichment, is within limits to meet the requirements of 10 CFR 50.62 (Ref. 1).
| |
| SR 3.1. 7.5 ensures that the* parameters used in the determination of sodium pentaborate concentration are within limits. The available solution volume is the solution volume above the pump suction penetration. This Surveillance requires an examination of the sodium pentaborate solution by using chemical analysis to' ensure the proper weight of 8-10 exists in the storage tank. SR 3.1.7.5 must be performed anytime boron or water is added to the storage tank solution to establish that the weight of 8-10 is within the specified limits. This SurveillanceSR 3. 'i. 7 .5 must aiso be performed anytime the solution temperature is restored to;::: 45°F, to ensure no significant boron precipitation occurred.
| |
| (continued)
| |
| RIVER BEND B 3.1-41 Revision No. 5-6
| |
| | |
| SLC System B 3.1.7 BASES SURVEILLANCE SR 3.1.7.3 and SR 3.1.7.5 (continued)
| |
| REQUIREMENTS The 31 day Frequency of these Surveillances is appropriate because of The time interval _/1 the relatively slow variation of boron concentration bet\veen surveillances.
| |
| based Surveillance Frequencies are SR 3.1.7.4 and SR 3.1.7.6 controlled under the Surveillance SR 3.1.7.4 verifies the continuity of the explosive charges in the injection Frequency Control valves to ensure proper operation will occur if required. The 31 day Program, Frequency is based on operating experience that has demonstrated the reliability of the explosive charge continuity.
| |
| <Cornbine ~ S R 3.1.7.6 verifies each valve in the system is in its correct position, but paragraphs and does not apply to the squib (i.e., explosive) valves. Verifying the correct delete line space> alignment for manual, power operated, and automatic valves in the SLC System flow path ensures that the proper flow paths will exist for system operation. A valve is also allowed to be in the nonaccident position, provided it can be aligned to the accident position from the control room, or locally by a dedicated operator at the valve controls. This is acceptable since the SLC System is a manually initiated system. This Surveillance does not apply to valves that are locked, sealed, or otherwise secured in position, since they were verified to be in the correct position prior.to locking, sealing, or securing. This verification of valve alignment does not The Surveillance apply to valves that cannot be inadvertently misaligned, such as check Frequencies are valves. This SR does not require any testing or valve manipulation; controiled under the rather, it involves verification that those valves capable of being Survelllance mispositioned are in the correct positions. The 31 day Frequency is Frequency Control based on engineering judgment and is consistent with the procedural Program.
| |
| controls governing valve operation that ensure correct valve positions.
| |
| (continued)
| |
| RIVER BEND B 3.1-42 Revision No. 1
| |
| | |
| . SLC System B 3.1.7 BASES SURVEILLANCE SR 3.1.7.7 REQUIREMENTS (continued) Demonstrating each SLC System pump develops a flow rate :2: 41.2 gpm at a discharge pressure :2: 1250 psig ensures that pump performance has not degraded during the fuel cycle. This minimum pump flow rate requirement ensures that, when combined with the sodium pentaborate solution concentration requirements, the rate of negative reactivity insertion from the SLC System will adequately compensate for the positive reactivity effects encountered during power reduction, cooldown of the moderator, and xenon decay. This test confirms one point on the pump design curve, and is indicative of overall performance. Such inservice inspections confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. The Frequency of this Surveillance is in accordance with the lnservice Testing Program.
| |
| SR 3.1.7.8 This Surveillance ensures that there is a functioning flow path from the boron solution storage tank to the RPV, including the firing of an explosive valve. The replacement charge for the explosive valve shall be from the same manufactured batch as the one fired or from another batch that has been certified by having one of that batch successfully fired. Other administrative controls, such as those that limit the shelf life of the explosive charges, must be followed. The pump and explosive valve tested should be alternated such that both complete flow paths are tested every 48 months, at alternating 24 month intervals. The Surveillance may be performed in separate steps to prevent injecting boron into the RPV.
| |
| An acceptable method for verifying flow from the pump to the RPV is to pump demineralized water from a test tank through one SLC subsystem and into the RPV. In order to pump this water, the test valve 1 C41 *F031 is open. A system initiation signal (which normally signals the 1C41 *F001 The Surveillance storage tank suction valve) is generated with the test valve open and Frequency is
| |
| * verification is made that the storage tank suction valve remains closed.
| |
| controlled under the The 24 month Frequency is based on the need to perform this Surveillance Surveillance under the conditions that apply during a plant outage and the Frequency Control potential for an unplanned transient if the Surveillance were performed Prograrn.
| |
| with the reactor at po1.ver.
| |
| (continued)
| |
| RIVER BEND B 3.1-43 Revision No. 143
| |
| _J
| |
| | |
| SDV Vent and Drain Valves B 3.1.8 BASES ACTIONS C.1 (continued)
| |
| Time of 12 hours is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE SR 3.1.8.1 REQUIREMENTS During normal operation, th_e SDV vent and drain valves should be in the open position (except when performing SR 3.1.8.2) to allow for drainage of the SDV piping. Verifying that each valve is in the open position ensures that the SDV vent and drain valves will perform their intended function during normal operation. This SR does not require any testing or valve manipulation; rather, it involves verification that the valves are in the correct position. The 31 day Frequency is based on engineering judgment and is consistent with the procedural controls governing valve The Surveillance operation, which ensure correct valve positions. Improper valve position Freq~1ency is (closed) would not affect the isolation function.
| |
| controlled under the Surveillance SR 3.1.8.2 Frequency Control Program. During a scram, the SDV vent and drain valves should close to contain the reactor water discharged to the SDV piping. Cycling each valve through its complete range of motion (closed and open) ensures that the valve will function properly during a scram. The 92 day Frequency is based on operating experience and takes into account the level of redundancy in the system design.
| |
| SR 3.1.8.3 SR 3.1.8.3 is an integrated test of the SDV vent and drain valves to verify total system performance. After receipt of a simulated or actual scram signal, the closure of the SDV vent and drain valves is verified. The closure time of 30 seconds after a receipt of a scram signal is based on the bounding leakage case evaluated in the accident analysis. Similarly, after receipt of a simulated or actual scram (continued)
| |
| RIVER BEND B 3.1-48 Revision No. O
| |
| | |
| SDV Vent and Drain Valves B 3.1.8 BASES SURVEILLANCE SR 3.1.8.3 (continued)
| |
| REQUIREMENTS reset signal, the opening of the SDV vent and drain valves is verified. The LOGIC SYSTEM FUNCTIONAL TEST in LCO 3.3.1.1 and the scram time The Surveillance testing of control rods in LCO 3.1.3, "Control Rod OPERABILITY," overlap Frequency is this Surveillance to provide complete testing of the assumed safety controlled under the function. The 24 month Frequency is based on the need to perform this Surveillance Surveillance under the conditions that apply during a plant outage and the Frequency Control potential for an unplanned transient if the Surveillance were performed Program. vvith the reactor at power.
| |
| REFERENCES 1. USAR, Section 4.6.1.1.2.4.2.5.
| |
| : 2. 10 CFR 50.67.
| |
| : 3. NUREG-0803, "Generic Safety Evaluation Report Regarding Integrity of BWR Scram System Piping," August 1981.
| |
| RIVER BEND B 3.1-49 Revision No. 143
| |
| | |
| APLHGR B 3.2.1 BASES (continued)
| |
| ACTIONS If any APLHGR exceeds the required limit, an assumption regarding an initial condition of the OBA and transient analyses may not be met.
| |
| Therefore, prompt action is taken to restore the APLHGR(s) to within the required limit(s) such that the plant will be operating within analyzed conditions and within the design limits of the fuel rods. The 2 hour Completion Time is sufficient to restore the APLHGR(s) to within its limit and is acceptable based on the low probability of a transient or OBA occurring simultaneously with the APLHGR out of specification.
| |
| If the APLHGR cannot be restored to within its required limit within the associated Completion Time, the plant must be brought to a MODE or*
| |
| other specified condition in which the LCO does not apply. To achieve this status, THERMAL POWER must be reduced to < 23.8% RTP within 4 hours. The allowed Completion Time is reasonable, based on operating experience, to reduce THERMAL POWER to < 23.8% RTP in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE SR 3.2.1.1 REQUIREMENTS APLHGRs are required to be initially calculated within 12 hours after THERMAL POWER is~ 23.8% RTP and then every 24 hoursperiodically thereafter. They are compared to the specified limits in the COLR to ensure that the reactor is operating within the assumptions of the safety analysis. The 24 hour Frequency is based on both engineering judgment and reoognition of the slovmess of ohanges in power distribution under normal oonditions. The 12 hour allowance after THERMAL POWER
| |
| ~ 23.8% RTP is achieved is acceptable given the large inherent margin to operating limits at low power levels. ~ , - - - - - - - - - - - - - - - - .
| |
| REFERENCES 1. NEDE-24011-P-A, "General Electric Standard Application for Reactor Fuel, GESTAR-11" (latest approved revision).
| |
| : 2. USAR, Chapter 4, Appendix 48.
| |
| (continued)
| |
| The time interval based SurJeillance Frequency -
| |
| is controlled under the Surveillance Frequency Control Program.
| |
| RIVER BEND B 3.2-3 Revision No. 6-4
| |
| | |
| 1 MCPR B 3.2.2 BA~ES (continued)
| |
| SURVEILLANCE SR 3.2.2.1 REQUIREMENTS The MCPR is required to be initially calculated within 12 hours after THERMAL POWER is 2 23.8% RTP and then every 24 hoursperiodicaliy thereafter. It is compared to the specified limits in the COLR to ensure that the reactor is operating within the assumptions of the safety analysis.
| |
| The 24 hour Frequency is based on both engineering judgment and recognition of the slovmess of changes in po1Ner distribution during normal operation. The 12 hour allowance after THERMAL POWER reaches 2 23.8% RTP is acceptable given the large inherent margin to operating limits at low power levels.
| |
| REFERENCES 1. NUREG-0562, "Fuel Rod Failures As A Consequence of Nucleate Boiling or Dry Out," June 1979.
| |
| : 2. XN-NF-80-19(P)(A) Volume 3, Revision 2, "Exxon Nuclear Methodology for Boiling Water Reactors THERM EX: Thermal Limits Methodology Summary Description," January 1987.
| |
| : 3. USAR, Chapter 4, Appendix 48.
| |
| : 4. USAR, Chapter 15, Appendix 1.58.
| |
| : 5. XN-NF-80-19(P)(A) Volume 1, "Exxon Nuclear Methodology for Boiling Water Reactors - Neutronic Methods for Design and Analysis," March 1983 (As Supplemented).
| |
| RIVER BEND B 3.2-8 Revision No. 6-15
| |
| | |
| LHGR B 3.2.3 BASES ACTIONS* 8.1 (continued)
| |
| Completion Time is reasonable, based on operating experience, to reduce THERMAL POWER to < 23.8% RTP in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE SR 3.2.3.1 REQUIREMENTS The LHGRs are required to be initially calculated within 12 hours after THERMAL POWER is 2: 23.8% RTP and then every 24 hoursperioclically thereafter. They are compared with the specified limits in the COLR to ensure that the reactor is operating within the assumptions of the safety analysis. The 24 hour Frequency is based on both engineering judgment
| |
| . and recognition of the slowness of changes in povver distribution under normal conditions. The 12 hour allowance after THERMAL POWER 2: 23.8% RTP.is achieved is acceptable given the large inherent margin to operating limits at lower power levels.
| |
| REFERENCES 1. NEDE-24011-P-A, "General Electric Standard Application for Reactor Fuel, GESTAR-11" (latest approved revision).
| |
| : 2. USAR, Chapter 4, Appendix 48.
| |
| : 3. NUREG-0800, "Standard Review Plan," Section 4.2, II.A.2(g),
| |
| Revision 2, July 1981.
| |
| RIVER BEND B 3.2-11 Revision No. 6-4
| |
| | |
| FCBB B 3.2.4 BASES (continued)
| |
| SURVEILLANCE SR 3.2.4.1 REQUIREMENTS Verifying FCBB ~ 1.0 is required to ensure th_e reactor is operating within the assumptions of the safety analysis. The boiling boundary limit is established to ensure that the core will remain stable during normal reactor operations in the Restricted Region of the power and flow map defined in the COLR which may otherwise be susceptible to 1
| |
| neutronic/thermal hydraulic instabilities.
| |
| FCBB is required to be verified every 24 hoursperiodica!ly while operating This Suri1ei!lance in the Restricted Region defined in the COLR. The 24 hour Frequency is based on both engineering judgment and recognition ofthe slow rate of change in povver distribution during normal operation.
| |
| The second Frequency requires FCBB to be within the limit within* 15 Program. minutes following an unexpected transient. The verification of the FCBB is required as a result of the possibility that the unexpected transient results in the limit not being met. The 15 minute frequency is based on both engineering judgment and the availability of the PBDS to provide the operator with information regarding the potential imminent onset of neutronic/thermal hydraulic instability. The 15 minute Frequency for this SR is not to be used to delay entry into Condition B following an unexpected reduction in feedwater heating, recirculation pump trip, recirculation pump down shift to slow speed, or significant flow control valve closure (small changes in flow control valve position are not considered significant). The action to exit the Restricted Region in Condition B is required following unplanned events that occur while operating in the region and can result in significant loss of stability margin.
| |
| During such unplanned events, adherence to the FCBB limit cannot be assured. Therefore, continued operation in the restricted Region is not appropriate:
| |
| ( continued)
| |
| RIVER BEND B 3.2-17 Revision No. 4-8
| |
| /
| |
| | |
| RPS Instrumentation B 3.3.1.1 BASES.
| |
| SURVEILLANCE As noted at the beginning of the SRs, the SRs for each RPS REQUIREMENTS instrumentation Function are located in the SRs column of Table 3.3.1.1-1.
| |
| The Surveillances are modified by a Note to indicate that, when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains trip capability. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken. This Note is based on the RPS reliability analysis (Ref. 9) assumption of the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour testing allowance does not significantly reduce the probability that the RPS will trip when necessary.
| |
| SR 3.3.1.1.1 Performance of the CHANNEL CHECK once every 12 hours ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift on one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
| |
| Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication The Surveillance that the instrument has drifted outside its limit.
| |
| Frequency is controlled under the The Frequency is based upon operating experience that demonstrates Surveiilance channel failure is rare. The CHANNEL CHECK supplements less formal, Frequency c:ontrol but more frequent, checks of channels during normal operational use of Program. the displays associated with the channels required by the LCO.
| |
| (continued)
| |
| RIVER BEND B 3.3-24 Revision No. 1
| |
| | |
| RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.2 REQUIREMENTS (continued) To ensure that the APRMs are accurately indicating the true core average power, the APRMs are calibrated to the reactor power calculated from a heat balance. The frequency of once per 7 days is based on minor changes in LPRM sensitivity, which could affect the APRM reading between The Surveillance performances of SR 3.3.1.1.8.
| |
| Frequency is controlled under tr1e A restriction to satisfying this SR when < 23.8% RTP is provided that Surveillance requires the SR to be met only at 23.8% RTP because it is difficult to Frequency Control accurately maintain APRM indication of core THERMAL POWER consistent FJrogram. with a heat balance when< 23.8% RTP. At low power levels, a high degree of accuracy is unnecessary because of the large inherent margin to thermal limits (MCPR and APLHGR). At 23.8% RTP, the Surveillance is required to have been satisfactorily performed within the last 7 days,in accordance with SR 3.0.2. A Note is provided which allows an increase in THERMAL POWER above 23.8% if the eay-Frequency is not met per SR 3.0.2. In this event, the SR must be performed within 12 hours after reaching or exceeding 23.8% RTP. Twelve hours is based on operating experience and in consideration of providing a reasonable time in which to complete the SR.
| |
| SR 3.3.1.1.3 The Average Power Range Monitor Flow Biased Simulated Thermal Power-High Function uses a trip level generated by the flow control trip reference card based on the recirculation loop drive flow. The drive flow is adjusted by a digital algorithm according to selected drive flow alignment dip switch settings. This SR sets the flow control trip reference card to ensure the drive flow alignment used results in the appropriate trip level being generated from the digital components of the card.
| |
| The Frequency of once following a refueling outage is based on the expectation that any change in the core flow to drive flow functional relationship during power operation would be gradual and (continued)
| |
| RIVER BEND B 3.3-25 Revision No. 6-4
| |
| | |
| RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.4 REQUIREMENTS (continued) A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.
| |
| Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.
| |
| As noted, SR 3.3.1.1.4 is not required to be performed when entering MODE 2 from MODE 1 since testing of the MODE 2 required IRM and APRM Functions cannot be performed in MODE 1 without utilizing jumpers, lifted leads, or movable links. This allows entry into MODE 2 if the +-lay-Frequency is not met per SR 3.0.2. In this event, the SR must The .Surveiilan:::e be performed within 12 hours after entering MODE 2 from MODE 1.
| |
| Frequency is Twelve hours is based on operating experience and in consideration of controlled under tl1e providing a reasonable time in which to complete the SR.
| |
| Surveillance Frequency Control /\ Frequency of 7 days provides an acceptable level of system average Program. availability over the Frequency interval and is based on reliability analysis (Ref. 9).
| |
| SR 3.3.1.1.5 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended Function. A Frequency of 7 days provides an acceptable level of system average availability over the Frequency and is based on the reliability analysis of Reference 9. (The Manual Scram Function's CHANNEL FUNCTIONAL TEST Frequency v,as credited in the analysis to extend many automatic scram Functions' Frequencies.)
| |
| * SR 3.3.1.1.6 and SR 3.3.1.1.7 These Surveillances are established to ensure that no gaps in neutron flux indication exist from subcritical to power operation for monitoring core reactivity status. The overlap between SRMs and IRMs is required to be demonstrated to ensure that reactor power will not be increased into a region without adequate neutron flux indication. This is (continued)
| |
| RIVER BEND B 3.3-26 Revision No. 4-8
| |
| | |
| RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.6 and SR 3.3.1.1.7 (continued)
| |
| REQUIREMENTS required prior to withdrawing SRMs from the fully inserted position since indication is being transitioned from the SRMs to the IRMs.
| |
| The overlap between IRMs and APRMs is of concern when reducing power into the IRM range. On power increases, the system design will prevent further increases (initiate a rod block) if adequate overlap is not maintained.
| |
| Overlap between IRMs and APRMs exists when sufficient IRMs and APRMs concurrently have onscale readings such that the transition between MODE 1 and MODE 2 can be made without either APRM downscale rod block, or IRM upscale rod block. Overlap between SRMs and IRMs similarly exists when, prior to withdrawing the SRMs from the fully inserted position, IRMs are above 2/40 on Range 1 before SRMs have reached the upscale rod block.
| |
| As noted, SR 3.3.1.1.7 is only required to be met during entry into MODE 2 from MODE 1. That is, after the overlap requirement has been met and indication has transitioned to the IRMs, maintaining overlap is not required (APRMs may be reading downscale once in MODE 2).
| |
| If overlap for a group of channels is not demonstrated (e.g., IRM/APRM overlap), the reason for the failure of the Surveillance should be The Surveillance determined and the appropriate channel(s) declared inoperable. Only Frequency of SR 3.3.i.1.7is controlled under the Survelllance Frequency Control
| |
| !\those appropriate channel(s) that are required in the current MODE or condition should be declared inoperable.
| |
| /\ Frequency of 7 days is reasonable based on engineering judgment and the reliability of the IRMs and APRMs.
| |
| Program.
| |
| SR 3.3.1.1.8 LPRM gain settings are determined from the local flux profiles measured by the Traversing lncore Probe (TIP) System. This establishes the relative local flux profile for appropriate representative input to the APRM System. The 2000 MVVD/T Frequency is based on NA 200 and ~JA 300 LPRM operating experience. Nuclear Instrumentation, power distribution and other uncertainties are combined in Framatome-ANP's analysis to determine the MCPR Safety Limit (Ref. USAR Section 4.4).
| |
| (continued)
| |
| The Surveillance Frequency is controlled under -
| |
| the Surveillance Frequency Controi Program.
| |
| RIVER BEND B 3.3-27 Revision No. 6-15
| |
| | |
| I RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.9 and SR 3.3.1.1.12 REQUIREMENTS (continued) A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology. The 92 day Frequency of SR 3.3.1.1.9 is based on the reliability analysis of Reference 9.
| |
| For Functions 9 and 10 the CHANNEL FUNCTIONAL TEST shall include the turbine first stage pressure instruments.
| |
| * The 24 month Frequency is based on the need to perform this
| |
| *rhe Surveillance Surveillance under the conditions that apply during a plant outage and the Frequencies are potential for an unplanned transient if the Surveillance v:ere performed c.or.trol!ed under the with the reactor at povver.
| |
| Surveillance Frequency Control Prograrn.
| |
| SR 3.3.1.1.10 The calibration of trip units provides a check of the actual trip setpoints.
| |
| The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in Table 3.3.1.1-1. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be readjusted to be equal to or more conservative than accounted for in the appropriate setpoint methodology.
| |
| The Surveil!ance For Functions 9 and 1O all applicable trip unit setpoints must be calibrated Frequency is including the turbine first stage pressure instrument trip unit setpoints.
| |
| controlled under the Surveillance The Frequency of 92 days for SR 3.3.1.1.10 is based on the reliability Frequency Control analysis of Reference 9.
| |
| Program.
| |
| (continued)
| |
| RIVER BEND B 3.3-28 Revision No. 143
| |
| | |
| RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE SR 3.3.1.1.11, SR 3.3.1.1.13, and SR 3.3.1.1.17 REQUIREMENTS (continued) A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.
| |
| For Functions 9 and 10 the CHANNEL CALIBRATION shall include the turbine first stage pressure instruments.
| |
| Note 1 states that neutron detectors and flow reference transmitters are excluded from CHANNEL CALIBRATION because of the difficulty of simulating a meaningful signal. Changes in neutron detector sensitivity are compensated for by performing the Ga-y-calorimetric calibration (SR 3.3.1.1.2) and the 2000 MWD/T LPRM calibration against the TIPs (SR 3.3.1.1.8). Calibration of the flow reference transmitters is performed on an 24 month Frequencyperiodically (SR 3.3.1.1.17). A second Note is provided that requires the APRM and IRM SRs to be performed within 12 hours of entering MODE 2 from MODE 1. Testing of the MODE 2 APRM and IRM Functions cannot be performed in MODE 1 without utilizing jumpers, lifted leads or movable links. This Note allows entry into MODE 2 from MODE 1 if the associated Frequency is not met per SR 3.0.2.
| |
| Twelve hours is based on operating experience and in consideration of providing a reasonable time in which to complete the SR. The Frequency of SR 3.3.1.1.11, SR 3.3.1.1.13, and SR 3.3.1.1.17 is based upon the assumption of the magnitude of equipment drift in the setp_oint analysis.
| |
| Note 3 states that the digital components of the flow control trip reference card are excluded from CHANNEL CALIBRATION of Function 2.b, Average Power Range Monitor Flow Biased Simulated Thermal Power-High. The analog output potentiometers of the flow control trip reference card are not excluded. The flow control trip reference card has an automatic self-test feature which periodically tests the hardware which performs the digital algorithm. Exclusion of the digital components of the flow control trip reference card from CHANNEL CALIBRATION of Function 2.b is based on the conditions required to perform the test and the likelihood of a change in the status of these components not being detected.
| |
| t (continued)
| |
| ....-----_J The Surveillance Frequencies are controllecl under the Surveillance Frequency Control Program.
| |
| RIVER BEND B 3.3-29 Revision No. 143
| |
| | |
| RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE REQUIREMENTS SR 3.3.1.1.14 (continued)
| |
| The Average Power Range Monitor Flow Biased Simulated Thermal Power-High Function uses an electronic filter circuit to generate a signal proportional to the core Tl-,IERMAL POWER from the APRM neutron flux signal. This filter circuit is representative of the fuel heat transfer dynamics that produce the relationship between the neutron flux and the core THERMAL POWER. The filter time constant is specified in the COLR and must be verified to ensure that the channel is accurately reflecting the desired parameter. The Frequency of 24 months is based The Surveillance on engineering judgment and reliability of the components.
| |
| Frequency is controiled under the SR 3.3.1.1.15 Surveillance Frequency Control The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the Program. OPERABILITY of the required trip logic for a specific channel. The functional testing of control rods, in LCO 3.1.3, "Control Rod OPERABILITY," and SDV vent and drain valves, in LCO 3.1.8, "Scram Discharge Volume (SDV) Vent and Drain Valves," overlaps this Surveillance to provide complete testing of the assumed safety function.
| |
| The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.
| |
| SR 3.3.1.1.16 This SR ensures that scrams initiated from the Turbine Stop Valve Closure and Turbine Control Valve Fast Closure, Trip Oil Pressure-Low Functions will not be inadvertently bypassed when THERMAL POWER is
| |
| ;::,: 40% RTP. This involves calibration of the bypass channels. Adequate margins for the instrument setpoint methodology are incorporated into the actual setpoint. Because main turbine bypass flow can affect this setpoint nonconservatively (THERMAL POWER is derived from turbine first stage pressure), the main turbine bypass valves must remain closed at THERMAL POWER ;::,: 40% RTP to ensure that the calibration remains valid.
| |
| (continued)
| |
| RIVER BEND B 3.3-30 Revision No. 143
| |
| | |
| RPS Instrumentation B 3.3.1.1 BASES I
| |
| SURVEILLANCE SR 3.3.1.1.16 (continued)
| |
| REQUIREMENTS If any bypass channel setpoint is nonconservative (i.e., the Functions are bypassed at ~ 40% RTP, either due to open main turbine bypass valve(s) or other reasons), then the affected Turbine Stop Valve Closure and Turbine Control Valve Fast Closure, Trip Oil Pressure-Low Functions are considered inoperable. Alternatively, the bypass channel can be placed in the conservative condition (nonbypass). If placed in the nonbypass condition, this SR is met and the channel is considered OPERABLE.
| |
| Tile Surveillance The Frequency of 24 months is based on engineering judgment and Frequency is reliability of the components.
| |
| controlled under the Surveillance SR 3.3.1.1.18 Frequency Control Program. This SR ensures that th'e individual channel response times are less than or equal to the maximum values assumed in the accident analysis. The RPS RESPONSE TIME acceptance criteria are included in Reference 10.
| |
| As noted, neutron detectors are excluded from RPS RESPONSE TIME testing because the principles of detector operation virtually ensure an.
| |
| instantaneous response time.
| |
| RPS RESPONSE TIME tests are conducted on a 24 month STAGGERED TEST BASIS. Note 2 requires STAGGERED TEST BASIS Frequency to be determined based on 4 channels per trip system, in lieu of the 8 o channels specified in Table 3.3.1.1 1 for the MSIV Closure Function. This' Frequency is based on the logic interrelationships of the various channels required to produce an RPS scram signal. Therefore, staggered testing results in response time verification of these devices every 24 months.
| |
| REFERENCES 1. USAR, Figure 7.2-1.
| |
| I
| |
| : 2. USAR, Section 5.2.2.
| |
| : 3. USAR, Section 6.3.3.
| |
| (continued)
| |
| RIVER BEND B 3.3-31 Revision No. 143
| |
| | |
| SRM Instrumentation B 3.3.1.2 BASES SURVEILLANCE SR 3.3.1.2.1 and SR 3.3.1.2.3 (continued)
| |
| REQUIREMENTS Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication The Surveillance that the instrument has drifted outside its limit. "
| |
| Frequencies are controlled uncler the The Frequency of once every 12 hours for SR 3.3.1.2.1 is based on Surveillance operating experience that demonstrates channel failure is rare. While in Frequency Control MODES 3 and 4, reactivity changes are not expected; therefore, the 1
| |
| Program. 12 hour Frequency is relaxed to 24 hours for SR 3.3.1.2.3. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the channels required by the LCO.
| |
| SR 3.3.1.2.2 To provide adequate coverage of potential reactivity changes in the core, one SRM is required to be OPERABLE in the quadrant where CORE ALTERATIONS are being performed, and the other OPERABLE SRM must be in an adjacent quadrant containing fuel. Note 1 states that this SR is required to be met only during CORE ALTERATIONS. It is not required to be met at other times in MODE 5 since core reactivity changes are not occurring. This Surveillance consists of a review of plant logs to ensure that SRMs required to be OPERABLE for given CORE ALTERATIONS are, in fact, OPERABLE. In the event that only one SRM is required to be OPERABLE, per Table 3.3.1.2-1, footnote (b), only the The Surveillance a. portion of this SR is required. Note 2 clarifies that more than one of the Frequency is three requirements can be met by the same OPERABLE SRM. +l=le controlled under the 12 hour Frequency is based upon operating experience and supplements Survel!lance operational controls over refueling activities, which include steps to ensure Frequency Control that the SRMs required by the LCO are in the proper quadrant.
| |
| Program.
| |
| SR 3.3.1.2.4 This Surveillance consists of a verification of the SRM instrument readout to ensure that the SRM reading is greater than a specified minimum count rate. This ensures that the detectors are indicating count rates indicative of neutron flux levels within the core. Verification of the signal to
| |
| ( continued)
| |
| RIVER BEND B 3.3-37 Revision No. 0
| |
| | |
| ' SRM Instrumentation B 3.3.1.2 BASES SURVEILLANCE SR 3.3.1.2.4 (continued)
| |
| REQUIREMENTS noise ratio also ensures that the detectors are inserted to a normal operating level. In a fully withdrawn condition, the detectors are sufficiently removed from the fueled region of the core to essentially eliminate neutrons from reaching the detector. Any count rate obtained while fully withdrawn is assumed to be "noise" only. With few fuel assemblies loaded, the SRMs will not have a high enough count rate to satisfy the SR. Therefore, allowances are made for loading sufficient "source" material, in the form of irradiated fuel assemblies, to establish the minimum count rate.
| |
| To accomplish this, the SR is modified by a Note that states that the count rate is not required to be met on an SRM that has less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies are in the associated core quadrant. With four or less fuel assemblies loaded around each SRM and no other fuel assemblies in the associated quadrant, even with a control rod withdrawn the configuration will not be The Surveillance critical.
| |
| Frequencies are controlled under the The Frequency is based upon channel redundancy and other information Surveillance available in the control room, and ensures that the required channels are Frequency Control frequently monitored *,a,rhile core reactivity changes are occurring. \/Vhen Program. no reactivity changes are in progress, the Frequency is relaxed from 12 hours to 24 hours.
| |
| SR 3.3.1.2.5 The Survei!/ance Performance of a CHANNEL FUNCTIONAL TEST demonstrates the Frequency is associated channel will function properly. The 31 day Frequency is based controlled under tile on operating experience and on other Surveillances (such as CHANNE;L Surveillance CHECK) that ensure proper functioning between CHANNEL Frequency Control FUNCTIONAL TESTS.
| |
| Program.
| |
| The Note to the Surveillance allows the Surveillance to be delayed until entry into the specified condition of the Applicability. The SR must be performed in MODE 2 within 12 hours of entering MODE 2 with IRMs on Range 2 or below. The allowance to enter the Applicability with the 31 day Frequency not met is reasonable, based on the limited time of 12 hours allowed after entering the Applicability and the (continued)
| |
| RIVER BEND B 3.3-38 Revision No. 0
| |
| | |
| SRM Instrumentation B 3.3.1.2 BASES SURVEILLANCE SR 3.3.1.2.5 (continued)
| |
| REQUIREMENTS inability to perform the Surveillance while at higher power levels. Although the Surveillance could be performed while on IRM Range 3, the plant would not be expected to maintain steady state operation at this power level. In this event, the 12 hour Frequency is reasonable, based on the SRMs being otherwise verified to be OPERABLE (i.e., satisfactorily performing the CHANNEL CHECK) and the time required to perform the Surveillances.
| |
| SR 3.3.1.2.6
| |
| . - - - - - - - - - - ,\
| |
| foe Surveillance Performance of a CHANNEL CALIBRATION verifies the performance of Frequency is the SRM detectors and associated circuitry. The Frequency considers the controlled under the plant conditions required to perform the test, the ease of performing the Surveiilance test, and the likelihood of a change in the system or component status.
| |
| Frequency Control The neutron detectors are excluded from the CHANNEL CALIBRATION Program because they cannot readily be adjusted. The detectors are fission chambers that are designed to have a relatively constant sensitivity over the range, and with an accuracy specified for a fixed useful life.
| |
| The Note to the Surveillance allows the Surveillance to be delayed until entry into the specified condition of the Applicability. The SR must be performed in MODE 2 within 12 hours of entering MODE 2 with IRMs on Range 2 or below. The allowance to enter the Applicability with the 24 month Frequency not met is reasonable, based on the limited time of 12 hours allowed after entering the Applicability and the inability to perform the Surveillance while at higher power levels. Although the Surveillance could be performed while on IRM Range 3, the plant would not be expected to maintain steady state operation at this power level. In this event, the 12 hour Frequency is reasonable, based on the SRMs being otherwise verified to be OPERABLE (i.e., satisfactorily performing the CHANNEL CHECK) and the time required to perform the Surveillances.
| |
| REFERENCES None.
| |
| RIVER BEND B 3.3-39 Revision No. 143
| |
| | |
| /
| |
| PBDS B 3.3.1.3 BASES ACTIONS C.1 (continued)
| |
| Actions to restart an idle recircula.tion loop, withdraw control rods or reduce recirculation flow may result in approaching unstable reactor conditions and are not allowed to be used to comply with this Required Action. Exit of the Monitored Region is accomplished by control rod insertion and/or recirculation flow increases. However, actions are 1
| |
| allowed provided the Fraction of Core Boiling Boundary (FCBB) is recently (within 15 minutes) verified to be :,:; 1.0. Recent verification of FCBB being met provides assurance that with the PBDS inoperable, planned decreases in recirculation drive flow should not result in significant degradation of core stability performance.
| |
| The specified Completion Time of 15 minutes ensures timely operator action to exit the region consistent with the low probability that reactor conditions exceed the initial conditions assumed in the safety analysis.
| |
| The time required to exit the Monitored Region will depend on existing plant conditions. Provided efforts are begun within 15 minutes and continued until the Monitored Region is exited, operation is acceptable based on the low probability of a transient which degrades stability performance occurring simultaneously with the required PBDS channel inoperable.
| |
| SURVEILLANCE SR 3.3.1.3.1 REQUIREMENTS During operation in the Restricted Region or the Monitored Region the PBDS Hi-Hi DR Alarm is relied upori to indicate conditions consistent with the imminent onset of neutronic/ thermal hydraulic instability. Verification This verification every 12 hours provides assurance of the proper jndication of the alarm during operation in the Restricted Region or the Monitored Region. The 12 hour Frequency supplements less formal, but The Surveillance more frequent, cheeks of alarm status during operation.
| |
| Frequency is controliecl under the SR 3.3.1.3.2 Sur,1eill2nce
| |
| *Frequency Performance of the CHANNEL CHECK every 12 hours ensures that a gross failure of instrumentation has not occurred. This CHANNEL CHECK is normally a comparison of the PBDS indication to the state of the annunciator, as well as comparison to the same parameter on (continued)
| |
| RIVER BEND B 3.3-399 Revision No. 4-8 J
| |
| | |
| PBDS B 3.3.1.3 BASES SURVEILLANCE SR 3.3.1.3.2 (continued)
| |
| REQUIREMENTS the other channel if it is available. It is based on the assumption that the instrument channel indication agrees with the immediate indication available to the operator, and that instrument channels monitoring the same parameter should read similarly. Deviations between the instrument channels could be an indication of instrument component failure. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL FUNCTIONAL TEST. Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability.
| |
| The 12 hour Frequency is based on operating experience that demonstrates ohannel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, oheoks of ohannels during normal operational use of the displays associated '.nith the qhannels
| |
| ,,required by the LCO.
| |
| SR 3.3.1.3.3 A CHANNEL FUNCTIONAL TEST is performed for the PBDS to ensure that the entire system will perform the intended function. The CHANNEL FUNCTIONAL TEST for the PBDS includes manual initiation of an internal test sequence and verification of appropriate alarm and inop conditions being reported.
| |
| Performance of a CHANNEL FUNCTIONAL TEST at a Frequency of 24 months verifies the performance of the PBDS and associated circuitry.
| |
| The Frequency considers the plant conditions required to perform the test, the ease of performing the test, and the likelihood of a change in the system or component status. The alarm circuit is designed to operate for over 24 months 'Nith sufficient accuracy on signal amplitude and signal timing considering environment, initial calibration and accuracy drift (Ref.
| |
| 2}.
| |
| REFERENCES 1. NEDO 32339, Revision 1, "Reactor Stability Long Term Solution:
| |
| Enhanced Option I-A," April 1998.
| |
| : 2. NED0-32339P-A, Supplement 2, "Reactor Stability Long Term Solution: Enhanced Option I-A Solution Design," April 1998.
| |
| RIVER BEND B 3.3-39h Revision No. 4-8 I
| |
| L_
| |
| | |
| Control Rod Block Instrumentation B 3.3.2.1 BASES SURVEILLANCE SR 3.3.2.1.1, SR 3.3.2.1.2, SR 3.3.2.1.3, and SR 3.3.2.1.4 REQUIREMENTS (continued) control rod block occurs. Proper operation of the RWL is verified by SR 3.3.2.1.1 which verifies proper operation of the two-notch withdrawal limit and SR 3.3.2.1.2 which verifies proper operation of the four-notch withdrawal limit. Proper operation of the RPG is verified by SR 3.3.2.1.3 and SR 3.3.2.1.4. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology. As noted, the SRs are not required to be performed until 1 hour after specified conditions are met (e.g., after any control rod is withdrawn in MODE 2).
| |
| This allows entry into the appropriate conditions needed to perform the required SRs ...The Frequencies are based on reliability analysis (Ref. 7).
| |
| The Surveillance Frequencies are controllecl the SR 3.3.2.1.5 Survei!iance The LPSP is the point at which the RPCS makes the transition between Frequency Control the function of the RPG and the RWL. This transition point is Program.
| |
| automatically varied as a function of power. This power level is inferred from the first stage turbine pressure (one channel to each trip system).
| |
| These power setpoints must be verified periodically to be within the Allowable Values. If any LPSP is nonconservative, then the affected Functions are considered inoperable. Since this channel has both upper and lower required limits, it is not allowed to be placed in a condition to enable either the RPG or RWL. Function. Because main turbine bypass steam flow can affect the LPSP nonconservatively for the RWL, the RWL Surveillance is considered inoperable with any main turbine bypass valves open. +AB Frequency is Frequency of 92 days is based on the setpoint methodology utilized for controlled uncle, the these channels.
| |
| Surveillance Frequency Control Program. SR 3.3.2.1.6 .
| |
| This SR ensures the high power function of the RWL is not bypassed when power is above the HPSP. The power level is inferred from turbine first stage pressure signals. Periodic testing of the HPSP channels is required to verify the setpoint to be less than or equal to the limit.
| |
| Adequate margins in accordan.ce with setpoint methodologies are included. If the HP-SP is nonconservative, then the *RwL is considered inoperable. Alternatively, the HPSP can be placed in the conservative condition (nonbypass). If placed (continued)
| |
| RIVER BEND B 3.3-46 Revision No. O
| |
| | |
| Control Rod Block Instrumentation B 3.3.2.1 BASES SURVEILLANCE SR 3.3.2.1.6 (continued)
| |
| REQUIREMENTS in the nonbypassed condition, the SR is met and the RWL would not be considered inoperable. Because main turbine bypass steam flow can affect the HPSP nonconservatively for the RWL, the RWL is considered inoperable with any main turbine bypass valve open. The Frequency of 92 days is based on the setpoint methodology utilized for these channels.
| |
| SR 3.3.2.1.7 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies that the channel responds to the measured parameter within the necessary range and accuracy.
| |
| CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations. Any setpoint adjustment shall be consistent with the assumptions of the current plant The Surveillance specific setpoint methodology.
| |
| Frequency ls contro!lecl under the The Frequency is based upon the assumption of the magnitude of Survei!lance equipment drift in the setpoint analysis.
| |
| Frequency Control Program.
| |
| SR 3.3.2.1.8 The CHANNEL FUNCTIONAL TEST for the Reactor Mode Switch-Shutdown Position Function is performed by attempting to withdraw any control rod with the reactor mode switch in the shutdown position and verifying a control rod block occurs.
| |
| As noted in the SR, the Surveillance is not required to be performed until 1 hour after the reactor mode switch is in the shutdown position, since testing of this interlock with the reactor mode switch in any other position cannot be performed without using jumpers, lifted leads, or movable limits.
| |
| This allows entry into MODES 3 and 4 if the 24 month Frequency is not met per SR 3.0.2.
| |
| The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance vvere performed with the reactor at power.
| |
| (continued)
| |
| RIVER BEND B 3.3-47 Revision No. 143
| |
| | |
| Control Rod Block Instrumentation B 3.3.2.1 BASES SURVEILLANCE SR 3.3.2.1.9 REQUIREMENTS (continued) LCO 3.1.3 and LCO 3.1.6 may require individual control rods to be bypassed in RAGS to allow insertion of an inoperable control rod or correction of a control rod pattern not in compliance with BPWS. With the control rods bypassed in the RAGS, the RPG will not control the movement of these bypassed control rods. Individual control rods may also be required to be bypassed to allow continuous withdrawal for determining the location of leaking fuel assemblies, adjustment of control rod speed, or control rod scram time testing. To ensure the proper bypassing and movement of those affected control rods, a second licensed operator or other qualified member of the technical staff must verify the bypassing and movement of these control rods is in conformance with applicable analyses. Compliance with this SR allows the RPG and RWL to be OPERABLE with these control rods bypassed.
| |
| REFERENCES 1. USAR, Section 7.6.1.7.
| |
| : 2. USAR, Section 15.4.2.
| |
| : 3. NEDE-24011-P-A, "General Electric Standard Application for Reload Fuel" (latest approved revision).
| |
| : 4. "Modifications to the Requirements for Control Rod Drop Accident Mitigating Systems," BWR Owners Group, July 1986.
| |
| : 5. NED0-21231, "Banked Position Withdrawal Sequence,"
| |
| January 1977.
| |
| : 6. NRG SER, Acceptance of Referencing of Licensing Topical Report NEDE-24011-P-A, "Ge*neral Electric Standard Application for Reactor Fuel, Revision 8, Amendment 17,"
| |
| December 27, 1987.
| |
| : 7. NEDC 30851 PA, "Technical Specification Improvement Analysis for BWR Control Rod Block Instrumentation,"
| |
| October 1988.
| |
| GE NE /\71 00019 01, "Reduction of Low Power Set Point for RBS Rod Pattern Control System." May 1996.
| |
| RIVER BEND B 3.3-48 Revision No. 6-13
| |
| | |
| PAM Instrumentation B 3.3.3.1 BASES ACT!ONS F.1 (continued)
| |
| Since alternate means of monitoring primary containment area radiation have been developed and tested, the Required Action is not to shut down the plant but rather to initiate action to prepare and submit a Special Report to the NRC. These alternate means may be temporarily installed if the normal PAM channel cannot b*e restored to OPERABLE status within the allotted time. The report provided to the NRC should discuss the alternate means used, describe the degree to which the alternate means are equivalent to the installed PAM channels, justify the areas in which they are not equivalent, and provide a schedule for restoring the normal PAM channels. The Special Report shall be submitted in accordance with 10 CFR _50.4 within 14 days of entering Condition F.
| |
| SURVEILLANCE The following SRs apply to each PAM instrumentation Function in REQUIREMENTS Table 3.3.3.1-1 except as noted.
| |
| SR 3.3.3.1.1 Performance of the CHANNEL CHECK once every 31 days ensures that a gross instrumentation failure has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
| |
| The high radiation instrumentation should be compared to similar plant instruments located throughout the plant.
| |
| Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including isolation, indication, and readability. If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. *
| |
| (continued)
| |
| RIVER BEND B 3.3-58 Revision No. O
| |
| | |
| r-.
| |
| PAM Instrumentation B 3.3.3.1 BASES SURVEILLANCE SR 3.3.3.1.1 (continued)
| |
| REQUIREMENTS
| |
| _,.The Frequency of 31 days is based upon plant operating experience with regard to channel OPERABILITY and drift, which demonstrates that failure of more than one channel of a given function in any 31 day interval is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of those displays associated with the required channels of this L:CO.
| |
| SR 3.3.3.1.2:.aM SR 3.3.3.1.3 For all Functions except the containment and dryNell hydrogen analyzers, a CHANNEL C/\LIBR/\TION is performed every 24 months, or approximately at every refueling. CHANNEL CALIBRATION is a complete check of the instrument loop including the sensor. The test verifies that the channel responds to the measured parameter with the necessary range and accuracy. The Frequency is based on operating experience and consistency with the typical industry refueling cycles.
| |
| * For the containment and dryi.vell hydrogen analyzers, the CHANNEL CALIBRATION is performed every 92 days. This Frequency is based on operating experience.
| |
| REFERENCES. 1. Regulatory Guide 1.97, "Instrumentation for Light-Water Cooled Nuclear Power Plants to Assess Plant and Environs Conditions During and Following an Accident," Revision 2, December 1980.
| |
| : 2. NRC Safety Evaluation Report, "Conformance to Regulatory Guide 1.97, Revision 2, River Bend Station, Unit 1," dated June 30, 1986.
| |
| : 3. USAR Section 7.5.
| |
| : 4. Technical Requirements Manual RIVER BEND B 3.3-59 Revision No. 143
| |
| _J
| |
| | |
| Remote Shutdown System 8 3.3.3.2 BASES ACTIONS A.1 (continued)
| |
| The Required Action is to restore the Function (both divisions, if applicable) to OPERABLE status within 30 days. The Completion Time is based on operating experience and the low probability of an event that would require evacuation of the control room.
| |
| 8.1
| |
| )
| |
| If the Required Action and associated Completion Time of Condition A are not met, the plant must be brought to ~ MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours. The allowed Completion Time is reasonable, based on operating experience, to reach the required MODE from full power conditions in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE SR 3.3.3.2.1 REQUIREMENTS Performance of the CHANNEL CHECK once every 31 days ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
| |
| Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication The Surveillance that the sensor or the signal processing equipment has drifted outside its Frequency is limit. As specified in the Surveillance, a CHANNEL CHECK is only controlled under the required for those channels that are normally energized.
| |
| Surveii!ance Frequency Control The Frequency is based upon plant operating experience that Program.
| |
| demonstrates channel failure is rare.
| |
| (continued)
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| /
| |
| RIVER BEND 8 3.3-63 Revision No. O
| |
| | |
| Remote Shutdown System B 3.3.3.2 BASES SURVEILLANCE SR 3.3.3.2.2 REQUIREMENTS (continued) SR 3.3.3.2.2 verifies each required Remote Shutdown System transfer switch and control circuit performs the intended function. This verification is performed from the remote shutdown panel and locally, as appropriate.
| |
| Operation of the equipment from the remote shutdown panel is not necessary. The surveillance can be satisfied by performance of a continuity check. This will ensure that if the control room becomes inaccessible, the plant can be placed and maintained in MODE 3 from the remote shutdown panel and the local control stations. However, this Surveillance is not required to be performed only during a plant outage.
| |
| The Surveillance Frequency is SR 3.3.3.2.3 controlled under the Surveillance CHANNEL CALIBRATION is a complete check of the instrument loop and Frequency Control the sensor. The test verifies the channel responds* to measured Program. parameter values with the necessary range and accuracy. Valve position Functions are excluded since channel performance is adequately
| |
| ~determined during performance of other valve surveillances.
| |
| REFERENCES 1. 10 CFR 50, Appendix A, GDC 19.
| |
| : 2. RBS Technical Requirements Manual.
| |
| RIVER BEND B 3.3-64 Revision No. 143
| |
| | |
| EOC-RPT Instrumentation B 3.3.4.1 BASES SURVEILLANCE SR 3.3.4.1.1 (continued)
| |
| REQUIREMENTS The CHANNEL FUNCTIONAL TEST shall include the turbine first stage pressure instruments.
| |
| The calibration of the turbine first stage pressure transmitter trip units provides a check of the actual trip setpoints. The channel must be declared inoperable if the setting is discovered to be less conservative than the Allowable Value specified in SR 3.3.4.1.5. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis.
| |
| Under these conditions, the setpoint must be readjusted to be equal to or more conservative than accounted for in the appropriate setpoint methodology.
| |
| The Frequency of 92 days is based on assumptions of the reliability The Surveiliance analysis (Ref. 5) and on the methodology included in the determination of Frequency is the trip setpoint.
| |
| controlled under the Surveillance Frequency Control SR 3.3.4.1.3 Program.
| |
| CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.
| |
| The CHANNEL CALIBRATION shall include the turbine first stage pressure instruments.
| |
| The Frequency is based upon the assumption of the magnitude of equipment drift in the setpoint analysis.
| |
| (continued)
| |
| RIVER BEND B 3.3-72 Revision No. 1
| |
| | |
| EOC-RPT Instrumentation B 3.3.4.1 BASES SURVEILLANCE SR 3.3.4.1.4 REQUIREMENTS (continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required trip logic for a specific channel. The system functional test of the pump breakers is included as a part of this test, overlapping the LOGIC SYSTEM FUNCTIONAL TEST; to provide complete testing of the associated safety function. Therefore, if a breaker is incapable of operating, the associated instrument channel would also be inoperable.
| |
| The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed
| |
| 'Nith the reactor at power.
| |
| This SR ensures that an EOC-RPT initiated from the TSV Closure and The Surveillance TCV Fast Closure, Trip Oil Pressure-Low Functions will not be Frequency is inadvertently bypassed when THERMAL POWER is~ 40% RTP. This controlled under the involves calibration of the bypass channels. Adequate margins for the .
| |
| Su1veiilance instrument setpoint methodologies are incorporated into the actual Frequency Control setpoint. Because main turbine bypass flow can affect this setpoint Program.
| |
| nonconservatively (THERMAL POWER is derived from first stage pressure), the main turbine bypass valves must remain closed at THERMAL POWER ~ 40% RTP to ensure that the calibration remains valid. If any bypass channel's setpoint is nonconservative (i.e., the Functions are bypassed at ~ 40% RTP either due to open main turbine bypass valves or othe,r reasons), the affected TSV Closure and TCV Fast Closure, Trip Oil Pressure-Low Functions are considered inoperable.
| |
| Alternatively, the bypass channel can be placed in the conservative condition (nonbypass). If placed in the nonbypass condition, this,SR is met and the channel considered OPERABLE.
| |
| (continued)
| |
| RIVER BEND B 3.3-73 Revision No. 143
| |
| | |
| EOC-RPT Instrumentation B 3.3.4.1 BASES SURVEILLANCE SR 3.3.4.1.6 REQUIREMENTS (continued) This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the accident analysis. The EOC-RPT SYSTEM RESPONSE TIME acceptance criteria are included in Reference 6.
| |
| A Note to the Surveillance states that breaker interruption time may be assumed from the most recent performance of SR 3.3.4.1. 7. This is allowed since the time to open the contacts after energization of the trip coil and the arc suppression time are short and do not appreciably change, due to the design of the breaker opening device and the fact that the breaker is not routinely cycled.
| |
| EOG RPT SYSTEM RESPONSE TIME tests are conducted on an 24 month STAGGERED TEST BASIS. Each test shall include at least the logic of one type of channel input (Turbine Stop Valve Closure or Turbine Control Valve Fast Closure, Trip Oil Pressure Lov,0 such that both types of channel inputs are tested at least once per 48 months. Response
| |
| * times cannot be determined at power because operation of final actuated devices is required. Therefore, this Frequency is consistent 'Nith the typical industry refueling cycle.
| |
| The Surveillance SR 3.3.4.1.7 Frequency is controlied under the This SR ensures that the RPT breaker interruption time is provided to the Survei!lance EOC-RPT SYSTEM RESPONSE TIME test. Breaker Interruption time is Frequency Control defined as Breaker Response time plus Arc Suppression time. Breaker Program. Response is the time from application of voltage to the trip coil until the arcing contacts separate. Arc Suppression is the time from arcing contact separation until the complete suppression of the electrical arc across the open contacts. Breaker Response shall be verified by testing to be within the manufacturer's design response time. Testing of the breaker response time verifies the design interruption time to be:,; five cycles (83.3 ms).
| |
| Breaker arc suppression shall be validated by visual observation of puffer performance and insulation testing of the breaker arc chutes. The 60
| |
| * month Frequency of (continued)
| |
| RIVER BEND B 3.3-74 Revision No. 143
| |
| | |
| EOC-RPT Instrumentation B 3.3.4.1 I I (continued) I BASES SURVEILLANCE SR 3.3.4.1.7 (continued)
| |
| REQUIREMENTS the testing is based on the difficulty of performing the test and the reliability of the circuit breakers.
| |
| REFERENCES 1. USAR, Section 7 .6.1.1.
| |
| : 2. USAR, Section 5.2.2.
| |
| : 3. USAR, Sections 15.1.1, 15.1.2, and 15 ..1.3.
| |
| : 4. USAR, Sections 15.2.2, 15.2.3 and 15.2.5.
| |
| : 5. GENE-770-06-1, "Bases for Changes To Surveillance Test Intervals And Allowed Out-Of-Service Times For Selected Instrumentation Technical Specifications," February 1991.
| |
| : 6. RBS Technical Requirements Manual.
| |
| RIVER BEND B 3.3-75 Revision No. 2-1
| |
| | |
| ATWS-RPT Instrumentation B 3.3.4.2 BASES (continued)
| |
| ACTIONS D.1 and D.2 (continued) performs the intended Function of the instrumentation (Required Action D.1). The allowed Completion Time of 6 hours is reasonable, based on operating experience, both to reach MODE 2 from full power conditions and to remove a recirculation pump from service in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE The Surveillances are modified by a Note to indicate that when a REQUIREMENTS channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains ATWS-RPT trip capability. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken. This Note is based on the reliability analysis (Ref. 2) assumption of the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour testing allowance does not significantly reduce the probability that the recirculation pumps will trip when necessary.
| |
| SR 3.3.4.2.1 Performance of the CHANNEL CHECK once every 12 hours ensures that gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
| |
| Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit.
| |
| (continued)
| |
| RIVER BEND B 3.3-82 Revision No. 0
| |
| | |
| ATWS-RPT Instrumentation B 3.3.4.2 BASES (continued)
| |
| SURVEILLANCE SR 3.3.4.2.1 (continued)
| |
| REQUIREMENTS channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the required channels of this LCO.
| |
| SR 3.3.4.2.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.
| |
| Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.
| |
| The Frequency of 92 days is based on the reliability analysis of The Surveillance Reference 2.
| |
| Frequency is controllecl under the Surveillance SR 3.3.4.2.3 Frequency Control Program. Calibration of trip units provides a check of the actual trip setpoints. The channel must be declared inoperable if the trip _setting is discovered to be less conservative than the Allowable Value specified in SR 3.3.4.2.4. If the trip setting is discovered to be less conservative than the setting accounted for in the appropriate setpoint methodology, but is not beyond ,
| |
| the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be readjusted to be equal to or more conservative than accounted for in the appropriate setpoint methodology.
| |
| * SR 3.3.4.2.4 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This'test verifies that the channel responds to the measured parameter within the necessary (continµed)
| |
| RIVER BEND B 3.3-83 Revision No. 0
| |
| | |
| A TWS-RPT Instrumentation B 3.3.4.2 BASES (continued)
| |
| SURVEILLANCE SR 3.3.4.2.4 (continued)
| |
| REQUIREMENTS range and accuracy. CHANNEL CALIBRATION leaves the channel
| |
| * adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.
| |
| The Frequency is based *upon the assumption of the magnitude of equipment drift in the setpoint analysis.
| |
| The Surveillance Frequency is SR 3.3.4.2.5 controlled under the Surveiliance The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the Frequency Controi OPERABILITY of the required trip logic for a specific channel. The Program. system functional test of the pump breakers, included as part of this Surveillance, overlaps the LOGIC SYSTEM FUNCTIONAL TEST to provide complete testing of the assumed safety function. Therefore, if a breaker is incapable of operating, the associated instrument channel(s) would be inoperable.
| |
| The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.
| |
| REFERENCES 1. USAR, Section 7.7.1.2.
| |
| : 2. NEDE-770-06-1, "Bases For Changes To Surveillance Test Intervals and Allowed Out-of-Service Times For Selected Instrumentation Technical Specifications," February 1991.
| |
| RIVER BEND B 3.3-84 Revision No. 143
| |
| | |
| ECCS Instrumentation B 3.3.5.1 BASES ACTIONS H.1 (continued)
| |
| With any Required Action and associated Completion Time not met, the associated feature(s) may be incapable of performing the intended function and the supported feature(s) associated with the inoperable untripped channels must be declared inoperable immediately.
| |
| SURVEILLANCE As noted at the beginning of the SRs, the SRs for each ECCS REQUIREMENTS instrumentation Function are found in the SRs column of Table 3.3.5.1-1.
| |
| The Surveillances are modified by a Note to indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours as follows: (a) for Functions 3.c, 3.f, 3.g, and 3.h; and (b) for Functions other than 3.c, 3.f, 3.g, and 3.h provided the associated Function or the redundant Function maintains ECCS initiation capability. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken. This Note is based on the reliability analysis (Ref. 4) assumption of the average time required to perform channel Surveillance. That analysis demonstrated th.at the 6 hour testing allowance does not significantly reduce the probability that. the ECCS will initiate when necessary.
| |
| SR 3.3.5.1.1 Performance of the CHANNEL CHECK once every 12 hours ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
| |
| (continued)
| |
| RIVER BEND B 3.3-118 Revision No. 0
| |
| | |
| ECCS Instrumentation B 3.3.5.1 BASES SURVEILLANCE SR 3.3.5.1.1 (continued)
| |
| REQUIREMENTS Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit.
| |
| The Frequency is based upon operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the channels required by the LCO.
| |
| SR 3.3.5.1.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.
| |
| Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.
| |
| The Surveillance Frequency is The Frequency of 92 days is based on the reliability analyses of control!ecl under the Reference 4.
| |
| SurJei!lance Frequency Control Program.
| |
| SR 3.3.5.1.3 The calibration of trip units provides a check of the actual trip setpoints.
| |
| The channel must be declared inoperable if the trip setting is discovered to be not within its required Allowable Value specified in Table 3.3.5.1-1.
| |
| \ If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant .
| |
| safety analyses. Under these conditions, the setpoint must be readjusted to be equal to or more conservative than the setting accounted for in the appropriate setpoint methodology.
| |
| The Frequency of 92 days is based on the reliability analysis of Reference 4.
| |
| (continued)
| |
| RIVER BEND B 3.3-119 Revision No. 0
| |
| | |
| ECCS Instrumentation B 3.3.5~1 I
| |
| BASES SURVEILLANCE SR 3.3.5.1.4 and SR 3.3.5.1.5
| |
| . REQUIREMENTS (continued) A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.
| |
| The Frequency of SR 3.3.5.1.4 and SR 3.3.5.1.5 is based upon the assumption of the magnitude of equipment drift in the setpoint analysis.
| |
| SR 3.3.5.1.6 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in LCO 3.5.1, LCO 3.5.2, LCO 3.8.1, and LCO 3.8.2 overlaps this Surveillance to provide complete testing of the assumed safety function.
| |
| ~
| |
| The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage (except for Division Ill \Nhich can he tested in any operational condition) and the potential for unplanned transients if the Surveillance were performed with the reactor at power. l (continued)
| |
| RIVER BEND B 3.3-120 Revision No. 143
| |
| | |
| RCIC System Instrumentation B 3.3.5.2 BASES (continued)*
| |
| SURVEILLANCE As noted in the beginning of the SRs, the SRs for each RCIC System REQUIREMENTS instrumentation Function are found in the SRs column of Table 3.3.5.2-1.
| |
| The Surveillances are modified by a Note to indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours for Functions 2 and 5; and (b) for up to 6 hours for Functions 1, 3, and 4 provided the associated Function maintains initiation capability. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken. This Note is based. on the reliability analysis (Ref. 1) assumption of the average time required Jo perform channel Surveillance. That analysis demonstrated that the 6 hour testing allowance does not significantly reduce the probability that the RCIC will initiate when necessary.
| |
| SR 3.3.5.2.1 Performance of the CHANNEL CHECK once e'Jery 12 hours ensures that a gro,ss failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one. of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
| |
| Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit.
| |
| (continued)
| |
| RIVER BEND B 3.3-131 Revision No. 130
| |
| | |
| RCIC System Instrumentation B 3.3.5.2 BASES SURVEILLANCE SR 3.3.5.2.1 (continued)
| |
| REQUIREMENTS channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channel status during normal operational use of the displays associated with the channels required by the LCO.
| |
| SR 3.3.5.2.2 ACHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.
| |
| The Frequency of 92 days is based on the reliab.ility analysis of Reference 1.
| |
| SR 3.3.5.2.3 The calibration of trip units provides a check of the actual trip setpoints.
| |
| The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in Table 3.3.5.2-1. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be re-adjusted to be equal to or more conservative than accounted for in the appropriate setpoint methodology.
| |
| The Frequency of 92 days is based on the reliability analysis of Reference 1.
| |
| SR 3.3.5.2.4 CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter with the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.
| |
| (continued)
| |
| RIVER BEND B 3.3-132 Revision No. O
| |
| | |
| RCIC System Instrumentation B 3.3.5.2 BASES SURVEILLANCE SR 3.3.5.2.4 (continued)
| |
| REQUIREMENTS The Frequency is based on the assumption of the magnitude of equipment drift in the setpoint analysis.
| |
| The Surveillance SR 3.3.5.2.5 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The
| |
| ~ system functional testing performed in LCO 3.5.3.overlaps this
| |
| ~Surveillance to provide complete testing of the safety function.
| |
| The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.
| |
| REFERENCES 1. NEDE-770-06-2, "Addendum to Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications," February 1991.
| |
| I RIVER BEND B 3.3-133 Revision No. 143
| |
| | |
| Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES ACTIONS K.1, K.2.1. and K.2.2 (continued)
| |
| If the channel is not restored to OPERABLE status or placed in trip within the allowed Completion Time, the associated penetration flow path(s) should be isolated (Required Action K.1 ). Isolating the affected penetration flow path(s) accomplishes the safety function of the inoperable instrumentation. Alternately, the plant must be placed in a condition in which the LCO does not apply.
| |
| This is done by placing the plant in at least MODE 3 within 12 hours and in MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE As noted at the beginning of the SRs, the SRs for each Primary REQUIREMENTS Containment and Drywell Isolation Instrumentation Function are found in the SRs column of Table 3.3.6.1-1.
| |
| The Surveillances are also modified by a Note to indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours provided the associated Function maintains trip capability. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken. This Note is based on the reliability analysis (Refs. 5 and 6) assumption of the average time required to *perform channel Surveillance. That analysis demonstrated that the 6 hour* testing allowance does not significantly reduce the probability that the isolation valves will isolate the penetration flow path(s) when nec;essary.
| |
| *SR 3.3.6.1.1 Performance of the CHANNEL CHECK once every 12 hours ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other (continued)
| |
| RIVER BEND B 3.3-165 Revision No. 0
| |
| | |
| Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE SR 3.3.6.1.1 (continued)
| |
| REQUIREMENTS channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channel~ or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
| |
| Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit.
| |
| The Surveillance Frequency is The Frequency is based on operating experience that demonstrates controlled under the channel failure is rare.
| |
| Surveillance Frequency Control The CHANNEL CHECK supplements less formal, but more frequent, Program. checks of channels during normal operational use of the displays associated with the channels required by the LCO.
| |
| SR 3.3.6.1.2 A CHANNEL FUNCTIONAL TEST is performed ori_each required channel to ensure that the entire channel will perform the intended function.
| |
| Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.
| |
| The Frequency is based on reliability analysis described in References 5
| |
| ~
| |
| SR 3.3.6.1.3 The calibration of trip units consists of a test to provide a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in (continued)
| |
| RIVER BEND B 3.3-166 Revision No. 0
| |
| | |
| Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE SR 3.3.6.1.3 (continued)
| |
| REQUIREMENTS Table 3.3.6.1-1. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be readjusted to be equal to or more conservative than accounted for in the appropriate setpoint methodology.
| |
| The Surveillance Frequency is The Frequency of 92 days is based on the reliability analysis of controlled under the References 5 and 6.
| |
| Surveillance Frequency Control Program.
| |
| SR 3.3.6.1.4 and SR 3.3.6.1.5 CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. For Functions 1.e, 3.f, and 4.h, there is a plant specific program which verifies that the instrument channel functions as required by verifying the as-left and as-found settings are consistent with those established by the setpoint methodology. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.
| |
| The Surveillance Ff'equencles are The Frequency of SR 3.3.6.1.4 and SR 3.3.6.1.5 is based on the contro!ied under U1e assumption of the magnitude of equipment drift in the setpoint analysis.
| |
| Surveiilance Frequency Control Program. SR 3.3.6.1.6 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required isolation logic for a specific channel. The system functional testing performed on PCIVs in LCO 3.6.1.3 and on drywell isolation valves in LCO 3.6.5:3 overlaps this Surveillance to
| |
| ~-----------i... provide complete testing of the assumed safety function. The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at pO\l.'eF.
| |
| (continued)
| |
| RIVER BEND B 3.3-167 Revision No. 152
| |
| | |
| Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE SR 3.3.6.1.7 REQUIREMENTS (continued) This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the accident analysis.
| |
| Testing is performed only on channels where the assumed response time does not correspond to the diesel generator (DG) start time. For channels assumed to respond within the DG start time, sufficient margin exists in the 1O second start time when compared to the typical channel response time (milliseconds) so as to assure adequate response without a specific measurement test. Testing of the closure times of the MS IVs is not included in this Surveillance since the closure time of the MS IVs is tested in SR 3.6.1.3.6. The instrument response times must be added to the MSIV closure times to obtain the ISOLATION SYSTEM RESPONSE TIME. ISOLATION SYSTEM RESPONSE TIME acceptance criteria for this instrumentation is included in Reference 7.
| |
| The Surveillance As noted the associated sensors are not required to be response time Frequency is tested. Response time testing for the remaining channel components is controliecl under the required. This is supported by Reference 8.
| |
| Surveillance Frequency ISOLATION SYSTEM RESPONSE TIME tests for this instrumentation are Program. conducted on an 24 month STAGGERED TEST BASIS. This test Frequency is consistent v1ith the typical industry refueling cycle.
| |
| REFERENCES 1. USAR, Section 6.3.
| |
| : 2. USAR, Chapter 15.
| |
| : 3. NED0-31466, "Technical Specification Screening Criteria Application and Risk Assessment," November 1987.
| |
| : 4. USAR, Section 9.3.5.
| |
| : 5. NEDC-31677-P-A, "Technical Specification Improvement Analysis for BWR Isolation Actuation Instrumentation," June 1989.
| |
| (continued)
| |
| RIVER BEND B 3.3-168 Revision No. 143
| |
| | |
| Secondary Containment and Fuel Building Isolation Instrumentation B 3.3.6.2 BASES SURVEILLANCE This Note is based on the reliability analysis (Refs. 3 and 4) assumption REQUIREMENTS of the average time required to perform channel Surveillance. That (continued) analysis demonstrated that the 6 hour testing allowance does not significantly reduce the probability that the SCIDs will isolate the associated penetration flow paths and the associated ventilation 1 subsystems will initiate when necessary.
| |
| SR 3.3.6.2.1 Performance of the CHANNEL CHECK once every 12 hours ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the indicated parameter for one instrument
| |
| * channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the .instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
| |
| Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication The Survei!ianca that the instrument has drifted outside its limit.
| |
| Frequency is controlled under the The Frequency is based on operating experience that demonstrates Surveil!ance channel failure is rare. The CHANNEL CHECK supplements less formal, Frequency Control but more frequent, checks of channels during normal operational use of Program. the displays associated with the channels required by the LCO.
| |
| SR 3.3.6.2.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.
| |
| (continued)
| |
| RIVER BEND B 3.3-178 Revision No. 6-5
| |
| | |
| Secondary Containment and Fuel Building Isolation Instrumentation B 3.3.6.2 BASES SURVEILLANCE SR 3.3.6.2.2 (continued)
| |
| REQUIREMENTS Any setpoint adjustment shall be left set consistent with the assumptions of the current plant specific setpoint methodology.
| |
| The F"requency of 92 days is based upon the reliability analysis of References 3 and 4.
| |
| SR 3.3.6.2.3 Calibration of trip units provides a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in Table 3.3.6.2-1. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be readjusted to be equal to or more conservative than accounted for in the appropriate setpoint methodology.
| |
| The Surveillance Frequency is The F"requency of 92 days is based on the reliability analysis of controlled unde;' the References 3 and 4.
| |
| Surveillance Frequency Ccntrol Program. SR 3.3.6.2.4 CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.
| |
| The F"requency is based upon the assumption of the magnitude of equipment drift in the setpoint analysis.
| |
| (continued)
| |
| RIVER BEND B 3.3-179 Revision No. 6-5
| |
| | |
| Secondary Containment and Fuel Building Isolation Instrumentation B 3.3.6.2 BASES SURVEILLANCE SR 3.3.6.2.5 REQUIREMENTS (continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required isolation logic for a specific channel. The system functional testing, performed on SCIDs and the associated ventilation subsystems in LCO 3.6.4.2, LCO 3.6.4.3, LCO 3.6.4.4, LCO 3.6.4.6, and LCO 3.6.4.7, respectively, overlaps this Surveillance to provide complete testing of the assumed safety function.
| |
| The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.
| |
| REFERENCES 1. USAR, Section 6.3.
| |
| : 2. USAR, Chapter 15.
| |
| : 3. NEDC-31677-P-A, "Technical Specification Improvement Analysis for BWR Isolation Actuation Instrumentation," July 1990.
| |
| : 4. NEDC-30851-P-A Supplement 2, "Technical Specifications Improvement Analysis for BWR Isolation Instrumentations Common to RPS and ECCS Instrumentation," March 1989. '
| |
| * RIVER BEND B 3.3-180 Revision No. 143
| |
| | |
| Containment Unit Cooler System Instrumentation B 3.3.6.3 BASES (continued)
| |
| SURVEILLANCE As noted at the beginning of the SRs, the SRs for each Containment REQUIREMENTS Unit Cooler System Function are located in the SRs column of Table 3.3.6.3-1.
| |
| The Surveillances are also modified by a Note to indicate that when a
| |
| * channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains containment unit cooler initiation capability. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the
| |
| * channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken. This Note is based on the reliability analysis (Ref. 3) assumption of the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour
| |
| * testing allowance does not significantly reduce the probability that the containment unit cooler will initiate when necessary.
| |
| SR 3.3.6.3.1 Performance of the CHANNEL CHECK once every 24 hours ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one *channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
| |
| Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication The Surveillance and readability. If a channel is outside the criteria, it may be an indication
| |
| \s that the instrument has drifted outside its limit.
| |
| controlled under Surveillance The Frequency is based upon *operating experience that demonstrates Frequency Control channel failure is rare. The CHANNEL CHECK supplements less formal, Program. but more frequent, checks of channels, during normal operational use of the displays associated with the channels required by the LCO.
| |
| (continued)
| |
| RIVER BEND B 3.3-188 Revision No. O
| |
| | |
| Containment Unit Cooler System Instrumentation B 3.3.6.3 BASES SURVEILLANCE SR 3.3.6.3.2 REQUIREMENTS (continued) A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure the entire channel will perform the intended function.
| |
| Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.
| |
| The Frequency of 92 days is based upon the reliability analysis of Reference 3.
| |
| SR 3.3.6.3.3' The calibration of trip units provides a check of the actual trip setpoints.
| |
| The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in Table 3.3.6.3-1. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be readjusted to be equal to or more conservative than accounted for in the appropriate setpoint methodology.
| |
| ~
| |
| The Frequency of 92 days is based upon the reliability analysis of Reference 3.
| |
| Program.
| |
| SR 3.3.6.3.4 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies that the channel responds to the measured parameter within the necessary range and accuracy.
| |
| CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.
| |
| The Frequency of SR 3.3.6.3.4 is based on the assumption of the magnitude of equipment drift in the setpoint analysis.
| |
| (continued)
| |
| )
| |
| RIVER BEND 83.3-189 Revision No. O
| |
| | |
| Containment Unit Cooler System Instrumentation B 3.3.6.3 BASES SURVEILLANCE SR 3.3.6.3.5 REQUIREMENTS (continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in LCO 3.6.1.7, "Primary Containment The Surveillance Unit Coolers," overlaps this Surveillance to provide complete testing of the Frequency is assumed safety function.
| |
| controlled under the Surveillance Frequency Control Surveillance under the conditions that apply during a plant outage and the Program. potential for an unplanned transient if the Surveillance 'Nere performed with the reactor at power.
| |
| REFERENCES 1. USAR, Section 7 .3.1.1.6.
| |
| : 2. USAR, Section 6.2.1.1.3.
| |
| : 3.
| |
| * GENE-770-06-1, "Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications," February 1991.
| |
| RIVER BEND B 3.3-190 Revision No. 143
| |
| | |
| Relief and LLS Instrumentation B 3.3.6.4 BASES, ACTIONS B.1 and 8.2 (continued)
| |
| MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours.
| |
| The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE The Surveillances are modified by a Note to indicate that when a channel REQUIREMENTS is placed in.an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains relief or LLS initiation capability, as applicable. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered .and Required Actions taken. This Note is based on the reliability analysis (Ref. 3) assumption of the average time required to perform channel surveillance. That analysis demonstrated the 6 hour testing allowance does not significantly reduce the probability that the relief and LLS valves will initiate when necessary.
| |
| SR 3.3.6.4.1 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.
| |
| The Surveillance is Any setpoint adjustment shall be left set consistent with the assumptions of the current plant specific setpoint methodology.
| |
| The Frequency of 92 days is based on the reliability analysis of Reference 3. *
| |
| (continued)
| |
| /
| |
| RIVER BEND B 3.3-195 Revision No. O
| |
| .I
| |
| | |
| Relief and LLS Instrumentation B 3.3.6.4 BASES SURVEILLANCE SR 3.3.6.4.2 REQUIREMENTS (continued) The calibration of trip units provides a check of the actual trip setpoints.
| |
| The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in SR 3.3.6.4.3.
| |
| If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be readjusted to be equal to or more conservative than accounted for in the appropriate setpoint methodology.
| |
| The Frequency of 92 days is based on the reliability analysis of Reference 3.
| |
| SR 3.3.6.4.3 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measureq parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.
| |
| The Frequency is based upon the assumption of the magnitude of equipment drift in the setpoint analysis.
| |
| SR 3.3.6.4.4 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required actuation logic for a sp.ecific channel. The system functional testing performed for S/RVs in LCO 3.4.4 and LCO 3.6.1.6 overlaps this Surveillance to provide complete testing of the assumed safety function.
| |
| The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outagE3 and the potential for an unplanned transient if the Surveillance were performed with the reactor at povver.
| |
| (continued)
| |
| RIVER BEND B 3.3-196 Revision No. 143
| |
| | |
| CRFA System Instrumentation B 3.3.7.1 BASES ACTIONS E.1 and E.2 (continued)
| |
| CRFA subsystem in operation must provide for automatically reinitiating the subsystem upon restoration of power following a loss of power to the CRFA subsystem(s).
| |
| Alternately, if it is not desired to start the subsystem, the CRFA subsystem associated with inoperable, untripped channels must be declared inoperable within 1 hour.
| |
| The 1 hour Completion Time is intended to allow the operator time to place the CRFA subsystem in operation. The 1 hour Completion Time is acceptable because it minimizes risk while allowing time for restoration or tripping of channels, or for placing the associated CRFA subsystem in operation.
| |
| SURVEILLANCE As noted at the beginning of the SRs, the SRs for each CRFA System REQUIREMENTS Instrumentation Function are located in the SRs column of Table3.3.7.1-1. 1 The Surveillances are also modified by a Note to indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours, provided the associated Function maintains CRFA System initiation capability. Upon completion cif the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken. This Note is based on the reliability analysis (Refs. 4, 5, and 6) assumption of the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour testing allowance does not significantly reduce the probability that the CRFA System will initiate when necessary.
| |
| SR 3.3.7.1.1 Performance of the CHANNEL CHECK once every 12 hours ensures that a gross failure .of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the indicated parameter for one instrument channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations (continued)
| |
| RIVER BEND B 3.3-205 Revision No. O
| |
| | |
| r CRFA System Instrumentation B 3.3.7.1 BASES SURVEILLANCE SR 3.3.7.1.1 (continued)
| |
| REQUIREMENTS between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
| |
| Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit.
| |
| The Frequency is based upon operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channel status during normal operational use of the displays associated with channels required by the LCO.
| |
| SR 3.3.7.1.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. Any setpoint adjustment shall be consistent with the assumptions of the The Surveillance current plant specific setpoint methodology.
| |
| Frequency is The Frequency of 92 days is based on the reliability analyses of controlled under the References 4, 5, and 6.
| |
| Surveillance' Frequency Control Program. SR 3.3.7.1.3 The calibration of trip units provides a Check of the actual trip setpoints.
| |
| Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology. The channel must be declared inoperable if the trip setting is discovered to be less conservativ~
| |
| than the Allowable Value. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the (continued)
| |
| RIVER BEND B 3.3-206 Revision No. O
| |
| | |
| CRFA System Instrumentation B 3.3.7.1 BASES SURVEILLANCE SR 3.3.7.1.3 (continued)
| |
| REQUIREMENTS setpoint must be readjusted to be equal to or more conservative than accounted for in the appropriate setpoint methodology.
| |
| The Frequency of 92 days is based on the reliability analyses of References 4, 5, and 6.
| |
| SR 3.3.7.1.4 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific The Surveillance setpoint methodology.
| |
| Frequency is controlled under the The Frequency is based on the assumption of the magnitude of Surveillance equipment drift in the setpoint analysis.
| |
| Frequency Control Program.
| |
| SR 3.3.7.1.5 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in LCO 3.7.3, "Control Room Fresh Air (CRFA) System," overlaps this Surveillance to provide complete testing of the assumed safety function.
| |
| The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the
| |
| . potential for an unplanned transient if the Surveillance were performed with the reactor at power.
| |
| REFERENCES 1. USAR, Section 7.3.1.1.9.
| |
| : 2. USAR, Section 6.4.
| |
| : 3. USAR, Chapter 15.
| |
| (continued)
| |
| RIVER BEND B 3.3-207 Revision No. 143
| |
| | |
| LOP Instrumentation B 3.3.8.1 BASES SURVEILLANCE or expiration of the 2 hour allowance, the channel must be returned to REQUIREMENTS OPERABLE status or the applicable Condition entered and Required (continued) Actions taken.
| |
| SR 3.3.8.1.1 Performance of the CHANNEL CHECK once every 12 hours ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
| |
| Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication 1
| |
| and readability. If a channel is outside the criteria, it may be an indication The Surveillance that the instrument has drifted outside its limit.
| |
| Frequency is The Frequency is based on operating experience that demonstrates
| |
| * controlled under the channel failure is rare. The CHANNEL CHECK supplements less formal, Surveillance but more frequent, checks of channels during normal operational use of Frequency Control the displays associated with the required channels of the LCO.
| |
| Program.
| |
| SR 3.3.8.1.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.
| |
| (continued)
| |
| RIVER BEND B 3.3-214 Revision No. 123
| |
| | |
| LOP Instrumentation B 3.3.8.1 BASES SURVEILLANCE SR 3.3.8.1.2 (continued)
| |
| REQUIREMENTS (continued) The Frequency of 31 days is based on plant operating experience with regard to channel OPERABILITY and drift that demonstrates that failure of more than one channel of a given Function in any 31 day interval is rare.
| |
| SR 3.3.8.1.3 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. There is a plant specific program which verifies that the instrumentation channel functions as required by verifying that the as-left and as-found settings are consistent with those established by the setpoint methodology.
| |
| CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant The Survei!iance specific setpoint methodology.
| |
| Frequency is controiled under th~'? The Frequency is based on the assumption of the magnitude of Surveillance equipment drift in the setpoint analysis.
| |
| Frequency Control Program SR 3.3.8.1.4 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required actuation logic for a specific channel. The system functional testing performed in LCO 3.8.1 and LCO 3.8.2 overlaps this Surveillance to provide complete testing of the assumed safety functions.
| |
| The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at pmver.
| |
| REFERENCES 1. USAR, Section 8.3.1.
| |
| : 2. USAR, Section 5.2.
| |
| : 3. USAR, Section 6.3.
| |
| , 4. USAR, Chapter 15.
| |
| RIVER BEND B 3.3-215 Revision No. 143
| |
| | |
| RPS Electric Power Monitoring B 3.3.8.2 BASES (continued)
| |
| SURVEILLANCE SR 3.3.8.2.1 REQUIREMENTS A CHANNEL FUNCTIONAL TEST is performed on each overvoltage, undervoltage, and underfrequency (including time delay) channel to ensure that the entire channel will perform the intended function.
| |
| <Delete line space>~
| |
| As noted in the Surveillance, the CHANNEL FUNCTIONAL TEST is only required to be performed while the plant is in a condition in which the loss of the RPS bus will not jeopardize steady state power operation (the design of the system is such that the power source must be removed from service to conduct the Surveillance). The 24 hours is intended to indicate an outage of sufficient duration to allow for scheduling and proper performance of the Surveillance. The 184 day Frequency and the The Note in the Surveillance are-is based on guidance provided in Generic Letter 91-09 (Ref. 2).
| |
| SR 3.3.8.2.2 CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies that the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument The Surveillance drifts between successive calibrations consistent with the plant specific Frequency is setpoint methodology.
| |
| controlled under the Surveillance The Frequency is based upon the assumption of a 24 month calibration Frequency Control interval in the determination of the magnitude of equipment drift in the Program. setpoint analysis.
| |
| (continued)
| |
| RIVER BEND B 3.3-221 Revision No. 143
| |
| | |
| RPS Electric Power Monitoring B 3.3.8.2 BASES SURVEILLANCE SR 3.3.8.2.3 REQUIREMENTS (continued) Performance of a system functional test demonstrates a required system actuation (simulated or actual) signal. The logic of the system will automatically trip open the associated power monitoring assembly circuit breaker. Only one signal per power monitoring assembly is required to be tested. This Surveillance overlaps with the CHANNEL CALIBRATION to provide complete testing of the safety function. The system functional test of the Class 1E circuit breakers is included as part of this test to provide complete testing of the safety function. If the breakers are incapable of Tt-ie Surveillance operating, the associated electric power monitoring assembly would be Frequency is inoperable.
| |
| controllecl under the Surveillance The 24 month Frequency is based on the need to perform this Frequency Control Surveillance under the conditions that apply during a plant outage and the Program. potential for an unplanned transient if the Surveillance were performed with the reactor at power.
| |
| REFERENCES 1. USAR, Section 8.3.1.1.3.
| |
| : 2. NRC Generic Letter 91-09, "Modification of Surveillance Interval for the Electric Protective Assemblies in Power Supplies for the Reactor Protection System."
| |
| : 3. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.
| |
| RIVER BEND B 3.3-222 Revision No. 161
| |
| | |
| Recirculation Loops Operating B 3.4.1 BASES ACTIONS (continued) D.1 With no recirculation loops in operation, or the Required Action and associated Completion Time of Condition A not met, the unit is required to be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to MODE 3 within 12 hours. In this condition, the recirculation loops are not required to be operating because of the reduced severity of DBAs and minimal dependence on the recirculation loop coastdown characteristics. The allowed Completion Time of 12 hours is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems.
| |
| ( .
| |
| SURVEILLANCE SR 3.4.1.1 REQUIREMENTS This SR ensures the recirculation loop flows are within the allowable limits for mismatch. At low core flow (i.e.,< 70% of rated core flow), the MCPR requirements provide larger margins to the fuel cladding integrity Safety Limit such that the potential adverse effect of early boiling transition during a LOCA is reduced. A larger flow mismatch can therefore be allowed when core flow is < 70% of rated core flow. The recirculation loop jet pump flow, as used in this Surveillance, is the summation of the flows from all of the jet pumps associated with a single recirculation loop.
| |
| The mismatch is measured in terms of percent of rated core flow. This SR is not required when both loops are not in operation since the mismatch Tl1e Sun;el!lance limits are meaningless during single loop or natural circulation operation.
| |
| Frequency is The Surveillance must be performed within 24 hours after both loops are controlled under the in operation. The 24 hour Frequency is consistent with the Frequency for Surveillance ~jet pump OPERJ\BILITY verification and has been shovm by operating Frequency Centro! experience to be adequate to detect off normal jet pump loop flov1s in a Program. timely manner.
| |
| '(continued)
| |
| RIVER BEND B 3.4-7 Revision No. 4-8
| |
| _j
| |
| | |
| ' FCVs B 3.4.2 BASES ACTIONS 8.1 .
| |
| (continued)
| |
| If the FCVs are not deactivated (locked up) and cannot be restored to OPERABLE status within the associated Completion Time, the unit must be brought to a MODE in which the LCO does not apply. To achieve this status, the unit must be brought to at least MODE 3 within 12 hours. This brings the unit to a condition where the flow coastdown characteristics of the recirculation loop are not important. The allowed Completion Time of 12 hours is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and .without challenging unit systems.
| |
| SURVEILLANCE SR 3.4.2.1 REQUIREMENTS Hydraulic power unit pilot operated isolation valves located between the servo valves and the common "open" and "close" lines are required to close in the event of a loss of hydraulic pressure. When closed, these valves inhibit FCV motion by blocking hydraulic pressure from the servo valve to the common open and close lines as well as to the alternate The Surveillance subloop. This Surveillance verifies FCV lockup on a loss of hydraulic Frequency is controlled under tl1e Surveillance Frequency Control Program.
| |
| SR 3.4.2.2 This SR ensures the overall average rate of FCV movement at all positions is maintained within the analyzed limits.
| |
| The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance (continued)
| |
| RIVER BEND B 3.4-11 Revision No. 143
| |
| | |
| FCVs B 3.4.2 BASES SURVEILLANCE SR 3.4 .2.2 (continued)
| |
| REQUIREMENTS were performed with the reactor at pmNer.
| |
| REFERENCES 1. USAR, Section 15.3.2.
| |
| : 2. USAR, Section 15.4.5.
| |
| <Move row to prior previous page>
| |
| RIVER BEND B 3.4-12 Revision No. 143
| |
| | |
| Jet Pumps B 3.4.3 BASES SURVEILLANCE SR 3.4.3.1 (continued)
| |
| REQUIREMENTS Individual jet pumps in a recirculation loop typically do not have the same flow. The unequal flow is due to the drive flow manifold, which does not distribute flow equally to all risers. The flow (or jet pump diffuser to lower plenum differential pressure) pattern or relationship of one jet pump to the loop average is repeatable. An appreciable change in this relationship is an indication that increased (or reduced) resistance has occurred in one of the jet pumps. This may be indicated by an increase in the relative flow for a jet pump that has experienced beam cracks.
| |
| The deviations from normal are considered indicative of a potential problem in the recirculation drive flow or jet pump system (Ref. 2). Normal flow ranges and established jet pump flow and differential pressure The Surveillance patterns are established by plotting historical data as discussed in Frequency is Reference 2.
| |
| controlled unc:er the The 24 hour Frequency has been shown by operating experience to be Surveillance adequate to verify jet pump OPERABILITY and is consistent 1.vith the Frequency Control Frequency for recirculation loop OPERABILITY verification.
| |
| Program ..
| |
| This SR is modified by two Notes. Note 1 allows this Surveillance not to be performed until 4 hours after the associated recirculation loop is in operation, since these checks can only be performed during jet pump operation. The 4 hours is an acceptable time to establish conditions appropriate for data collection and evaluation.
| |
| Note 2 allows this SR not to be performed when THERMAL POWER is
| |
| ::::; 23.8% RTP. During low flow conditions, jet pump noise approaches the threshold response of the associated flow instrumentation and precludes the collection of repeatable and meaningful data.
| |
| REFERENCES 1. USAR, Section 6.3.
| |
| : 2. GE Service Information Letter No. 330, "Jet Pump Beam Cracks,"
| |
| June 9, 1980.
| |
| : 3. NUREG/CR-3052, "Closeout of IE Bulletin 80-07: BWR Jet Pump Assembly Failure," November 1984.
| |
| RIVER BEND B 3.4-16 Revision No. 6-7
| |
| | |
| S/RVs B 3.4.4 BASES SURVEILLANCE SR 3.4.4.1 (continued)
| |
| REQUIREMENTS lift settings must be performed during shutdown, since this is a bench test, and in accordance with the lnservice Testing Program. The lift setting pressure shall correspond to ambient conditions of the valves at nominal operating temperatures and pressures.
| |
| The Frequency was selected because this Surveillance must be performed during shutdown conditions and is based on the time between refuelings.
| |
| SR 3.4.4.2 The required relief function S/RVs are required to actuate automatically upon receipt of specific initiation signals. A system functional test is performed to verify the mechanical portions of the automatic relief function operate as designed when initiated either by an actual or simulated initiation signal. The LOGIC SYSTEM FUNCTIONAL TEST in The Surveiilance SR 3.3.6.4.4 overlaps this SR to provide complete testing of the safety Frequency is function.
| |
| controlled under the Surveillance Frequency Control Surveillance under the conditions that apply during a plant outage and the Program. potential for an unplanned transient if the Surveillance 111ere performed 1.vith the reactor at power.
| |
| This SR is modified by a Note that excludes valve actuation. This prevents an RPV pressure blowdown.
| |
| SR 3.4.4.3 A manual actuation of each required S/RV (those valves removed and replaced to satisfy SR 3.4.4.1) is performed to verify that the valve is functioning properly. This SR can be demonstrated by one of two methods. If performed by method 1), plant startup is allowed prior to performing this test because valve OPERABILITY and the setpoints for overpressure protection are verified, per ASME requirements (Ref. 1),
| |
| prior to valve installation. Therefore, this SR is modified by a note that states the surveillance is not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. The 12 hours allowed for manual actuation after the required pressure is reached is sufficient to achieve stable conditions for testing and provides (continued)
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| RIVER BEND B 3.4-20 Revision No. 143
| |
| | |
| RCS Operational LEAKAGE B 3.4.5 BASES
| |
| * ACTIONS C.1 and C.2 (continued) 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE SR 3.4.5.1 REQUIREMENTS The RCS LEAKAGE is monitored by a variety of instruments designed to The Surveillance quantify the various types of LEAKAGE. Leakage detection Frequency is instrumentation is discussed in more detail in the Bases for LCO 3.4.7, controlled under the "RCS Leakage Detection Instrumentation." Sump level is typically Surveillance monitored to determine actual LEAKAGE rates. However, any method Frequency Control may be used to quantify LEAKAGE within the guidelines of Reference 7.
| |
| Program. In conjunction 1,.vith alarms and other administrative controls, a 12 hour Frequency for this Surveillance is appropriate for identifying changes in LEAKP,GE and for tracking required trends (Ref. 8).
| |
| REFERENCES 1. 10 CFR 50.2.
| |
| : 2. 10 CFR 50.55a(c).
| |
| : 3. 10 CFR 50, Appendix A, GDC 55.
| |
| : 4. GEAP-5620, "Failure Behavior in ASTM A106B Pipes Containing Axial Through-Wall Flaws," April 1968.
| |
| : 5. NUREG-75/067, lllnvestigation and Evaluation of Cracking in Austenitic Stainless Steel Piping of Boiling Water Reactor Plants,"
| |
| October 1975.
| |
| : 6. USAR, Section 5.2.5.5.3.
| |
| : 7. Regulatory Guide 1.45, May 1973.
| |
| -&.- Generic Letter 88 01, Supplement 1, "NRG Position on IGSCC in BWR Austenitic Stainless Steel Piping," February 1992.
| |
| RIVER BEND B 3.4-26 Revision No. O
| |
| | |
| RCS Leakage Detection Instrumentation B 3.4.7 BASES (continued)
| |
| ACTIONS G.1 (continued)
| |
| With all required monitors inoperable, no required automatic means of monitoring LEAKAGE are available, and immediate plant shutdown in accordance with LCO 3.0.3 is r~quired.
| |
| SURVEILLANCE SR 3.4.7.1 REQUIREMENTS This SR requires the performance of a CHANNEL CHECK of the required drywell atmospheric monitoring system. The check gives reasonable
| |
| * confidence that the channel is operating properly. The Frequency of 12 hours is based on ,instrument reliability and is reasonable for detecting off normal conditions.
| |
| SR 3.4.7.2 This SR requires the performance of a CHANNEL FUNCTIONAL TEST of Tt1f.J Survelllance the required RCS leakage detection instrumentation. The test ensures Frequency is that the monitors can perform their function in the desired manner. The controiled under the test also verifies the relative accuracy of the instrumentation. +J:te Survei!iance Frequency of 31 days considers instrument reliability, and operating Frequency Control experience has shown it proper for detecting degradation.
| |
| Prograrn.
| |
| SR 3.4.7.3 This SR requires the performance of a CHANNEL CALIBRATION of the required RCS leakage detection instrumentation channels. The calibration verifies the accuracy of the instrumentation, including the instruments located inside the drywell. The Frequency of 24 months is a typioal refueling cyole and oonsiders ohannel reliability.
| |
| (continued)
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| RIVER BEND B 3.4-37 Revision No. 149
| |
| | |
| RCS Specific Activity B 3.4.8 BASES (continued)
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| SURVEILLANCE SR 3.4.8.1 REQUIREMENTS This Surveillance is performed to ensure iodine remains within limit during The Surveillance ~normal operation. The 7 day Frequency is adequate to trend changes in Frequency is the iodine activity level.
| |
| contrnllec! under the Surveillance This SR is modified by a Note that requires this Surveillance to be Frequency Control performed only in MODE 1 because the level of fission products Prograrn. generated in other MODES is much less.
| |
| REFERENCES 1. 10 CFR 50.67.
| |
| : 2. USAR, Section 15.6.4.
| |
| RIVER BEND B 3.4-42 Revision No. 11 O
| |
| | |
| RHR Shutdown Cooling System - Hot Shutdown B 3.4.9 BASES ACTIONS B.1, B.2, and B.3 (continued)
| |
| During the period when the reactor coolant is being circulated by an alternate method (other than by the required RHR shutdown cooling subsystem or recirculation pump), the reactor coolant temperature and pressure must be periodically monitored to ensure proper function of the alternate method. The once per hour Completion Time is deemed appropriate.
| |
| SURVEILLANCE SR 3.4.9.1 REQUIREMENTS This Surveillance verifies that one RHR shutdown cooling subsystem or The Surveil!ance recirculation pump is in operation and circulating reactor coolant. The Frequency is required flow rate is determined by the flow rate necessary to provide contro!ied under the sufficient decay heat removal capability. The Frequency of 12 hours is Survei!lance Frequency Control Program.
| |
| This Surveillance is modified by a Note allowing sufficient time to align the RHR System for shutdown cooling operation after clearing the pressure interlock that isolates the system, or for placing a recirculation pump in operation. The Note takes exception to the requirements of the Surveillance being met (i.e., forced coolant circulation is not required for this initial 2 hour period), which also allows entry into the Applicability of this Specification in accordance with SR 3.0.4 since the Surveillance will not be "not met" at the time of entry into the Applicability.
| |
| SR 3.4.9.2 ,
| |
| )
| |
| RHR Shutdown Cooling System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the RHR shutdown cooling subsystems and may also prevent water hammer, pump cavitation, and pumping of noncondensible gas into the reactor vessel.
| |
| Selection of RHR Shutdown Cooling System locations susceptible to gas accumulation is based on a review of system design information, including*
| |
| piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration.
| |
| (continued)
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| RIVER BEND B 3.4-47 Revision No. 163
| |
| | |
| RHR Shutdown Cooling System - Hot Shutdown B 3.4.9 BASES SURVEILLANCE SR 3.4.9.2 (continued)
| |
| REQUIREMENTS Susceptible locations depend on plant and system configuration, such as '
| |
| stand-by versus operating conditions.
| |
| The RHR Shutdown Cooling System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible location exceeds an acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR Shutdown Cooling System is not rendered inoperable by the accumulated gas (i.e., the system is sufficiently filled with water), the Surveillance may be declared met.
| |
| Accumulated gas should be eliminated or brought within the acceptance criteria limits.
| |
| RHR Shutdown Cooling System locations susceptible to gas accumulation are monitored and, if gas is found, the gas volume is compared to the acceptance criteria for the location. Susceptible locations in the same system flow path which are subject to the same gas intrusion mechanisms may be verified by monitoring a representative sub-set of susceptible locations. Monitoring may not be practical for locations that are inaccessible due to radiological or environmental conditions, the plant configuration, or personnel safety. For these locations alternative methods (e.g., operating parameters, remote monitoring) may be used to monitor the susceptible location. Monitoring is not required for susceptible locations where the maximum potential accumulated gas void volume has The Surveillance been evaluated and determined to not challenge system OPERABILITY.
| |
| Frequency is The accuracy of the method used for monitoring the susceptible locations controlled uncler the and trending of the results should be sufficient to assure system Surveillance OPERABILITY during the Surveillance interval.
| |
| Frequency Control Program. The This SR is modified by a Note that states the SR is not required to be 1 Surveillance performed until 12 hours reactor steam dome pressure is < the RHR cut in Frequency may vary permissive pressure. After a rapid shutdown, there may be insufficient by location time to verify all susceptible locations prior to entering the Applicability.
| |
| susceptible to gas accumulation. The 31 day Frequency takes into consideration the gradual nature of gas accumulation in the RHR Shutdovm Cooling System piping and the procedural controls governing system operation.
| |
| REFERENCES None.
| |
| RIVER BEND B 3.4-47a Revision No. 163
| |
| | |
| RHR Shutdown Cooling System-Cold Shutdown B 3.4.10 BASES SURVEILLANCE SR 3.4.10.1 (continued)
| |
| REQUIREMENTS determined by the flow rate necessary to provide sufficient decay heat removal capability. The Frequency of 12 hours is sufficient in vievv of other visual and audible indications available to the operator for monitoring the RHR subsystem in the control room.
| |
| The Surveillance Frequency is SR 3.4.10.2 controlled under the Surveillance RHR Shutdown Cooling System piping and components have the Frequency Control potential to develop voids and pockets of entrained gases. Preventing Program. and managing gas intrusion and accumulation is necessary for proper operation of the RHR shutdown cooling subsystems and may also prevent water hammer, pump cavitation, and pumping of noncondensible gas into the reactor vessel.
| |
| Selection of RHR Shutdown Cooling System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of importanfcomponents that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration. Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions.
| |
| The RHR Shutdown Cooling System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. If accumulated ga~ is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible location exceeds an acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR Shutdown Cooling System is not rendered inoperable by the accumulated gas (i.e., the system is sufficiently filled with water), the Surveillance may be declared met.
| |
| Accumulated gas should be eliminated or brought within the acceptance criteria limits.
| |
| RHR Shutdown Cooling System locations susceptible to gas accumulation are monitored and,. if gas is found, the gas volume is compared to the acceptance criteria for the location. Susceptible locations in the same system flow path which are subject to the same gas intrusion mechanisms may be verified by monitoring a representative sub-set of susceptible locations. Monitoring may not be practical for locations (continued)
| |
| RIVER BEND B 3.4-52 Revision No. 163
| |
| | |
| RHR Shutdown Cooling System-Cold Shutdown B 3.4.10 BASES SURVEILLANCE SR 3.4.10.2 (continued)
| |
| REQUIREMENTS that are inaccessible due to radiological or environmental conditions, the The Surveillance plant configuration, or p'ersonnel safety. For these locations alternative Frequency is methods (e.g., operating parameters, remote monitoring) may be used to controlled under the monitor the susceptible location. Monitoring is not required for susceptible Surveillance locations where the maximum potential accumulated gas void volume has Frequency Control been evaluated and determined to not challenge system OPERABILITY:
| |
| Program. The The accuracy of the method used for monitoring the susceptible locations Surveillance and trending of the results should be sufficient to assure system Frequency may vary OPERABILITY during the Surveillance interval.
| |
| by location The 31 day Frequency takes into consideration the gradual nature of gas susceptible to gas accumulation in the RHR Shutdown Cooling System piping and the accumulation.
| |
| procedural controls governing system operation.
| |
| REFERENCES None.
| |
| RIVER BEND B 3.4-52a Revision No. 163
| |
| * RCS PIT Limits B 3.4.11 BASES ACTIONS C.1 and C.2 (continued)
| |
| Operati'on outside the PIT limits in other than MODES 1, 2, and 3 (including defueled conditions) must be corrected so that the RCPB is returned to a condition that has been verified by stress analyses. The Required Action must be initiated without delay and continued until the limits are restored.
| |
| Besides restoring the PIT limit parameters to within limits, an evaluation is required to determine if RCS operation is allowed. This evaluation must verify that the RCPB integrity is acceptable and must be completed before approaching criticality or heating up to > 200°F. Several methods may be used, including comparison with pre-analyzed transients, new analyses, or inspection of the components. ASME Section XI, Appendix E (Ref. 6),
| |
| may be used to support the evaluation; however, its use is restricted to evaluation of the beltline.
| |
| SURVEILLANCE SR 3.4.11.1 REQUIREMENTS Verification that operation is within limits is required every 30 minutes when RCS pressure and temperature conditions are undergoing planned changes. This Frequency is considered reasonable in view of the controi room indication avajlable to monitor RCS status. Also, since temperature rate of change limits are specified in hourly increments, 30 minutes permits assessment and correction of minor deviations.
| |
| The Surveillance Surveillance for heatup, cooldown, or inservice leakage and hydrostatic Frequency is testing may be discontinued when the criteria given in the relevant plant contro!!ed under the procedure for ending the activity are satisfied.
| |
| Surveillance Frequency Control This SR has been modified by a Note that requires this Surveillance to be Program. performed only during system heatup and cooldown operations and inservice leakage and hydrostatic testing.
| |
| (continued)
| |
| RIVER BEND B 3.4-58 Revision No. O
| |
| | |
| RCS PIT Limits B 3.4.11 BASES SURVEILLANCE SR 3.4.11.5, SR 3.4.11.6, and SR 3.4.11.7 REQUIREMENT (continued) Limits on the reactor vessel flange and head flange temperatures are generally bounded by the other PIT limits during system heatup and cooldown. However, operations approaching MODE 4 from MODE 5 and in MODE 4 with RCS temperature less than or equal to certain specified values require assurance that these temperatures meet the LCO limits.
| |
| The flange temperatures must be verified to be above the limits 30 minutes before and while tensioning the vessel head bolting studs to ensure that once the head is tensioned the limits are satisfied. When in MODE 4 with RCS temperatures 80°F, 30 minute checks of the flange temperatures are required because of the reduced margin to the limits.
| |
| When in MODE 4 with RCS temperatures 100°F, monitoring of the flange The Surveiiiance temperature is required every 12 hours to ensure the temperatures are Frequencies are within limits.
| |
| controlled under the Surveillance Frequency Control Program.
| |
| SR 3.4.11.8 and SR 3.4.11.9 Differential temperatures within the applicable limits ensure that thermal stresses resulting from increases in THERMAL POWER or recirculation loop flow during single recirculation loop operation will not exceed design allowances. Performing the Surveillance within 15 minutes before beginning such an increase in power or flow rate provides adequate assurance that the limits will not be exceeded between the time of the Surveillance and the time of the change in operation.
| |
| An acceptable means of demonstrating compliance with the temperature differential requirement in SR 3.4.11 .9 is to compare the temperatures of the operating recirculation loop and the idle loop.
| |
| (continued)
| |
| RIVER BEND B 3.4-60 Revision No. O
| |
| | |
| Reactor Steam Dome Pressure B 3.4.12 BASES APPLICABILITY In MODES 3, 4, and 5, the limit is not applicable because the reactor is (continued) shut down. In these MODES, the reactor pressure is well below the required limit, and no anticipated events will challenge the overpressure limits.
| |
| ACTIONS With the reactor steam dome pressure greater than the limit, prompt action should be taken to reduce pressure to below the limit and return the reactor to operation within the bounds of the analyses. The 15 minute Completion Time is reasonable considering the importance of maintaining the pressure within limits. This Completion Time also ensures that the probability of an accident while pressure is greater than the limit is minimal.
| |
| If the reactor steam dome pressure cannot be restored to within the limit within the associated Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours. The allowed Completion Time of 12 hours is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE SR 3.4.12.1 REQUIREMENTS Verification that reactor steam dome pressure is ::; 1075 psig ensures that the initial conditions of the vessel overpressure protection analysis are met. Operating experience has shown the 12 hour Frequency to be sufficient for identifying trends and verifying operation within safety analyses assumptions. - - - - - - - - ~ - - - - - - - ~
| |
| ----- The Surveillance Frequency is controlled under the REFERENCES 1. USAR, Section 5.2.2.1.
| |
| Surveii!ance Frequency Control
| |
| : 2. USAR, Section 15.
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| Program.
| |
| RIVER BEND B 3.4-63 Revision No. 6-14
| |
| | |
| EGGS-Operating B 3.5.1 BASES (continued)
| |
| SURVEILLANCE SR 3.5. *u /continued)
| |
| REQUIREMENTS gas intrusion mechanisms may be verified by monitoring a representative sub-set of susceptible locations. Monitoring may be practical for locations that are inaccessible due to radiological or environmental conditions, the plant configuration, or personnel safety. For these locations alternative methods (e.g., operating parameters, remote monitoring) may be used to monitor the susceptible location. Monitoring is not required for susceptible locations where the maximum potential accumulated gas void volume has been evaluated and determined to not challenge system OPERABILITY. The accuracy of the method used for monitoring the susceptible locations and trending of the results should be The Surveiliance sufficient to assure system OPERABILITY during the Surveillance Frequency is interval.
| |
| controlled under the Surveillance The 31 day Frequency is based on operating experience, on the Frequency Control procedural controls governing system operation, and on the gradual Program. Tl,e nature of void buildup in the EGGS piping.
| |
| Surveillance Frequency rnay SR 3.5.1.2 vary by locatlon susceptible to gas Verifying the correct alignment for manual, power operated, and accumulation. automatic valves in the EGGS flow paths provides assyrance that the proper flow paths will exist for EGGS operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position since these valves were verified to be in the correct position prior to locking, sealing, or securing. A valve that receives an initiation signal is allowed to be in a nonaccident position provided the valve will automatically reposition in the proper stroke time. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves potentially capable of being mispositioned are in the correct position.
| |
| This SR does not apply to valves that cannot be inadvertently misaligned, The Surveiliance such as check valves.
| |
| Frequency is controlled under the The 31 day Frequency of this SR was. derived from the lnservice Testing Surveillance Program requirements for performing valve testing at least once every Frequency Control 92 days. The Frequency of 31 days is further justified because the Program. valves are operated under procedural control and because improper valve alignment would only affect a single subsystem. This Frequency has been shown to be acceptable through operating experience.
| |
| (continued)
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| RIVER BEND B 3.5-9a Revision No. 163
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| _J
| |
| | |
| ECCS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.2 (continued)
| |
| REQUIREMENTS This SR is modified by Note 1 that allows LPCI subsystems to be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the RHR cut in permissive pressure in MODE 3, if capable of being manually realigned (remote or local) to the LPCI mode and not otherwise inoperable. This allows operation in the RHR shutdown cooling mode during MODE 3 if necessary.
| |
| This SR is also modified by Note 2 which exempts system vent flow paths opened under administrative control. The administrative control should be proceduralized and include stationing a dedicated individual at the system vent flow path who is in continuous communication with the operators in the control room. This individual will have a method to rapidly close the system vent flow path if directed.
| |
| SR 3.5.1.3 Verification every 31 days that ADS air accumulator supply pressure is
| |
| ~ 131 psig assures adequate air pressure for reliable ADS operation.
| |
| The accumulator on each ADS valve provides pneumatic pressure for valve actuation. The designed pneumatic supply pressure requirements for the accumulator are such that, following a failure of the pneumatic supply to the accumulator, at least two valve actuations can occur with the drywell at 70% of design pressure (Ref. 13). The ECCS safety analysis assumes only one actuation to achieve the depressurization required for operation of the low pressure ECCS. This minimum required pressure of 131 psig is provided by the nonsafety related air supply The Surveillance system (SW) with safety related backup from the penetration valve Frequency is leakage control system (LSV), post LOCA, at a system design pressure controlled under the of 120 psig. The 31 day Frequency takes into consideration Surveillance Frequency Control alarms for lovv air pressure.
| |
| Program.
| |
| SR 3.5.1.4 The performance requirements of the ECCS pumps are determined through application of the 10 CFR 50, Appendix K, criteria (Ref. 8). This periodic Surveillance is performed (in accordance with the ASME OM Code requirements for the ECCS pumps) to verify that the ECCS pumps will develop the flow rates required by the respective analyses. The ECCS pump flow rates ensure that adequate core cooling is provided to satisfy the acceptance criteria of 10 CFR 50.46 (Ref. 10).
| |
| (continued)
| |
| RIVER BEND B 3.5-10 Revision No. 163
| |
| | |
| ECCS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.4 (continued)
| |
| REQUIREMENTS The pump flow rates are verified with a pump differential pressure that is sufficient to overcome theRPV pressure expected during a LOCA. The
| |
| * total system pump outlet pressure is adequate to overcome the elevation head pressure between the pump suction and the vessel discharge, the piping friction losses, and RPV pressure present during LOCAs. These values may be established during pre-operational testing. The Frequency for this Surveillance is in accordance with the lnservice Testing Program requirements.
| |
| SR 3.5.1.5 The ECCS subsystems are required to actuate automatically to perform their design functions. This Surveillance test verifies that, with a required system initiation signal (actual or simulated), the automatic initiation logic of HPCS, LPCS, and LPCI will cause the systems or subsystems to operate as designed, including actuation of the system throughout its emergency operating sequence, automatic pump startup, and actuation of all automatic valves in the flow path to their required positions. This test may be performed by means of any series of sequential, overlapping, or total system steps so that the entire system is tested. This Surveillance also ensures that the HPCS System will automatically restart on an RPV low water level (Level 2) signal received subsequent to an RPV high water level (Level 8) trip and that the suction is automatically transferred from the CST to the suppression pool. The LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.1, "Emergency Core The Surveillance Cooling System (ECCS) Instrumentation," overlaps this Surveillance to Frequency is provide complete testing of the assumed safety function.
| |
| controlled uncler the Surveiliance The 24 month Frequency is based on the need to perform this Frequency Control Surveillance under the conditions that apply during a plant outage (except Program. for Division Ill which can be tested in any operational condition) and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.
| |
| (continued)
| |
| RIVER BEND B 3.5-11 Revision No. 143 1
| |
| | |
| EGGS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.5 (continued)
| |
| REQUIREMENTS This SR is modified by a Note that excludes vessel injection/spray during the Surveillance. Since all active components are testable and full flow can be demonstrated by recirculation through the test line, coolant injection into the RPV is not required during the Surveillance.
| |
| SR 3.5.1.6 The ADS designated S/RVs are required to actuate automatically upon receipt of specific initiation signals. A system functional test is performed to demonstrate that the mechanical portions of the ADS function (i.e.,
| |
| solenoids) operate as designed when initiated either by an actual or simulated initiation signal, causing proper actuation of all the required components. SR 3.5.1.7 and the LOGIC SYSTEM FUNCTIONAL TEST The Surveillance performed in LCO 3.3.5.1 overlap this Surveillance to provide complete Frequency is testing of the assumed safety function.
| |
| contro!!sd under the Surveillance The 24 month Frequency is based on the need to perform this Frequency Contr.o! Surveillance under the conditions that apply during a plant outage and Program. the potential for an unplanned transient if the Surveillance 'Nere performed 1Nith the reactor at power.
| |
| This SR is modified by a Note that excludes valve actuation. This prevents an RPV pressure blowdown.
| |
| SR 3.5.1.7 A manual actuation of each required ADS valve (those valves removed and replaced to satisfy SR 3.4.4.1) is performed to verify that the valve is functioning properly. This SR can be demonstrated by one of two methods. If performed by method 1), plant startup is allowed prior to performing this test because valve OPERABILITY and the setpoints for overpressure protection are verified, per ASME requirements (Ref. 16) prior to valve installation. Therefore, this SR is modified by a note that states the surveillance is not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. The 12 hours allowed for manual actuation after the required pressure is reached is sufficient to achieve stable conditions for testing and provides a reasonable time to complete the SR. If performed by method 2), valve (continued)
| |
| RIVER BEND B 3.5-12 Revision No. 143
| |
| | |
| EGGS-Operating B 3.5.1 BASES SURVEILLANCE SR 3.5.1.7 (continued)
| |
| REQUIREMENTS*
| |
| implemented by the lnservice Testing Program of Specification 5.5.6.
| |
| The testing frequency required by the lnservice Testing Program is based on operating experience and valve performance. Therefore, the frequency was concluded to be acceptable from a reliability standpoint.
| |
| SR 3.5.1.8 This_ SR ensures that the EGGS RESPONSE TIMES are within limits for each of the EGGS injection and spray subsystems. This SR is modified by a Note which identifies that the associated EGGS actuation instrumentation is not required to be response time tested. Response time testing of the remaining subsystem components is required. This is The Surveillance supported by Reference 14. Response time testing acceptance criteria Frequency is are included in Reference 15.
| |
| controlled under the Surveillance EGGS RESPONSE TIME tests are conducted every 24 months. The 24 Frequency Control month Frequency is based on the need to perform this Surveillance under Progran1. the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed 1Nith the reactor at pmver.
| |
| (continued)
| |
| RIVER BEND B 3.5-13a . Revision No. 143
| |
| | |
| ECCS-Shutdown
| |
| , B 3.5.2 BASES ACTIONS C.1, C.2, D.1, D.2, and D.3 (continued) result from the identifie9 conditions. The lack of available ECCS during shutdown conditions would not be expected to result in the immediate release of appreciable fission products to the containment atmosphere.
| |
| Actions must continue until all requirements of this Condition are satisfied.
| |
| The 4 hour Completion Time to restore at least one ECCS injection/spray subsystem to OPERABLE status ensures that prompt action will be taken to provide the required cooling capacity or to initiate actions to place the plant in a condition that minimizes any potential fission product release to the environment.
| |
| SURVEILLANCE SR 3.5.2.1 and SR 3.5.2.2 REQUIREMENTS The minimum water level of 13 ft 3 inches required for the suppression pool is periodically verified to ensure that the suppression pool will provide adequate net positive suction head (NPSH) for the ECCS pumps, recirculation volume, and vortex prevention. With the suppression pool ;--.
| |
| water level less than the required limit, all ECCS injection/spray subsystems are inoperable unless they are aligned to an OPERABLE CST.
| |
| When the suppression pool level is< 13 ft 3 inches, the HPCS System is considered OPERABLE only if it can take suction from the CST and the CST water level is sufficient to provide the required NPSH for the HPCS pump. Therefore, a verification that either the suppression pool water level is 2 13 ft 3 inches or the HPCS System is aligned to take suction from the CST and the CST contains 2 125,000 gallons of water, equivalent to 11 ft 1 inch; ensures that the HPCS System can supply makeup water to the RPV.
| |
| The 12 hour Frequency of these SRs was developed considering operating experience related to suppression pool and CST water level variations during the applicable MODES. Furthermore, the 12 hour Frequency is considered adequate in view of other indications in the control room, including alarms, to alert the operator to an abnormal suppression pool or CST water level condition.
| |
| (continued)
| |
| RIVER BEND B 3.5-18 Revision No. 0
| |
| | |
| EGGS-Shutdown B 3.5.2 BASES SURVEILLANCE SR 3.5.2.3, SR 3.5.2.5, and SR 3.5.2.6 REQUIREMENTS (continued) The Bases provided for SR 3.5.1.1, SR 3.5.1.4, and SR 3.5.1.5 are applicable to SR 3.5.2.3, SR 3.5.2.5, and SR 3.5.2.6, respectively.
| |
| SR 3.5.2.4 Verifying the correct alignment for manual, power operated, and automatic valves in the ECCS flow paths provides assurance that the proper flow paths will exist for ECCS operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position since these valves were verified to be in the correct position prior to locking, sealing, or securing. A valve that receives an initiation signal is allowed to be in a nonaccident position provided the valve will automatically reposition in the proper stroke time. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves.
| |
| The Surveillance capable of potentially being mispositioned are in the correct position.
| |
| Frt::quency is This SR does not apply to valves that cannot be inadvertently misaligned, controlled under tile such as check valves. The 31 day Frequency is appropriate because the Surveillance Frequency Control Program.
| |
| In MODES 4 and 5, the RHR System may operate in the shutdown cooling mode to remove decay heat and sensible heat from the reactor.
| |
| Therefore, RHR valves that are required for LPCI subsystem operation may be aligned for decay heat removal. This SR is modified by a Note that allows one LPCI subsystem of the RHR System to be considered OPERABLE for the ECCS function if all the required valves in the LPCI flow path can be manually realigned (remote or local) to allow injection into the RPV and the system is not otherwise inoperable. This will ensure adequate core cooling if an inadvertent vessel draindown should occur.
| |
| The Surveillance is modified by a Note which *exempts system vent flow paths opened under administrative control. The administrative control should be proceduralized and include stationing a dedicated individual at the system vent flow path who is in continuous communication with the operators in the control room. This individual will have a method to rapidly close the system vent flow path if directed.
| |
| REFERENCES 1. USAR, Section 6.3.3.4.
| |
| RIVER BEND 83.5-19 Revision No. 163
| |
| | |
| RCIC System B 3.5.3 BASES (continued)
| |
| SUFNEILLi\NCE S~ 3.5.3.1 !continued)
| |
| R,EQU\REMENTS personnel safety. For these locations alternative methods (e.g.,
| |
| operating parameters, remote monitoring) may be used to monitor the susceptible location. Monitoring is not required for susceptible locations where the maximum potential accumulated gas void volume has been evaluated and determined to not challenge system OPERABILITY. The accuracy of the method used for monitoring the susceptible locations and The Surveillance trending of the results should be sufficient to assure system F:--equency ls OPERABILITY during the Surveillance interval.
| |
| controi!ecl under the Surveillance The 31 day Frequency is based on the gradual nature of void buildup in Fraquency the RCIC piping, the procedural controls governing system operation, and Program. The operating experience.
| |
| Surveillance Frequency rnay SR 3.5.3.2 vary by location susceptible to Verifying the correct alignment for manual, power operated, and accurnu!ation. automatic valves in the RCIC flow path provides assurance that the proper flow path will exist for RCIC operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position since these were verified to be in the correct position prior to locking, sealing, or securing. A valve that receives an initiation signal is allowed to be in a nonaccident position provided the valve will automatically reposition in the proper stroke time. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves. For the RCIC System, this SR also includes the steam flow path for the turbine and the flow controller position.
| |
| The Surveillance Frequency is controlled under the Program requirements for performing valve testing at least every Surveillance 92 days. The Frequency of 31 days is further justified because the valves Frequency Control are operated under procedural control and because improper valve Program.
| |
| position would af:f.ect only the RCIC System. This Frequency has been shown to be acceptable through operating experience.
| |
| The Surveillance is modified by a Note which exempts system vent flow paths opened under administrative control. The administrative control should be proceduralized and include stationing a dedicated individual at the system vent flow path who is in continuous communication with the operators in the control room. This individual will have a method to rapidly close the system vent flow path if directed.
| |
| (continued)
| |
| RIVER BEND B 3.5-23a Revision No. 163
| |
| | |
| RCIC System B 3.5.3 BASES SURVEILLANCE SR 3.5.3.3 and SR 3.5.3.4 REQUIREMENTS (continued) The RCIC pump flow rates ensure that the system can maintain reactor coolant inventory during pressurized conditions with the RPV isolated.
| |
| The flow tests for the RCIC System are performed at two different pressure ranges such that system capability to provide rated flow is tested both at the higher and lower operating ranges of the system.
| |
| Additionally, adequate steam flow must be passing through the main turbine or turbine bypass valves to continue to control reactor pressure when the RCIC System diverts steam flow. Since the required reactor steam pressure must be available to perform SR 3.5.3.3 and SR 3.5.3.4, sufficient time is allowed after adequate pressure and flow are achieved to perform these SRs. Reactor startup is allowed prior to performing the low pressure Surveillance because the reactor pressure is low and the time to satisfactorily p'erform the Surveillance is short. The reactor pressure is allowed to be increased to normal operating pressure since it is assumed that the low pressure test has been satisfactorily completed and there is no indication or reason to believe that RCIC is inoperable.
| |
| Therefore, these SRs are modified by Notes that state the Surveillances The Surveillance are not required to be performed until 12 hours after the reactor steam Frequencies are pressure and flow are adequate to perform the test.
| |
| controlled under the Surveiliance Frequency Control Testing Program requirements. The 24 month Frequency for SR 3.5.3.4
| |
| -Program. is based on the need to perform this Surveillance under the conditions that apply just prior to or during startup from a plant outage.
| |
| SR 3.5.3.5 The RCIC System is required to actuate automatically to perform its design function. This Surveillance verifies that with a required system initiation signal (actual or simulated) the automatic initiation logic of RCIC will cause the system to operate as designed, including actuation of the system throughout its emergency operating sequence, (continued)
| |
| RIVER BEND B 3.5-24 Revision No. 143
| |
| | |
| RCIC System B 3.5.3 BASES SURVEILLANCE SR 3.5.3.5 (continued)
| |
| REQUIREMENTS automatic pump startup and actuation of all automatic valves to their required positions. This Surveillance test also ensures that the RCIC System will automatically restart on an RPV low water level (Level 2) signal received subsequent to an RPV high water level (Level 8) trip and that the suction is automatically transferred from the CST to the suppression pool. The LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.2, "Reactor Core Isolation Cooling (RCIC) System The Survsiilance Instrumentation," overlaps this Surveillance to provide complete testing of Frequency is the assumed safety function.
| |
| controiied under the Surveillance The 24 month Frequency is based on the need to perform this Frequency Control Surveillance under the conditions that apply during a plant outage and ProQram. the potential for an unplanned transient if the Surveillance were performed with the reactor at power.
| |
| This SR is modified by a Note that excludes vessel injection during the Surveillance. Since all active components are testable and full flow can be demonstrated by recirculation through the test line, coolant injection into the RPV is not required during the Surveillance.
| |
| REFERENCES 1. 10 CFR 50, Appendix A, GDC 33.
| |
| : 2. USAR, Section 5.4.6.2.
| |
| : 3. Memorandum from R.L. Baer (NRC) to V. Stello, Jr. (NRC),
| |
| "Recommended Interim Revisions to LCO's for ECCS Components," December 1, 1975.
| |
| : 4. USAR, Section 5.4.6.1 RIVER BEND B 3.5-25 Revision No. 143
| |
| | |
| Primary Containment Air Locks B 3.6.1.2 BASES SURVEILLANCE SR 3.6.1.2.1 (continued)
| |
| REQUIREMENTS the reactor coolant system is not pressurized and specific primary containment leakage limits are not imposed. However, due to the size of the air lock penetration, leakage limits are imposed to assure an OPERABLE barrier. In these conditions the leakage limits are not related to radiological evaluations, but only reflect engineering judgment of an acceptable barrier. The periodic testing requirements verify that the air lock leakage does not exceed the allowed fraction of the overall primary containment leakage rate. The Frequency is required by the Primary Containment Leakage Rate Testing Program.
| |
| The SR has been modified by two Notes. Note 1 states that an inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test. This is considered reasonable since either air lock door is capable of providing a fission.
| |
| product barrier in the event of aDBA. Note 2 has been added to this SR, requiring the results to be evaluated against the acceptance criteria of SR 3.6.1.1.1 during operation in MODES 1, 2, and 3. This ensures that air lock leakage is properly accounted for in determining the overall primary containment leakage rate. Since the overall primary containment leakage rate is only applicable in MODE 1, 2, and 3 operation, the Note 2 requirement is imposed only during these MODES.
| |
| SR 3.6.1.2.2 The Surveillanc:e The seal air flask pressure is verified to be at~ 90 psig every 7 days to Frequency is ensure that the seal system remains viable. It must be checked because controlled under the it could bleed down during or following access through the air lock, which Surveillance occurs regularly. The 7 day Frequency has been shown to be acceptable Frequency Control through operating experience and is considered adequate in viev, of the Program. other indications available to operations personnel that the seal air flask pressure is lm1v.
| |
| (continued)
| |
| RIVER BEND B 3.6-13 Revision No. 6-1 O
| |
| | |
| Primary Containment Air Locks B 3.6.1.2 BASES SURVEILLANCE SR 3.6.1.2.3 REQUIREMENTS (continued) The air lock interlock mechanism is designed to prevent simultaneous opening of both doors in the air lock. Since both the inner and outer doors of an air lock are designed to withstand the maximum expected post accident primary containment pressure (Ref. 3), closure of either door will support primary containment OPERABILITY. Thus, the interlock feature supports primary containment OPERABILITY while the air lock is being used for personnel transit in and out of the containment. Periodic testing The Surveillance of this interlock demonstrates that the interlock will function as designed Frequency is and that simultaneous inner and outer door opening will not inadvertently controlled under the occur. Due to the nature of this interlock, and given that the interlock Surveillance mechanism is only challenged when the primary containment airlock door Frequency Control is opened, this test is only required to be performed upon entering or Program. exiting a primary containment air lock, but is not required more frequently than once per 184 days. The 184 day Frequency is based on engineering judgment and is considered adequate in viev, of other administrative controls.
| |
| SR 3.6.1.2.4 A seal pneumatic system test to ensure that pressure does not decay at a rate equivalent to > 1.50 psig for a period of 24 hours from an initial pressure of 90 psig is an effective leakage rate test to verify system performance.
| |
| REFERENCES 1. USAR, Section 3.8.
| |
| : 2. 10 CFR 50, Appendix J, Option B.
| |
| : 3. USAR, Table 6.2-1.
| |
| : 4. USAR, 15.7.4.
| |
| : 5. Regulatory Guide 1.163, "Performance-Based Containment Leak-Test Program," dated September 1995.
| |
| RIVER BEND B 3.6-14 Revision No. 143
| |
| | |
| PCIVs B 3.6.1.3 BASES ACTIONS. F.1 and F.2 (continued) vessel (OPDRVs) to minimize the probability of a vessel draindown and subsequent potential for fission product release. Actions must continue until OPDRVs are suspended. If suspending the OPDRVs would result in closing the residual heat removal (RHR) shutdown cooling isolation valves, an alternative Required Action is provided to immediately initiate action to restore the valves to OPERABLE status. This allows RHR to remain in service while.actions are being taken to restore the valve.
| |
| SURVEILLANCE SR 3.6.1.3.1 REQUIREMENTS This SR verifies that the 36 inch primary containment purge valves are closed as required or, if open, open for an allowable reason. If a purge valve is open in violation of this SR, the valve is considered inoperable. If the inoperable valve is not otherwise known to have excessive leakage when closed; it is not considered to have leakage outside of the limits.
| |
| The SR is also modified by a Note (Note 1) stating that primary containment purge valves are only required to be closed in MODES 1, 2, and 3. At times other th*an MODE 1, 2, or 3 when the purge valves are required to be capable of closing (e.g., during movement of recently irradiated fuel assemblies) pressurization concerns are not present and the purge valves are allowed to be open (automatic isolation capability would be required by SR 3.6.1.3.4 and SR 3.6.1.3.7).
| |
| The SR is modified by a Note (Note 2) stating that the SR is not required to be met when the purge valves are open for the stated reasons. The Note states that these valves may be opened for pressure control, ALARA, or air quality considerations for personnel entry or for Surveillances, or special testing on the purge system that require the valves to be open (e.g., testing of the containment purge radiation monitors). These primary containment purge valves are capable of closing in the environment following a LOCA. Therefore, these valves are allowed to be open for limited periods of time. The 31 day Frequency is consistent with other PCIV requirements.
| |
| 1 (continued)
| |
| ------J The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
| |
| RIVER BEND - B 3.6-22 Revision No. 11 O
| |
| | |
| PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.1 (continued)
| |
| REQUIREMENTS Note 3 to this SR ensures that both SGT subsystems are not damaged should a primary containment pressurization event occur and that one is always available for its' design function.
| |
| SR 3.6.1.3.2 I
| |
| I I I This SR verifies that each primary containment isolation manual valve and blind flange that is located outside primary containment, drywell, and steam tunnel, and is required to be closed during accident conditions, is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside of the primary containment boundary is within design limits. This SR does not require any testing or valve manipulation.
| |
| Rather, it involves verification that those devices outside primary containment, drywell, and steam tunnel, and capable of being The Surveillance mispositioned, are in the correct position. Since verification of position for Frequency is devices outside primary containment is relatively easy, the 31 day control!ecJ under the Frequency was chosen to provide added assurance that the devices are Surveillance in the correct positions.
| |
| Frequency Control Program. Three Notes are added to this SR. Note 1 provides an exception to meeting this SR in MODES other than MODES 1, 2, and 3. When not operating in MODES 1, 2, or 3, the primary containment boundary, including verification that required penetration flow paths are isolated, is addressed by LCO 3.6.1.10, "Primary Containment-Shutdown" (SR 3.6.1.10.1 ). The second Note applies to valves and blind flanges located in high radiation areas and allows them to be verified by use of administrative controls. Allowing verification by administrative controls is considered acceptable, since access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of these devices, once they have been verified to be in the proper position, is low. A third Note is included to clarify that PC IVs open under administrative controls are not required to meet the SR during the time the PCIVs are open.
| |
| (continued)
| |
| RIVER BEND B 3.6-23 Revision No. 0
| |
| | |
| PCIVs B 3.6.1.3
| |
| .BASES SURVEILLANCE SR 3.6.1.3.3 (contir~
| |
| REQUIREMENTS (continued) safety:.related spent fuel storage pool instrumentation to pro\fide level indication for the transfer pool. Since the IFTS transfer tube drain line is not isolated in a manner similar to the transfer tube, and the motor-operated drain valve may. be opened while the blind flange is removed, administrative controls are required to ensure the drain line flow path is quickly isolated in the event of a LOCA. In this instance, administrative control of the IFTS transfer tube drain line isolation valve includes stationing a dedicated individual, who is in continuous communication with the control room, in the vicinity of the IFTS drain tank in the fuel building.
| |
| This individual will initiate closure of the IFTS transfer tube drain line motor-operated isolation valve (F42:..MOVF003) if a need for primary containment isolation is indicated. Removal of the blind flange is limited to 60 days per operating cycle while in Modes 1,2, or 3 to reduce the risk significance of this activity. The pressure integrity of the IFTS transfer tube, the seal created by water depth of the fuel building spent fuel storage pool, the administrative control of the drain line flow path, and the time limit for blind flange removal create an acceptable barrier to prevent the post-OBA LOCA containment building atmosphere from leaking into the fuel building.
| |
| SR 3.6.1.3.4 Verifying the isolation time of each power operated and each automatic PCIV is within limits is required to demonstrate OPERABILITY. MSIVs may be excluded from this SR since MSIV full closure isolation time is demonstrated by SR 3.6.1.3.6. The isolation time test ensures that the valve will isolate in a time period less than or equal to that assumed in the safety analysis. The isolation time and Frequency of this SR are in accordance with the lnservice Testing Program.
| |
| (continued)
| |
| RIVER BEND B 3.6-24a Revision No. 6-11
| |
| | |
| PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.7 REQUIREMENTS (continued) Automatic PCIVs close on a primary containment isolation signal to prevent leakage of radioactive material from primary containment following a OBA. This SR ensures that each automatic PCIV will actuate to its isolation position on a primary containment isolation signal. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.1.6 overlaps this SR to provide complete testing of the safety function. The 24 month Frequency The Surveiiiance is based on the need to perform this Surveillance under the conditions Frequency is that apply during a plant outage and the potential for an fJnplanned controlled under the transient if the Surveillance were performed with the reactor at power.
| |
| Survei!l::;nce Frequency Control SR 3.6.1.3.8 Program.
| |
| The use of MS-PLCS as a positive leakage barrier results in in-leakage and gradual pressure buildup within the containment. The total allowable MSIV in-leakage rate does not have radiological consequences. This surveillance ensures that the total allowable air in-leakage rate is limited such that containment pressurization does not exceed 50 percent of the design value in a 30 day period due to these sources.
| |
| The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at povver.
| |
| SR 3.6.1.3.9 This SR ensures that the leakage rate of secondary containment bypass leakage paths is less than the specified leakage rate when pressurized to
| |
| ;::: Pa* 7 .6 psig. This provides assurance that the assumptions in the radiological (continued)
| |
| RIVER BEND B 3.6-26 Revision No. 143
| |
| | |
| Primary Containment Pressure
| |
| . B 3.6.1.4 BASES (continued)
| |
| APPLICABILITY In MODES 1, 2, and 3, a OBA could result in a release of radioactive material to primary containment. In MODES 4 and 5, the probability and consequences of these events are reduced due to the pressure and temperature limitations of these MODES. Therefore, maintaining primary containment pressure within limits is not required in MODE 4 or 5.
| |
| ACTIONS When primary containment pressure is not within the limits of the LCO, differential pressure must be restored to within limits within 1 hour. The Required Action is necessary to return operation to within the bounds of the primary containment analysis. The 1 hour Completion Time is consistent with the ACTIONS of LCO 3.6.1.1, "Primary Containment-Operating," which requires that primary containment be restored to OPERABLE status within 1 hour.
| |
| 8.1 and 8.2 If primary containment pressure cannot be restored to within limits within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE SR 3.6.1.4.1 REQUIREMENTS Verifying that primary containment pressure is within limits ensures that operation remains within the limits assumed in the primary containment analysis. The 12 hour Frequency of this SR was developed based on operating experienoe related to trending primary containment pressure variations during the applicable MODES. Furthermore, the 12 hour Frequency is considered adequate in view of other indications available in f
| |
| the control room, including alarms, to alert the operator to an abnormal primary containment pressure condition.
| |
| REFERENCES 1. USAR, Section 6.2.
| |
| I
| |
| .--------J The Surveillance Frequency is controlled under the Surveii!ance Frequency Control Program.
| |
| RIVER BEND B 3.6-31 Revision No. O
| |
| | |
| Primary Containment Air Temperature B 3.6.1.5 BASES (continued)
| |
| APPLICABILITY In MODES 1, 2, and 3, a OBA could cause a release of radioactive material to primary containment. In MODES 4 and 5, the probability and consequences of these events are reduced due to the pressure and temperature limitations of these MODES. Therefore, maintaining primary containment average air temperature within the limit is not required in MODE 4 or 5.
| |
| ACTIONS /
| |
| When primary containment average air temperature is not within the limit of the LCO, it must be restored within 8 hours. This Required Action is necessary to return operation to within the bounds of the primary containment analysis. T,he 8 hour Completion Time is acceptable, considering the sensitivity of the analysis to variations in this parameter, and provides sufficient time to correct minor problems.
| |
| B.1 and B.2 If the primary containment average air temperature cannot be restored to within limit within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE SR 3.6.1.5.1 REQUIREMENTS Verifying that the primary containment average air temperature is within the LCO limit ensures that operation remains within the limits assumed for the primary containment analyses. In order to determine the primary containment average air temperature, an arithmetic average is calculated, using measurements taken at locations within the primary containment The Survei!!ance selected to provide a representative sample of the overall primary Frequency is containment atmosphere.
| |
| controiled under the Surveillance The 24 hour Frequency of this SR is considered acceptable based on Frequency Control observed slovv rates of temperature increase within primary containment Program. as a result of environmental heat (continued)
| |
| (continued)
| |
| RIVER BEND B 3.6-33 Revision No. O J
| |
| | |
| Primary Containment Air Temperature B 3.6.1.5 BASES (continued)
| |
| SURVEILLANCE SR 3.6.1.5.1 (continued)
| |
| REQUIREMENTS sources (due to large volume of the primary containment). Furthermore, the 24 hour Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal primary containment air temperature condition.
| |
| REFERENCES 1. USAR, Section 6.2.
| |
| RIVER BEND B 3.6-34 Revision No. O
| |
| | |
| LLS Valves B 3.6.1.6 BASES SURVEILLANCE SR 3.6.1.6.1 (continued)
| |
| REQUIREMENTS frequency of the required relief-mode actuator testing was developed based on the tests required by ASME OM Code (ref. 3) as implemented by the lnservice Testing Program of Specification 5.5.6. The testing frequency required by the lnservice Testing Program is based on operating experience and valve performance. Therefore, the frequency was concluded to be acceptable from a reliability standpoint.
| |
| SR 3.6.1.6.2 The LLS designed S/RVs are required to actuate automatically upon receipt of specific initiation signals. A system functional test is performed to verify that the mechanical portions (i.e., solenoids) of the automatic LLS function operate as designed when initiated either by an actual or simulated automatic initiation signal. The LOGIC SYSTEM FUNCTIONAL Tr1e Surveillance TEST in SR 3.3.6.4.4 overlaps this SR to provide complete testing of the Frequency is safety function.
| |
| controileci under the Surveillance The 24 month Frequency is based on the need to perform this Frnquency Control Surveillance under the conditions that apply during a plant outage and the Prograrr1. potential for an unplanned transient if the Surveillance \Nere performed *
| |
| 'Nith the reactor at power.
| |
| This SR is modified by a Note that excludes valve actuation. This prevents a reactor pressure vessel pressure blowdown.
| |
| REFERENCES 1. GESSAR-11, Appendix 38, Attachment A, Section 3BA.8.
| |
| : 2. USAR, Section 5.2.2.
| |
| : 3. ASME OM Code for Operation and Maintenance of Nuclear Power Plants.
| |
| : 4. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.
| |
| RIVER BEND B 3.6-38 Revision No. 161
| |
| | |
| Primary Containment Unit Coolers B 3.6.1.7 BASES SURVEILLANCE SR 3.6.1.7.1 REQUIREMENTS Verifying the correct alignment for pressure relief and backdraft dampers in the primary containment unit cooler ventilation flow path provides assurance that the proper flow paths will exist for system operation. This SR does not apply to dampers that are locked, sealed, or otherwise secured in position, since these were verified to be in the correct position prior to locking, sealing, or securing. This SR does not require any testing The Surveillance or damper manipulation; rather, it involves verification that those dampers Frequency is capable of being mispositioned are in the correct position.
| |
| controlled under the Surveillance The 31 day Frequency of this SR is justified because the dampers are Frequency Control operated under procedural control and because improper positioning Program. would affect only a single unit cooler. This Frequency has been shown to be acceptable based on operating experience.
| |
| (continued)
| |
| RIVER BEND B 3.6-41 a Revision No. 161
| |
| | |
| Primary Containment Unit Coolers B 3.6.1.7 BASES SURVEILLANCE SR 3.6.1.7.2 REQUIREMENTS (continued) Verifying each unit cooler develops a flow rate ;:::: 50,000 cfm ensures overall performance has not degraded during the cycle. Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. The Frequency of this SR is consistent with that applied to pumps by the lnservice Testing Program.
| |
| SR 3.6.1.7.3 This SR verifies that each primary containment unit cooler actuates upon receipt of an actual or simulated automatic actuation signal throughout its' emergency operating sequence and that the pressure relief and backdraft damper in the flow path actuates to its' correct position. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.3.5 overlaps this SR to provide complete testing of the safety function. The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed vvith the reactor at pm,ver.
| |
| REFERENCES 1. USAR, Section 6.2.1.1.3.4.
| |
| : 2. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.
| |
| RIVER BEND B 3.6-42 Revision No. 161
| |
| | |
| MS-PLCS B 3.6.1.9 BASES SURVEILLANCE SR 3.6.1.9.1 (continued)
| |
| REQUIREMENTS from the PVLCS accumulators. Due to the support system function of PVLCS for S/RV actuator air, however, the specified minimum pressure of 101 psig is required, which provides sufficient air for intermediate and long term post-LOCA S/RV actuations. This minimum air pressure alone is sufficient for PVLCS to support the OPERABILITY of these S/RV systems and is verified every 24 hours. The 24 hour Frequency is considered adequate in view of other indications available in the control room, such as alarms, to alert the operator to an abnormal PVLCS air pressure condition.
| |
| The Surveillance Frequency is controlled under the SR 3.6.1.9:2 Surveillance Frequency Control Each PVLCS compressor is operated for~ 15 minutes to verify MS-PLCS Program. OPERABILITY. The 31 day Frequency was developed considering the knovm reliability of the PVLCS compressor and controls, the t\vo subsystem redundancy, and the low probability of a significant degradation of the MS PLCS subsystem occurring betv.1een surveillances and has been shovvn to be acceptable through operating experience.
| |
| SR 3.6.1.9.3 A system functional test is performed to ensure that the MS-PLCS will operate through its operating sequence. The 24 month Frequency is
| |
| * based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance 'Nere performed 1.vith the reactor at power.
| |
| REFERENCES 1. USAR, Section 6.7.
| |
| : 2. USAR, Section 15.6.5.
| |
| : 3. NEDC-32988, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.
| |
| RIVER BEND B 3.6-49 Revision No. 161
| |
| | |
| Primary Containment-Shutdown B 3.6.1.10 BASES SURVEILLANCE SR 3.6.1.10.1 (continued)
| |
| REQUIREMENTS Rather, it involves verification, through a system walkdown, that the required valves are in the correct position. The 31 day Frequency was chosen to provide added assurance that the valves remain in the correct positions.
| |
| The Survei!!ance Frequency is The SR is modified by a Note stating that the SR is not required to be met controlled the for vent and drain line pathways provided the total calculated flow rate Surveillance through open vent and drain pathways is ::; 70.2 cfm. Administrative Frequency Control controls ensure that open vent and drain pathways will: (1) only be Prograrn. opened to support leakage rate testing; (2) not exceed 12 valves; (3) require monitoring opened vent and drain valves, as well as the containment-to-auxiliary building differential pressure every 2 hours; and (4) assure at least one person is assigned to each open penetration (Ref.
| |
| 1).
| |
| REFERENCES 1. NRG SER for TS Amendment #35, dated March 3, 1989.
| |
| : 2. USAR, Section 15.7.6.
| |
| RIVER BEND B 3.6-53 Revision No. 0
| |
| | |
| Suppression Pool Average Temperature B 3.6.2.1 BASES ACTIONS E.1 and E.2 (continued)
| |
| If suppression pool average temperature cannot be maintained::::; 120°F, the plant must be brought to a MODE in which the Leo: does not apply.
| |
| To achieve this status, the reactor pressure must be reduced to
| |
| < 200 psig within 12 hours and the plant must be brought to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner without challenging plant systems.
| |
| Continued addition of heat to the suppression pool with pool temperature
| |
| > 120°F could result in exceeding the design basis maximum allowable values for primary containment temperature or pressure.
| |
| SURVEILLANCE SR 3.6.2.1.1 REQUIREMENTS The suppression pool average temperature is regularly monitored to ensure that the required limits are satisfied. Ave,rage temperature is determined by taking an arithmetic average of the functional suppression pool water temperature channels. The 24 hour Frequency has been The time interval shovm to be acceptable based on operating experience. When heat is based Surveillance being added to the suppression pool by testing, however, it is necessary Frequency is to monitor suppression pool temperature more frequently. The 5 minute controlled under the Frequency during testing is justified by the rates at which testing will heat Surveillance up the suppression pool, has been shown to be acceptable based on Frequency Centro! operating experience, and provides assurance that allowable pool Program. temperatures are not exceeded. The Frequencies 5 minute Frequency afe-is further justified in view of other indications available in the control room, including alarms, to alert the operator to an abnormal suppression pool average temperature condition.
| |
| REFERENCES 1. USAR, Section 6.2.
| |
| : 2. USAR, Section 15.2.
| |
| RIVER BEND B 3.6-58 Revision No. 0.
| |
| | |
| Suppression Pool Water Level B 3.6.2.2 BASES ACTIONS B.1 and B.2 (continued)
| |
| If suppression pool water level cannot be restored to within limits within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE SR 3.6.2.2.1 REQUIREMENTS Verification of the suppression pool water level is to ensure that the required limits are satisfied. The 24 hour Frequency of this SR was The Survemance developed considering operating experience related to trending variations Frequency is in suppression pool *.Nater level and *.vater level instrument drift during the controlled under the applicable MODES and to assessing the proximity to the specified LCO Survei!iance level limits. Furthermore, the 24 hour Frequency is considered adequate Frequency Control in view of other indications available in the control room, including alarms, Program.
| |
| to alert the operator to an abnormal suppression pool \Nater level condition.
| |
| REFERENCES 1. USAR, Section 6.2.
| |
| RIVER BEND B 3.6-61 Revision No. O
| |
| | |
| RHR Suppression Pool Cooling B 3.6.2.3 BASES ACTIONS
| |
| . (c6ntinued) D.1 and D.2 If the required Action and required Completion Time of Condition C cannot be met or if two RHR suppression pool cooling subsystems are inoperable, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE SR 3.6.2.3.1 REQUIREMENTS Verifying the correct alignment for manual, power operated, and automatic valves, in the RHR suppression pool cooling mode flow path provides assurance that the proper flow path exists for system operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position since these valves were verified-to be in the correct position prior to being locked, sealed, or secured. A valve is also allowed to be in the nonaccident position, provided it can be aligned to the accident position within the time assumed in the accident analysis. This is acceptable, since the RHR suppression pool cooling mode is manually initiated. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being mispositioned are in the correct position. This SR does not apply to valves that cannot be The Surveiiiance inadvertently misaligned, such as check valves.
| |
| Frequency is controlled under the The Frequency of 31 days is justified because the valves are operated Surveil!ance under procedural control, improper valve position would affect only a Frequency single subsystem, the probability of .an event requiring initiation of the Program. system is low, and the subsystem is a manually initiated system. This Frequency has been shown to be acceptable, based on operating experience.
| |
| SR 3.6.2.3.2 RHR Suppression Pool Cooling System piping and components have the potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper operation of the RHR suppression pool cooling subsystems and may also prevent water hammer and pump cavitation.
| |
| (continued)
| |
| RIVER BEND B 3.6-64a Revision No. 163
| |
| | |
| RHR Suppression Pool Cooling B 3.6.2.3 BASES SURVEILLANCE SR 3.6.2.3.2 (continued)
| |
| REQUIREMENTS (continued) Selection of RHR Suppression Pool Cooling System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise caus*e gas to be trapped or difficult to remove during system maintenance or restoration. Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions.
| |
| The RHR Suppression Pool Cooling System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible location exceeds an acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR Suppression Pool Cooling System is not rendered inoperable by the accumulated gas (i.e., the system is sufficiently filled with water), the Surveillance may be declared met.
| |
| Accumulated gas should be eliminated or brought within the acceptance criteria limits.
| |
| RHR Suppression Pool Cooling System locations susceptible to gas accumulation are monitored and, if gas is found, the gas volume is compared to the acceptance criteria for the location. Susceptible locations in the same system flow path which are subject to the same gas intrusion mechanisms may be verified by monitoring a representative sub-set of susceptible locations. Monitoring may not be practical for locations that are inaccessible due to radiological or environmental conditions, the plant configuration, or personnel safety. For these locations alternative methods (e.g., operating parameters, remote monitoring) may be used to The Surveillance monitor the susceptible location. Monitoring is not required for susceptible Frequency is locations where the maximum potential accumulated gas void volume has controlled under the been evaluated and determined to not challenge system OPERABILITY.
| |
| Surveiiiance The accuracy of the method used for monitoring the susceptible locations Frequency Control and trending of the results should be sufficient to assure system Program. The OPERABILITY durin9 the Surveillance interval.
| |
| Surveiliance Frequency rnay vary The 31 day Frequency takes into consideration the gradual nature of gas by location accumulation in the RHR Suppression Pool Cooling System piping and susceptible to gas the procedural controls governing system operation.
| |
| accumulation. '
| |
| RIVER BEND B 3.6-64b Revision No. 163
| |
| | |
| Primary Containment and Drywell Hydrogen lgniters B 3.6.3.2 BASES ACTIONS C.1 (continued) operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE SR 3.6.3.2.1 and SR 3.6.3.2.2 REQUIREMENTS These SRs verify that there are no physical problems that could affect the igniter operation. Since the igniters are mechanically passive, they are not subject to mechanical failure. The only credible failures are loss of power or burnout. The verification that each required igniter is energized is performed by circuit current versus voltage measurement of each circuit.
| |
| Tr!e Surveillance Frequencies are controlled under the operating experience because of the low failure occurrence, and provides Surveiiiance assurance that hydrogen burn capability exists between the more rigorous Frequency Control 24 month Surveillanoes. Operating experience has shown these Prograrn. components usually pass the Surveillance when performed at a 184 day Frequency. Additionally, these surveillances must be performed every 92 days if four or more igniters in any division are inoperable. The 92 day Frequency was chosen, recognizing that the failure occurrence is higher than normal. Thus, decreasing the Frequency from 184 days to 92 days is a prudent measure, since only PA'O more inoperable igniters (for a total of six) will result in an inoperable igniter division. SR 3.6.3.2.2 is modified by a Note that indicates that the Surveillance is not required to be performed until 92 days after four or more igniters in the division are discovered to be inoperable.
| |
| SR 3.6.3.2.3 and SR 3.6.3.2.4 These functional tests are performed every 24 months to verify system.
| |
| OPERABILITY. The current draw to develop a surface temperature of
| |
| ;;:: 1700°F is verified for igniters in inaccessible areas. Inaccessible areas are defined as areas that have high radiation levels during the entire refueling outage period. These areas are the heat exchanger, filter demineralizer, backwash, and holding pump rooms of the RWCU system.
| |
| Additionally, the surface temperature of each accessible igniter is verified to be ;;:: 1700°F to demonstrate (continued)
| |
| RIVER BEND B 3.6-76 Revision No. 143
| |
| | |
| Primary Containment and Drywell Hydrogen lgniters
| |
| 14:47, 13 May 2024 (EDT) B 3.6.3.2 The Surveillance Frequency is controlled uncler the Surveillance Frequency Control Program.
| |
| BASES SURVEILLANCE SR 3.6.3.2.3 and SR 3.6.3.2.4 (continued)
| |
| REQUIREMENTS that a temperature sufficient for ignition is achieved. The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed ,Nith the reactor at power.
| |
| REFERENCES 1. 10 CFR 50.44.
| |
| : 2. 10 CFR 50, Appendix A, GDC 41.
| |
| : 3. USAR, Section 6.2.5.
| |
| RIVER BEND B 3.6-77 Revision No. 143
| |
| | |
| Primary Containment/Drywell Hydrogen Mixing System B 3.6.3.3 BASES SURVEILLANCE SR 3.6.3.3.1 (continued)
| |
| REQUIREMENTS and 3, because these valves have never been demonstrated capable of closing during accident conditions in the drywell (Reference 3). The 92 day frequency is consistent with operating experience, the known reliability of the fan and controls, and the two redundant subsystems available.
| |
| SR 3.6.3.3.2 The Surveillance Verifying that each primary containment/drywell hydrogen mixing Frequency is subsystem flow rate is ~ 600 cfm ensures that each subsystem is capable controlled under tile of maintaining drywell hydrogen concentrations below the flammability Surveiliance limit. The 24 month Frequency is based on the need to perform this Frequency Control Surveillance under the conditions that apply during a plant outage when Program. the dl)0Nell boundary is not required.
| |
| REFERENCES* 1. Regulatory Guide 1.7, Revision 2.
| |
| : 2. USAR, Section 6.2.5.
| |
| : 3. CR 96-0767.
| |
| RIVER BEND B 3.6-82 Revision No. 143
| |
| | |
| Secondary Containment-Operating B 3.6.4.1.
| |
| BASES SURVEILLANCE SR 3.6.4.1.1 REQUIREMENTS This SR ensures that the shield building annulus and auxiliary building is Tl1e Surveillanc.e sufficiently leak tight to preclude exfiltration under expected wind Frequency is conditions. The 24 hour Frequency of this SR 11.1as developed based on controlled under the operating experience related to secondary containment vacuum variations Surveillance during 'the applicable MODES and the low probability of a OBA occurring Frequency Control between surveillances.
| |
| Program.
| |
| Furthermore, the 24 hour Frequency is considered adequate in viev.r of other indications available in the control room, including alarms, to alert the operator to an abnormal secondary containment vacuum condition.
| |
| SR 3.6.4.1.2 and SR 3.6.4.1.3 Verifying that secondary containment equipment hatches are closed/installed and access doors are closed ensures that the infiltration of outside air of such a magnitude as to prevent maintaining the desired negative pressure does not occur. Verifying that all such openings are closed provides adequate assurance that exfiltration from the secondary containment will not occur. In this application the term "sealed" has no connotation of leak tightness, rather inadvertent opening is prevented.
| |
| Maintaining secondary containment OPERABILITY requires verifying each The Su:veiliance door in the access opening is closed, except when the access opening is Frequendes me being used for entry and exit. Verifying the main plant exhaust duct drain controlled under the loop seal and the turbine building/auxiliary building exhaust duct drain Surveillance loop seals are full of water also prevents infiltration of outside air and Frequency Control xfiltration from the secondary containment. The 31 day Frequency for these SRs has been shown to be adequate based on operating ProQram.
| |
| experience, and is considered adequate in vievv of the other controls on secondary containment access openings.
| |
| (continued)
| |
| RIVER BEND B 3.6-86 Revision No. 161
| |
| | |
| Secondary Containment-Operating B 3.6.4.1 BASES SURVEILLANCE SR 3.6.4.1.4 and SR 3.6.4.1.6 REQUIREMENTS The SGT System exhausts the shield building annulus and auxiliary building atmosphere to the environment through appropriate treatment equipment. To ensure that all fission products are treated, SR 3.6.4.1.4 verifies that the SGT System will rapidly establish and maintain a pressure in the shield building annulus and auxiliary building that is less than the lowest postulated pressure external to the secondary containment boundary. This is confirmed by demonstrating that one SGT subsystem will draw down the shield building annulus and auxiliary building to ~ 0.5 and~ 0.25 inches of vacuum water gauge in :s; 18.5 and :s; 34.5 seconds, respectively. This cannot be accomplished if the secondary containment boundary is not intact. SR 3.6.4.1.6 demonstrates that each SGT subsystem can maintain ~ 0.5 and ~ 0.25 inches of vacuum water gauge The Surveillance for 1 hour. The 1 hour test period allows shield building annulus and Frequencies are auxiliary building to be in thermal equilibrium at steady state conditions.
| |
| contro!!eci under the Therefore, these two tests are used to ensure the integrity of this portion Surveillance of the secondary containment boundary. Since these SR.s are secondary Frequency Control containment tests, they need not be*performed with each SGT subsystem.
| |
| Program. The SGT subsystems are tested on a STAGGER.ED TEST BASIS, however, to ensure that in addition to the requirements of LCO 3.6.4 .3, either SGT subsystem will perform this test.
| |
| * REFERENCES 1. USAR, Section 15.6 . 5.
| |
| : 2. USAR, Section 15.7.4.
| |
| : 3. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.
| |
| RIVER BEND B 3.6-87 Revision No. 161
| |
| | |
| SCI Os/FBI Os B 3.6.4.2 BASES ACTIONS C.1 and C.2 (continued)
| |
| If any Required Action and associated Completion Time cannot be met for SCI Os, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience,, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
| |
| 0.1, 0.2, and 0.3 If any Required Action and associated Completion Time cannot be met, the plant must be placed in a condition in which the LCO does not apply.
| |
| When applicable, movement of recently irradiated fuel assemblies in the fuel building must be immediately suspended. Suspension of this activity shall not preclude completion of movement of a component to a safe position.
| |
| Required Action D.1 has been modified by a Note stating that LCO 3.0.3 is not applicable. If moving recently irradiated fuel assemblies while in MODE 4 or 5, LCO 3.0.3 would not specify any action. If moving recently irradiated fuel assemblies while in MODE 1, 2, or 3, the fuel movement is independent of reactor operations. Therefore, in either case, inability to suspend movement of irradiated fuel assemblies would not be a sufficient reason to require a reactor shutdown.
| |
| SURVEILLANCE SR 3.6.4.2.1 REQUIREMENTS Verifying the isolation time of each required power operated automatic SCIO and FBID is within limits is required to demonstrate OPERABILITY.
| |
| The isolation time test ensures that the SCI Os and FBI Os will isolate in a time period less than or equal to that assumed in the safety analyses.
| |
| The fequency of this SR is 92 days. (continued)
| |
| .-----------..J The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
| |
| RIVER BEND B 3.6-93 Revision No. 115
| |
| | |
| SCI Os/FBI Os B 3.6.4.2 BASES SURVEILLANCE SR 3.6.4.2.2 REQUIREMENTS (continued) Verifying that each required automatic SCIO and FBID closes on an isolation signal is required to prevent leakage of radioactive material from secondary containment or fuel building following a OBA or other accidents. This SR ensures that each automatic SCIO will actuate to the The Surveillance isolation position on a secondary containment isolation signal and that Frequency is each FBID will actuate on a fuel building isolation signal. The LOGIC controlled under the SYSTEM FUNCTIONAL TEST in SR 3.3.6.2.5 overlaps this SR to provide
| |
| * Surveillance complete testing of the safety function. The 24 month Frequency is based Frequency Control on the need to perform this Surveillance under the conditions that apply Program. during a plant outage and the potential for an unplanned transient if the Surveillance were performed 111ith the reactor at pmA.<er.
| |
| REFERENCES 1. USAR, Section 15.6.5.
| |
| : 2. USAR, Section 6.2.3.
| |
| : 3. USAR, Section 15.7.4.
| |
| : 4. TRM, Table 3.6.4.2-1.
| |
| RIVER BEND B 3.6-94 Revision No. 143
| |
| | |
| SGT System B 3.6.4.3 BASES SURVEILLANCE SR 3.6.4.3.1 REQUIREMENTS Operating each SGT subsystem for~ 15 continuous minutes ensures that both subsystems are OPERABLE and that all associated controls are functioning properly. It also ensures that blockage, fan or motor failure, or excessive vibration can be detected for corrective action. The 31 day Frequency was developed in consideration of the known reliability of fan motors and controls and the redundancy availaele in the system. ~
| |
| SR 3.6.4.3.2 This SR verifies that the required SGT filter testing is performed in accordance with the Ventilation Filter Testing Program (VFTP). The SGT System filter tests are in accordance with Regulatory Guide 1.52 (Ref. 4).
| |
| The VFTP includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations).
| |
| Specified test frequencies and additional information are discussed in detail in the VFTP.
| |
| SR 3.6.4.3.3 This SR requires verification that each SGT subsystem starts upon receipt of an actual or simulated initiation signal. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.2.5 overlaps this SR to provide complete testing of the safety function. <l~-------------------i SR 3.6.4.3.4 This SR requires verification that the SGT filter cooling bypass damper can be opened and the fan started. This ensures that the ventilation mode of SGT System operation is available. -
| |
| (continued)
| |
| Tt1e Surveillance Frequency is controlled under ttla Surveillance Frequency Control Program.
| |
| RIVER BEND B 3.6-99 Revision No. 159
| |
| | |
| SGT System B 3.6.4.3 BASES (continued)
| |
| SURVEILLANCE SR 3.6.4 .3.4 (continued)
| |
| REQUIREMENTS available.
| |
| REFERENCES 1. 10 CFR 50, Appendix A, GDC 41.
| |
| : 2. USAR, Section 6.2.3.
| |
| : 3. USAR, Section 15.6.5.
| |
| : 4. Regulatory Guide 1.52, Rev. 2.
| |
| : 5. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification 'to Selected Required End States for BWR Plants, December 2002.
| |
| RIVER BEND B 3.6-100 Revision No. 161
| |
| | |
| Fuel Building B 3.6.4.5 BASES (continued)
| |
| APPLICABILITY Regardless of the plant operating MODE, anytime recently irradiated fuel is being handled there is the potential for a FHA and the fuel building OPERABILITY is required to mitigate the consequences.
| |
| ACTIONS With the fuel building inoperable the plant must be brought to a condition in which the LCO does not apply since it is incapable of performing its required accident mitigation function. To achieve this, handling of recently irradiated fuel (i.e., fuel that has occupied part of a critical core within the previous 24 hours) must be suspended immediately. Suspension shall not preclude completion of fuel movement to a safe position.
| |
| SURVEILLANCE SR 3.6.4.5.1 REQUIREMENTS This SR ensures that the fuel building boundary is sufficiently leak tight to preclude exfiltration under expected wind conditions. The 24 hour The Surveillance Frequency is controiied under the Furthermore, the 24 hour Frequency is considered adequate in vie¥.' of SurveiHance other indications available in the control room, including alarms, to alert Frequency Controi the operator to an abnormal fuel building vacuum condition.
| |
| Prograrn.
| |
| SR 3.6.4.5.2 and SR 3.6.4.5.3 Verifying that fuel building equipment hatches are installed and access doors are closed ensures that the infiltration of outside air of such a magnitude as to prevent maintaining the desired negative pressure does not occur. Verifying that all such openings are closed provides adequate*
| |
| assurance that exfiltration from the fuel building will not occur.*
| |
| Maintaining fuel building OPERABILITY requires verifying each door in the access opening is closed, except when the access opening is being used for entry and exit.
| |
| (continued)
| |
| RIVER BEND B 3.6-105 Revision No. 11 O
| |
| | |
| The Surveillance Frequencies are controllecl Fuel Building under the Sl!rveil!ance Frequency Controi B 3.6.4.5 Program.
| |
| BASES SURVEILLANCE SR 3.6.4.5.2 and SR 3.6.4.5.3 (continued)
| |
| REQUIREMENTS The 31 day Frequency for these SRs has been shovm to be adequate based on operating experience, and is considered adequate in viev.r of the other indications of door and hatch status that are available to the operator.
| |
| REFERENCES 1. USAR, Chapter 15.
| |
| RIVER BEND B 3.6-106 Revision No. O
| |
| | |
| Fuel Building Ventilation System-Fuel Handling B 3.6.4.7 BASES ACTIONS' With one fuel building ventilation charcoal filtration subsystem inoperable, the inoperable subsystem must be restored to OPERABLE status within 7 days. In this Condition, the remaining OPERABLE fuel building ventilation charcoal filtration subsystem is adequate to perform the required radioactivity release control function. However, the overall system reliability is reduced because a single failure in the OPERABLE subsystem could result in the radioactivity release control function not being adequately performed. The 7 day Completion Time is based on consideration of such factors as the availability of the OPERABLE redundant fuel building ventilation charcoal filtration subsystem and the low probability of a FHA occurring during this period.
| |
| B.1 and B.2 If the fuel building ventilation charcoal filtration subsystem cannot be restored to OPERABLE status within the required Completion Time the plant must be brought to a condition in which the LCO does not apply.
| |
| Additionally, if both subsystems are inoperable or if the on*e required subsystem not in operation the system is incapable of performing its required accident mitigation function and the plant must be brought to a condition in which the LCO does not apply. To achieve this, recently irradiated fuel handling must be suspended immediately. Suspension shall not preclude completion of fuel movement to a safe position.
| |
| SURVEILLANCE SR 3.6.4.7.1 REQUIREMENTS This Surveillance demonstrates that one fuel building ventilation charcoal filtration subsystem is in operation and filtering the fuel building atmosphere. The Frequency of 12 hours is sufficient in view of other visual and audible indications available to the operator for monitoring the fuel building ventilation charcoal filtration subsystem in the control room.
| |
| i (continued)
| |
| I Tile Surveiliance Frequency is controiied under the Survei!!ance Frequency Control Program.
| |
| RIVER BEND B 3.6-114 Revision No. 6-5
| |
| | |
| Fuel Building Ventilation System-Fuel Handling B 3.6.4.7 BASES SURVEILLANCE SR 3.6.4.7.2 REQUIREMENTS (continued) Operating each fuel building ventilation charcoal filtration subsystem for
| |
| ~ 15 continuous minutes ensures that both subsystems are OPERABLE and that all associated controls are functioning properly. It also ensures that blockage, fan or motor failure, or excessive vibration can be detected for corrective action. The 31 day rrequency v;as developed in consideration of the known reliability of fan motors and controls and the
| |
| ,tedundancy available in the system; SR 3.6.4.7.3 The Surveillance This SR Verifies that the required fuel* building ventilation charcoal filtration Frequency is filter testing is performed in accordance with the Ventilation Filter Testing controlled under the Program (VFTP). The fuel building ventilation charcoal filtration filter tests Survei!iance are in accordance with Regulatory Guide 1.52 (Ref. 4). The VFTP Frequency Control includes testing HEPA filter performance, charcoal adsorber efficiency, Program. minimum system flow rate,- and the physical properties of the activated charcoal (general use and following specific operations). Specified test frequencies and additional information are discussed in detail in the VFTP.
| |
| SR 3.6.4.7.4 This SR requires verification that each fuel building ventilation charcoal filtration subsystem starts upon receipt of an actual or simulated initiation signal. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.2.5 overlaps this SR to provide complete testing of the safety function.
| |
| (continued)
| |
| )
| |
| RIVER BEND 83.6-115 Revision No. 159
| |
| - I
| |
| | |
| Fuel Building Ventilation System-Fuel Handling B 3.6.4.7 BASES SURVEILLANCE SR 3.6.4.7.5 REQUIREMENTS (continued) This SR requires verification that the fuel building ventilation charcoal filtration filter cooling bypass damper can be opened and the fan started.
| |
| This ensures that the ventilation mode of Fuel Building Ventilation System operation is a v a i l a b l e . << - ~ - - - - - - - - - - - - - - - - - - - ~
| |
| REFERENCES 1. 10 CFR 50, Appendix A, GDC 41.
| |
| : 2. USAR, Section 6.2.3.
| |
| : 3. USAR, Section 15.6.5.
| |
| : 4. Regulatory Guide 1.52, Rev. 2.
| |
| The Surveillance Frequency is controlled under the Surveiilance Frequency Contra! Program.
| |
| . RIVER BEND B 3.6-116 Revision No. 143
| |
| | |
| Drywell B 3.6.5.1 BASES ACTIONS A.1 (continued) drywell is inoperable is minimal. Also, the Completion Time is the same as that applied to inoperability of the primary containment in LCO 3.6.1.1, "Primary Containment-Operating."
| |
| B.1 and B.2 If the drywell cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
| |
| SURVEILLANCE SR 3.6.5.1.1 REQUIREMENTS The seal air flask pressure is verified to be at ;:::: 75 psig every 7 days to ensure that the seal system remains viable. It must be checked because it could bleed down during or following access through the personnel door. The 7 day Frequency has been shown to be acceptable through operating experience and is considered adequate in view of the other indications available to operations personnel that the seal air flask The Surveillance.
| |
| pressure is low.
| |
| Frequency is controliecl under the Surveiiiance SR 3.6.5.1.2 Frequency Control Program. A seal pneumatic system test to ensure that pressure does not decay at a rate equivalent to > 20.0 psig for a period of 24 hours from an initial pressure of 75 psig is an effective leakage rate test to verify system
| |
| ' performance. The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.
| |
| (continued)
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| RIVER BEND B 3.6-119 Revision No. 143
| |
| | |
| Drywell B 3.6.5.1 BASES SURVEILLANCE SR 3.6.5.1.3 REQUIREMENTS (continued) The analyses in Reference 1 are based on a maximum drywell bypass leakage. This Surveillance ensures that the actual drywell bypass leakage is less than or equal to the acceptable A/~ design value of 0.81 ft2. As left drywell bypass leakage, prior to the first startup after performing a required drywell bypass leakage test, is required to be ::;; 10%
| |
| of the drywell bypass leakage limit. At all other times between required drywell leakage rate tests, the acceptance criteria is based on design A/-v-
| |
| : k. At the design A/~ the containment temperature and pressurization response are bounded by the assumptions of the safety analysis. Due to NRC Generic Letter 96-06 concerns, integrity of the reactor recirculation flow control valve hydraulic power unit (HPU) penetrations cannot be assumed. For this reason, 0.0164 ft2 is added to the drywell bypass leakage surveillance result (Ref. 3). This surveillance is performed at least once every 15 years on a performance based frequency. The frequency is consistent v.rith the difficulty of performing the test, risk of high radiation exposure, and the remote possibility that sufficient component failures will occur such that the dl)'\vell bypass leakage limit \\'ill be
| |
| __........-"'exceeded. If during the performance of this required Surveillance the The normal drywell bypass leakage rate is greater than the drywell bypass leakage Survei\lance limit, the Surveillance Frequency is increased to every 48 months. If Frequency is during the performance of the subsequent consecutive Surveillance the contro!ied under the drywell bypass leakage rate is less than or equal to the drywell bypass Surveillance leakage limit, the 15 year Frequency in accordance the Surveiliance Frequency Control Frequency Control Program may be resumed. If during the performance Progra1n, of two consecutive Surveillances the drywell bypass leakage is greater than the drywell bypass leakage limit, the Surveillance Frequency is increased to at least once every 24 months. The 24 month Frequency is maintained until during the performance of two consecutive Surveillances the drywell bypass leakage rate is less than or equal to the drywell bypass leakage limit, at which time the 15 year Frequency in accordance with the Surveillance Frequency Controi Program may be resumed. For two Surveillances to be considered consecutive, the Surveillances must be performed at least 12 months apart. Since the frequency is performance based, the Frequency 1.Mas concluded to be acceptable from a reliability standpoint.
| |
| SR 3.6.5.1.4 The exposed accessible drywell interior and exterior surfaces are inspected to ensure there are no apparent physical defects that would prevent the drywell from (continued)
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| RIVER BEND B 3.6-120 Revision No.* 157
| |
| | |
| Drywell B 3.6.5.1 BASES SURVEILLANCE SR 3.6.5.1.4 (continued)
| |
| REQUIREMENTS performing its intended function. This SR ensures that drywell structural integrity is maintained. The Frequency was chosen so that the interior and exterior surfaces of the drywell can be inspected in conjunction with the inspections of the primary containment required by 10 CFR 50, Appendix J (Ref. 2). Due to the passive nature of the drywell structure, the specified Frequency is sufficient to identify component degradation that may affect drywell structural integrity.
| |
| SR 3.6.5.1.5 This SR requires a test be performed to verify seal leakage of the drywell air lock doors at 3.0 psid. An administrative seal leakage rate limit has been established in plant procedures to ensure the integrity of the seals.
| |
| The Surveillance is only required to be performed once within 72 hours after each closing. The Frequency of 72 hours is based on operating experience.
| |
| SR 3.6.5.1.6 The Surveiiiance Frequency is .
| |
| controlled under the Surveillance Frequency Control Program.
| |
| REFERENCES 1. USAR, Chapter 6 and Chapter 15.
| |
| : 2. 10 CFR 50, A'ppendix J
| |
| : 3. Engineering Request (ER)-RB-99-07 41 RIVER BEND B 3.6-121 Revision No. 119
| |
| | |
| Drywell Air Lock B 3.6.5.2 BASES (continued)
| |
| SURVEILLANCE SR 3.6.5.2.2 (continued)
| |
| REQUIREM~NTS The Surveillance Frequency is controi!ecl under the The air lock door interlock is designed to prevent simultaneous opening of both doors in the air lock. Since both the inner and outer doors of the air Surveillance lock are designed to withstand the maximum expected post accident Frequency Control drywell pressure, closure of either door will support drywell Program.
| |
| OPERABILITY. Thus, the door interlock feature supports drywell OPERABILITY while the air lock is being used for personnel transit in and out of the drywell. Periodic testing and preventive maintenance of this interlock demonstrates that the interlock will function as designed and that simultaneous inner and outer door opening will not inadvertently occur.
| |
| Due to the nature of this interlock, and given that the interlock mechanism is only challenged when a drywell air lock door is opened, this test is only required to be performed once every 24 months. The 24 month Frequency is based on the need to perform this Surveillance under the reduced reactivity conditions that apply during a plant outage and the potential for violating the dryvtlell boundary. Operating experience has shown these components usually pass the Surveillance, and the Frequency is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
| |
| The Surveillance is modified by a Note requiring the Surveillance to be performed only upon entry into the drywell.
| |
| SR 3.6.5.2.4 DELETED SR 3.6.5.2.5 This SR ensures that the drywell air lock seal pneumatic (continued)
| |
| RIVER BEND B 3.6-127 Revision No. 2-4
| |
| | |
| Drywell Air Lock B 3.6.5.2 BASES (continued)
| |
| SURVEILLANCE SR 3.6.5.2.5 (continued)
| |
| REQUIREMENTS '
| |
| system pressure does not decay at an unacceptable rate. The air lock seal will support drywell OPERABILITY down to a pneumatic pressure of The Surveiiiance 75 psig. Since the air lock seal air flask pressure is verified in Frequency is SR 3.6.5.2.2 to be~ 75 psig, a decay rate :s: 20.0 psig over 24 hours is acceptable. The 24 hour interval is based on engineering judgment, controlied under U1e considering that there is no postulated OBA where the drywell is still Surveillance pressurized 24 hours after the event. The 24 month Frequency is based Frequency Control on the need to perform this Surveillance under the conditions that apply Program. during a plant outage when the air lock OPERABILITY is not required.
| |
| REFERENCES 1. 10 CFR 50, Appendix J.
| |
| : 2. USAR, Chapters 6 and 15.
| |
| RIVER BEND B 3.6-128 Revision No. 143
| |
| | |
| Drywell Isolation Valves B 3.6.5.3 BASES SURVEILLANCE SR 3.6.5.3.1 REQUIREMENTS Each 24 inch drywell purge isolation valve is required to be periodically verified sealed closed at 31 day intervals. This Surveillance is required since the drywell purge isolation valves are not qualified to close under accident conditions. This SR is designed to ensure that a gross breach of drywell is not caused by an inadvertent or spurious drywell purge isolation valve opening. Detailed analysis of these 24 inch drywell purge valves failed to conclusively demonstrate their ability to close during a LOCA in time to support drywell OPERABILITY. Therefore, these valves are required to be in sealed closed position during MODES 1, 2, and 3.
| |
| These 24 inch drywell purge valves that are sealed closed must have motive power to the valve operator removed. This can be accomplished by de-energizing the source of electric power or removing the air supply to The Survei!lance the valve operator. In this application, the term "sealed" has no Frequency is connotation of leakage within limits. The Frequency is based on purge controlled under the valve use during unit operations.
| |
| Surveillance SR 3.6.5.3.2 Frequency Control Program.
| |
| This SR ensures that the primary containmenUdrywell hydrogen mixing isolation valves are closed as required or, if open, open for an allowable reason for limited periods of time. This SR has been modified by a Note indicating the SR is not required to be met when the primary containmenUdrywell hydrogen mixing inlet or outlet valves are open for pressure control.
| |
| The 31 day Frequency is consistent with the valve SR 3.6.5.3.3 This SR requires verification that each drywell isolation manual valve and blind flange that is required to be closed during accident conditions is closed. The SR helps to ensure that drywell bypass leakage is maintained to a minimum. Due to the location of these devices, the Frequency specified as "prior to entering MODE 2 or 3 from MODE 4, if
| |
| .not performed in the previous 92 days," is appropriate because of the inaccessibility of the devices and because these devices are operated under administrative controls and the probability of their misalignment is low.
| |
| Two Notes are added to this SR. The first Note allows valves and blind flanges located in high radiation areas to (continued)
| |
| RIVER BEND B 3.6-134 Revision No. 2-8
| |
| | |
| Drywell Isolation Valves B 3.6.5.3 BASES SURVEILLANCE SR 3.6.5.3.4 REQUIREMENTS (continued) be verified by use of administrative controls. Allowing verification by administrative controls is considered acceptable since access to these areas is typically restricted during MODES 1, 2, and 3. Therefore, the probability of misalignment of these devices, once they have been veri,fied to be in their proper position, is low. A second Note is included to clarify that the drywell isolation valves that are open under administrative controls are not required to meet the SR during the time that the devices are open.
| |
| Verifying that the isolation time of each power operated and each automatic drywell isolation valve is within limits is required to demonstrate OPERABILITY. The isolation time test ensures the valve will isolate in a time period less than or equal to that assumed in the safety analysis. The isolation time and Frequency of this SR are in accordance with the lnservice Testing Program ..
| |
| SR 3.6.5.3.5 Verifying that each automatic drywell isolation valve closes on a drywell isolation signal is required to prevent bypass leakage from the drywell following a OBA. This SR ensures each automatic drywell isolation valve will actuate to its isolation position on a drywell isolation signal. The The Sun1eil!ance LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.1.6.overlaps this SR to.
| |
| Frequency is provide complete testing of the safety function. Tho 24 month Frequency is based on the need to perform this Surveillance under the conditions controlled under the that apply during a plant outage and the potential for an unplanned Surveillance transient if the Surveillance were performed v,ith the reactor at power, Freq*uency Control since isolation of penetrations would eliminate cooling water flmu and Program. disrupt the normal operation of many critical components.
| |
| SR 3.6.5.3.6 This SR ensures that the hydrogen mixing valves remain closed during Modes 1, 2, and 3, or, if open, are only open for a limited period of time over a 365 day cycle. Since (continued)
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| RIVER BEND B 3.6-135 Revision No. 143
| |
| | |
| Drywell Isolation Valves B 3.6.5.3 BASES SURVEILLANCE SR 3.6.5.3.6 REQUIREMENTS (continued) the hydrogen mixing isolation valves have never been demonstrated capable of closing under accident conditions in the drywell, this SR applies restrictions to the opening of these valves (Reference 3). +J::le ~~------.
| |
| frequency of this SR is consistent vvith the frequency of SR 3.6.3.2 and allmNs the administrative tracking of the hours open to be performed concurrently with the isolation valve closure verification.
| |
| REFERENCES 1. USAR, Section 6.2.4.
| |
| : 2. USAR, Table 6.2-51.
| |
| : 3. CR 96-0767.
| |
| The Surveillance Frequency is controlied under the Surveillance Frequency Control Program.
| |
| RIVER BEND B 3.6-136 Revision No. 6-2
| |
| | |
| Drywell Pressure B 3.6.5.4 BASES (continued)
| |
| SURVEILLANCE SR 3.6.5.4.1 REQUIREMENTS This SR provides assurance that the limitations on drywell-to-primary containment differential pressure stated in the LCO are met. The 12 hour The Survelllance Frequency of this SR was developed, based on operating experience Frequency is related to trending of dl)"Nell pressure variations during the applicable controlled under the MODES and to assessing proximity to the specified LCO differential Surveillance pressure limits. Furthermore, the 12 hour Frequency is considered Frequency Control adequate in view of other indications available in the control room, Program. including alarms, to alert the operator to an abnormal dryi.vell pressure condition. 1 REFERENCES 1. USAR, Section 6.2.1.
| |
| : 2. USAR, Section 3.8.
| |
| : 3. USAR, Section 6.2.1.1.3.
| |
| RIVER BEND B 3.6-139 Revision No. 2-8
| |
| | |
| Drywell Air Temperature B 3.6.5.5 BASES SURVEILLANCE SR 3.6.5.5.1 (continued)
| |
| REQUIREMENTS distributed, an arithmetic average is an accurate representation of actual The Surveillance ~drywell average temperature.
| |
| Frequency is The 24 hour Frequency of the SR was developed based on operating controlled under tile experience related to variations in drywell average air temperature Surveillance variations during the applicable MODES. Furthermore, the 24 hour Frequency Control Frequency is considered adequate in view of other indications available in Program. the control room, including alarms, to alert the operator to an abnormal dry.veil air temperature condition.
| |
| REFERENCES 1. USAR, Section 6.2.
| |
| RIVER BEND B 3.6-142 Revision No. 2-8 J
| |
| | |
| SSW System and UHS B 3.7.1 BASES SURVEILLANCE SR 3.7.1.1 (continued)
| |
| REQUIREMENTS inoperable. The 24 hour Frequency is based on operating experience related to trending of the parameter variations during the applicable MODES.
| |
| SR 3.7.1.2 Verification of the UHS arithmetical average water temperature ensures that the heat removal capability of the SSW System is within the The Surveillance assumptions of the OBA analysis. The average shall include at least 4 Frequency is OPERABLE sensors of which at least half shall be located above controlled under the elevation 94'-0". The 24 hour Frequency is based on operating experience Surveillance related to trending of the parameter variations during the applicable Frequency Control MODES.
| |
| Program.
| |
| SR 3.7.1.3 Operating each cooling tower fan cell for~ 15 minutes ensures that all fans are OPERABLE and that all associated controls are functioning properly. It also ensures that fan or motor failure, or excessive vibration can be detected for corrective action. The 31 day Frequency is based on operating experience, the knovm reliability of the fan units, the redundancy available, and the low probability of significant degradation of the cooling tower fans occurring between Surveillances.
| |
| SR 3.7.1.4 Verifying the correct alignment for each required manual, power operated, and automatic valve in each SSW subsystem flow path provides assurance that the proper flow paths will exist for SSW operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these valves were verified to be in the correct position prior to locking, sealing, or securing. A valve is also allowed to be in the nonaccident position and yet considered in the correct position, provided it can be automatically realigned to its accident position within the required time. This SR does not require any testing or valve manipulation; rather, it involves verification that (continued)
| |
| RIVER BEND B 3.7-7 Revision No. 161
| |
| | |
| SSW System and UHS B 3.7.1 BASES SURVEILLANCE SR 3.7.1.4 (continued)
| |
| REQUIREMENTS those valves capable of potentially being mispositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves.
| |
| Isolation of the SSW subsystem to components or systems does not necessarily affect the OPERABILITY of the SSW System. As such, when all SSW pumps, valves, and piping are OPERABLE, but a branch connection off the main header is isolated, the SSW subsystem needs to be evaluated to determine if it is still OPERABLE.
| |
| The 31 day Frequency is based on engineering judgment, is consistent
| |
| * with the procedural controls governing valve operation, and ensures correct valve positions.
| |
| The Surveillance SR 3.7.1.5 Frequency is controliecl under the This SR verifies that the automatic isolation valves of the SSW System Survei:lance will automatically switch to the safety or emergency position to provide Frequency Control cooling water exclusively to the safety related equipment during an accident event. This is demonstrated by use of an actual or simulated Program. initiation signal. This SR also verifies the automatic start capability of the SSW pump and cooling tower fans in each subsystem. Any series of sequential or overlapping steps which demonstrate the required function may be used to satisfy this requirement.
| |
| REFERENCES 1. Regulatory Guide 1.27, Revision 2, January 1976.
| |
| : 2. USAR, Section 9.2.
| |
| : 3. USAR, Table 9.2-15.
| |
| : 4. USAR, Section 6.2.1.
| |
| (continued)
| |
| RIVER BEND B 3.7-8 Revision No. 143
| |
| | |
| CRFA System B 3.7.2 BASES ACTIONS F.1 and F.2 (continued)
| |
| During movement of recently irradiated fuel assemblies in the primary containment or fuel building or during OPDRVs, with two CRFA subsystems inoperable, or with one or more CRFA subsystems inoperable due to an inoperable CRE boundary, action must be taken immediately to suspend activities that present a potential for releasing radioactivity that might require isolation of the CRE. This places the unit in a condition that minimizes the accident risk.
| |
| If applicable, movement of recently irradiated fuel assemblies in the primary containment and fuel building must be suspended immediately.
| |
| Suspension of these activities shall not preclude completion of movement of a component to a safe position. If applicable, actions must be initiated immediately to suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential for fission product release. Actions must continue until the OPDRVs are suspended.
| |
| SURVEILLANCE SR 3.7.2.1 REQUIREMENTS This SR verifies that a subsystem in a standby mode starts on demand from the control room and continues to operate with flow through the The Surveli!ance HEPA filters and charcoal adsorbers. Standby systems should be Frequency is checked periodically to ensure that they start and function properly. As controlled the the environmental and normal operating conditions of this system are not severe, testing each subsystem once every month provides an adequate Surveillance check on this system. Furthermore, the 31 day Frequency is based on the Frequency Centro! known reliability of the equipment and the t\.ivo subsystem redundancy Program. available.
| |
| (continued)
| |
| RIVER BEND B 3.7-14 Revision No. 159
| |
| | |
| CRFA System B 3.7.2 BASES SURVEILLANCE SR 3.7.2.2 REQUIREMENTS (continued) This SR verifies that the required CRFA testing is performed in accordance with the Ventilation Filter Testing Program (VFTP). The CRFA filter tests are in accordance with Regulatory Guide 1.52 (Ref. 5).
| |
| The VFTP includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations).
| |
| Specific test Frequencies and additional information are discussed in detail in the VFTP .
| |
| . SR 3.7.2.3 This SR verifies that each CRFA subsystem starts and operates on an actual or simulated initiation signal. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.7.1.5 overlaps this SR to provide complete testing of the safety function.
| |
| The Surveiliance 1
| |
| Frequency is SR 3.7.2.4 controlled under the This SR verifies the OPERABILITY of the CRE boundary by testing for Survei!lance unfiltered air inleakage past the CRE boundary and into the CRE. The Frequency Control details of the testing are specified in the Control Room Envelope Program. Habitability Program.
| |
| The CRE is considered habitable when the radiological dose to CRE occupants calculated in the licensing basis analyses of OBA consequences is no more than 5 rem TEDE and the CRE occupants are protected from hazardous chemicals and smoke. This SR verifies that the unfiltered air inleakage into the CRE is no greater than the flow rate assumed in the licensing basis analyses of OBA consequences. When unfiltered air in leakage is greater than the assumed flow rate, Condition B must be entered. Required Action B.3 allows time to restore the CRE boundary to OPERABLE status provided mitigating actions can ensure that the CRE remains within the licensing basis habitability limits for the occupants following an accident. Compensatory measures are discussed in Regulatory Guide 1.196, Section C.2.7.3, (Ref. 7) which endorses, with exceptions, NEI 99-03, Section 8.4 and Appendix F (Ref. 8). These compensatory measures may also be used as mitigating actions as required by Required Action 8.2. Temporary analytical methods may also be used as compensatory measures to restore OPERABILITY (Ref. 9).
| |
| Options for restoring the CRE boundary to OPERABLE status include changing the licensing basis OBA consequence analysis, repairing the CRE boundary, or a combination of these actions. Depending upon the nature of the problem and the corrective action, a full scope inleakage test may not be necessary to establish that the CRE boundary has been restored to OPERABLE status.
| |
| (continued)
| |
| RIVER BEND B 3.7-15 Revision No. 143
| |
| | |
| Control Room AC System
| |
| \ B 3.7.3 BASES ACTIONS E.1 and E.2 (continued) not preclude completion of movement of a component to a safe position.
| |
| Also, if applicable, actions must be initiated immediately to suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential for fission product release. Actions must continue until the OPDRVs are suspended.
| |
| SURVEILLANCE SR 3.7.3.1 REQUIREMENTS This SR verifies that the heat removal capability of the system is sufficient to remove the control room heat load assumed in the safety analysis. The SR consists of a combination of testing and calculation. The 24 month
| |
| ~ - - - - - - - - - ; , - Frequency is appropriate since significant degradation of the Control Room AC System is not expected over this time period.
| |
| REFERENCES 1. USAR, Section 6.4.
| |
| : 2. USAR, Section 9.4.1.
| |
| : 3. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.
| |
| - The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
| |
| RIVER BEND B 3.7-21 Revision No. 161
| |
| | |
| Main Condenser Offgas B 3.7.4 BASES (continued)
| |
| ACTIONS (continued) The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.
| |
| SURVEILLANCE SR 3.7.4.1 REQUIREMENTS This SR requires an isotopic analysis of an offgas sample if the measured release rate of radioactivity increases significantly (by;:,:,: 50% after
| |
| * correcting for expected increases due to changes in THERMAL POWER),
| |
| within 4 hours after the increase is noted, to ensure that the increase is not indicative of a sustained increase in the radioactivity rate. The noble gases to be sampled are Xe-133, Xe-133m, Xe-135, Xe-138, Kr-85m, Kr-87, and Kr-88.
| |
| SR 3.7.4.2 The Surveiliance Frequency is controllecl under the Surveillance Fr2qu0ncy Control Program. This SR is modified by a Note indicating that the SR is not required to be performed until 31 days after any main steam line is not isolated and the SJAE is in operation. Only in this condition can radioactive fission gases be in the Main Condenser Offgas System at significant rates.
| |
| REFERENCES 1. USAR, Section 15.7.1.
| |
| : 2. NUREG-0800.
| |
| : 3. 10 CFR 100.
| |
| : 4. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.
| |
| RIVER BEND B 3.7-24 Revision No. 161
| |
| | |
| r Main Turbine Bypass System B 3.7.5 BASES ACTIONS 8.1 (continued) sufficient margin to the required limits, and the Main Turbine Bypass System is not required to protect fuel integrity during the feedwater controller failure, maximum demand event. The 4 hour Completion Time is reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.
| |
| SURVEILLANCE SR 3.7.5.1 REQUIREMENTS Cycling each main turbine bypass valve through one complete cycl~ of full travel demonstrates that the valves are mechanically OPERABLE and will function when required. The 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve positions. Therefore, the Frequency is acceptable from a reliability standpoint.
| |
| SR 3.7.5.2 The Main Turbine Bypass System is required to actuate automatically to perform its design function. This SR demonstrates that, with the required Frequency is system initiation signals, the valves will actuate to their required position.
| |
| controlled under the The 24 month Frequency is based on the need to perform this Surveillance Surveillance under the conditions that apply during a unit outage and Frequency Control because of tho potential for an unplanned transient if the Surveillance Program. \'lore performed 'Nith the reactor at power.
| |
| SR 3.7.5.3 This SR ensures that the TURBINE BYPASS SYSTEM RESPONSE TIME is in compliance with the assumptions of the appropriate safety analysis.
| |
| The response time limits are specified in applicable surveillance test procedures. The 24 month Frequency is based on the need to perform this Surveillance (continued)
| |
| (continued)
| |
| RIVER BEND B 3.7-27 Revision No. 143
| |
| | |
| Main Turbine Bypass System B 3.7.5 BASES (continued)
| |
| SURVEILLANCE SR 3.7.5.3 (continued)
| |
| REQUIREMENTS under tho conditions that apply during a unit outage and because of the potential for an unplanned transient if the Surveillance were performed with the reactor at povver.
| |
| REFERENCES 1. USAR, Section 7.7.1.4.
| |
| : 2. USAR, Section 15.1.2.
| |
| RIVER BEND B 3.7-28 Revision No. 143
| |
| | |
| Fuel Pool Water Level B 3.7.6 BASES (continued)
| |
| LCO The specified water level preserves the assumption of the fuel handling accident analysis (Ref. 2). As such, it is the minimum required for fuel movement within the spent fuel storage pool and upper containment fuel storage pool.
| |
| APPLICABILITY This LCO applies whenever movement of irradiated fuel assemblies occurs in the associated fuel storage racks since the potential for a release of fission products exists.
| |
| ACTIONS Required Action A.1 is modified by a Note indicating that LCO 3.0.3 does not apply. If moving irradiated fuel assemblies while in MODE 1, 2, or 3, the fuel movement is independent of reactor operations. Therefore, inability to suspend movement of irradiated fuel assemblies is not a sufficient reason to require a reactor shutdown.
| |
| When the initial conditions for an accident cannot be met, steps should be taken to preclude the accident from occurring. With either fuel pool level less than required, the movement of irradiated fuel assemblies in the associated storage pool is suspended immediately. Suspen~ion of this activity shall not preclude completion of movement of an irradiated fuel assembly to a safe position. This effectively precludes a spent fuel handling accident from occurring.
| |
| SURVEILLANCE SR 3.7.6.1 REQUIREMENTS This SR verifies that sufficient water is available in the event of a fuel handling accident. The water level in the spent fuel storage pool and upper containment fuel storage pool must be checked periodically. +Re 7 day Frequency is acceptable, based on operating experience, considering that the water volume in the pool is normally stable and water level changes are controlled by unit procedures.
| |
| t Tl1e Surveillance I (continued) f=requency is controlled under the Surveillance Frequency Controi Program.
| |
| RIVER BEND B 3.7-30 Revision No. 0
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.1 REQUIREMENTS (continued) This SR ensures proper circuit continuity for the two qualified circuits between the offsite transmission network and the onsite Class 1E Distribution System and availability of offsite AC electrical power. The breaker alignment verifies that each breaker is in its correct position to The Surveillance ensure that the Division 1, 2, and 3 distribution buses and loads are Frequency is connected to their preferred power source and that appropriate independence of offsite circuits is maintained. The 7 day Frequency is contro!!ed uncier the . .. . . .
| |
| Surveillance Frequency Control Program.
| |
| SR 3.8.1.2 and SR 3.8.1. 7 These SRs help to ensure the availability of the standby electrical power supply to mitigate DBAs and transients and maintain the unit in a safe shutdown condition.
| |
| To minimize the wear on moving parts that do not get lubricated when the engine is not running, these SRs have been modified by Notes (the Note for SR 3.8.1.7 and Note 2 for SR 3.8.1.2) to indicate that all DG starts for these Surveillances may be preceded by an engine prelube period and followed by a warm up period prior to loading.
| |
| For the purposes of this testing, the DGs are started from standby conditions. Standby conditions for a DG mean that the diesel engine coolant and oil are being continuously circulated and temperature is being maintained consistent with manufacturer recommendations for DG 1A and DG 1B. For DG 1C, standby conditions mean that the lube oil is heated by the jacket water and continuously circulated through a portion of the system as recommended by the vendor. Engine jacket water is heated by an immersion heater and circulates through the system by 1
| |
| natural circulation.
| |
| In order to reduce stress and wear on diesel engines, the manufacturer recommends that the DGs be gradually accelerated to synchronous speed prior to loading. These modified start procedures are the intent of Note 3, which is only applicable when such procedures are used.
| |
| (continued)
| |
| RIVER BEND B 3.8-14 Revision No. 127
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.2 and SR 3.8.1.7 (continued)
| |
| REQUIREMENTS SR 3.8.1.7 requires that, at a 184 day Frequency, the DG starts from standby conditions and achieves the required voltage and frequency within 1O seconds for DG 1A and DG 1B and 13 seconds for DG 1C. The start requirements for each DG support the assumptions in the design basis LOCA analysis (Ref. 5). The start requirements may not be applicable to 3.8.1.2 (see Note 3 of SR 3.8.1.2), when a modified start as described above is used. If a modified start is not used, the start requirements of SR 3.8.1. 7 apply. Since SR 3.8.1. 7 does require a 1 O second start for DG 1A and DG 1B and 13 seconds for DG 1C, it is more restrictive than SR 3.8.1.2, and it may be performed in lieu of SR 3.8.1.2.
| |
| This is the intent of Note 1 of SR 3.8.1.2. Similarly, the performance of SR 3.8.1.12 or SR 3.8.1.19 also satisfies the requirements of SR 3.8.1.2 and SR 3.8.1.7.
| |
| In addition to the SR requirements, the time for the DG to reach steady state operation, unless the modified DG start method is employed, is
| |
| *rhe Surveillance periodically monitored and the trend evaluated to identify degradation of Frequencies are governor and voltage regulator performance.
| |
| controlled under the Surveillance Frequency Control industry guidelines for assessment of diesel generator performance (Refs.
| |
| Prograrn. 14 and 15). The 184 day Frequency for SR 3.8.1.7 is a reduction in cold testing consistent with Generic Letter 84 15 (Ref. 7). These Frequencies provide adequate assurance of DG OPERABILITY, while minimizing degradation resulting from testing.
| |
| SR 3.8.1.3 This Surveillance demonstrates that the DGs are capable of synchronizing and accepting the surveillance test. The minimum run time of 60 minutes is required to stabilize engine temperatures, while minimizing the time that the DG is connected to the offsite source.
| |
| Although no power factor requirements are established by this SR, the DG is normally operated at a power factor between 0.8 lagging and 1.0. The 0.8 value is the design rating of the machine, while 1.0 is an operational limitation to ensure circulating (continued)
| |
| RIVER BEND B 3.8-15 Revision No. 162
| |
| __J
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.3 (continued)
| |
| REQUIREMENTS currents are minimized. The load band is provided to avoid routine overloading of the DG. Routine overloading may result in more frequent The Surveillance teardown inspections in accordance with vendor recommendations in Frequency is order to maintain DG OPERABILITY.
| |
| controlled under the Surveillance The 31 day Frequency for this Surveillance is consistent with the industry Frequency Control guidelines for assessment of diesel generator performance (Refs. 14 and Program. ~
| |
| Note 1 modifies this Surveillance to indicate that diesel engine runs for this Surveillance may include gradual loading, as recommended by the manufacturer, so that mechanical stress and wear on the diesel engine are minimized.
| |
| Note 2 modifies this Surveillance by stating that momentary transients do not invalidate this test. The lower limit of the load band ensures the generator is sufficiently loaded during the test and the upper limit of the load band is to avoid an overload of the diesel generator during the routine test. The upper and lower limits provide a reasonable band to operate the DG in for the specified run time while achieving the intent of a full-load. The Note recognizes that there are external grid conditions that can cause a shift in load sharing with the DG and allows the operator time to recognize and adjust load back into the band without invalidating the performance of the surveillance. It also allows for momentary transients where the DG governor system acts to bring the load back into the load band. Momentary DG load "spikes" which are beyond the ability of the operator to monitor and control with normal control room instrumentation, and which the governor acted to maintain proper DG load band do not invalidate the test and the DG can be considered to have met the intent of operating "at full rated 1o*ad" for the specified duration.
| |
| Note 3 indicates that this Surveillance shall be conducted on only one DG at a time in order to avoid common cause failures that might result from offsite circuit or grid perturbations.
| |
| Note 4 stipulates a prerequisite requirement for performance of this SR. A successful DG start must precede this test to credit satisfactory performance.
| |
| (continued)
| |
| RIVER BEND B 3.8-16 Revision No. 151
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.4 REQUIREMENTS This SR provides verification that the level of fuel oil in the day tank is at or above the level at which fuel oil is automatically added. The level is expressed as an equivalent volume in gallons, and is selected to ensure adequate fuel oil for a minimum of 1 hour of DG operation at full load.
| |
| The 31 day Frequency is adequate to assure that a sufficient supply of fuel oil is available, since lov,1 level alarms are provided and facility operators would be aware of any large uses of fuel oil during this period.
| |
| SR 3.8.1.5 Microbiological fouling is a major cause of fuel oil degradation. There are numerous bacteria that can grow in fuel oil and cause fouling, but all must have a water environment in order to survive. Periodic Removal removal of water from the fuel oil day tanks once every 31 days eliminates the necessary environment for bacterial survival. This is an effective means of controlling microbiological fouling. In addition, it eliminates the potential for water entrainment in the fuel oil during DG operation. Water may*
| |
| come from any of several sources, including condensation, ground water, rain water, contaminated fuel oil, and breakdown of the fuel oil by bacteria.
| |
| ~fhe Surveillance Frequent checking for and removal of accumulated water minimizes Frequency is fouling and provides data regarding the watertight integrity of the fuel oil controllecl under the system. The Surveillance Frequency is established by Regulatory Surveillance Guide 1.137 (Ref. 10). This SR is for preventive maintenance. The Frequency Con:ro! presence of water does not necessarily represent a failure of this SR Program. provided that accumulated water is removed during performance of this Surveillance.
| |
| SR 3.8.1.6 This Surveillance demonstrates that each required fuel oil transfer pump operates and transfers fuel oil from its associated storage tank to its associated day tank. It is required to support the continuous operation of standby power sources. This Surveillance provides assurance that the fuel oil transfer pump is OPERABLE, the fuel oil piping system is intact, the fuel delivery piping is not obstructed, and the controls and control systems for automatic fuel transfer systems are OPERABLE.
| |
| The design of the fuel transfer systems is such that pumps operate automatically in order to maintain an adequate volume of fuel oil in the day tanks during or following DG testing. Therefore, a 31 day Frequenoy is speoified to oorrespond to the maximum interval for DG testing.
| |
| (continued)
| |
| RIVER BEND B 3.8-17 Revision No. 102
| |
| | |
| /AC Sources - Operating
| |
| , B 3.8.1 BASES SURVEILLANCE SR 3.8.1.7 REQUIREMENTS See SR 3.8.1.2 SR 3.8.1.8 The SLirveillance Transfer of each 4.16 kV ESF bus power supply from the normal offsite Frequency is circuit to the alternate offsite circuit demonstrates the OPERABILITY of controlled under the the alternate circuit. This SR applies to Divisions 1, 2, and 3. +Re Surveiiiance 24 month Frequency of the Surveillance is based on engineering Frequency Control judgment taking into consideration the plant conditions required to perform 1
| |
| ~ rograrn. the Surveillance, and is intended to be consistent with expected fuel cycle lengths.
| |
| This SR is modified by a Note. The reason for the Note is that, during operation with the reactor critical, performance of this SR could cause perturbations to the electrical distribution systems that could challenge continued steady state operation and, as a result, plant safety systems.
| |
| Credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:
| |
| : 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and
| |
| : 2) Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY
| |
| , or reliability.
| |
| Note 2 specifies that this SR is required to be met only when the 22 kV onsite circuit is supplying 4.16 kV Division Ill safety related bus E22-S004, via transformer STX-XNS1 C and non-safety related switch gear NNS-SWG1A and NNS-SWG1B. This is acceptable because the feature being tested does not perform a safety function if the 230 kV offsite circuit is already supplying 4.16 kV buses NNS-SWG1A or NNS-SWG1 B through transformers RTX-XNS1 C or RTX-XNS1 D.
| |
| (continued)
| |
| RIVER BEND B 3.8-18 Revision No. 169
| |
| _J
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.9 REQUIREMENTS Each DG is provided with an engine overspeed trip to prevent damage to the engine. Recovery from the transient caused by the loss of a large load could cause diesel engine overspeed, which, if excessive, might result in a trip of the engine. This Surveillance demonstrates the DG load response characteristics and capability to reject the largest single load while maintaining a specified margin to the overspeed trip .. The referenced load for DG 1A is the 943.1 kW low pressure core spray pump; for DG 1B, the 477.9 kW residual heat removal (RHR) pump; and for DG 1 C the 1862.4 kW HPCS pump. The Standby Service Water (SSW) pump values are not used as the largest load since the SSW supplies cooling to the associated DG. If this load were to trip, it would result in the loss of th~ DG. As required by IEEE-308 (Ref. 13), the load rejection test is acceptable if the increase in diesel speed does not exceed 75% of the difference between synchronous speed and the overspeed trip setpoint, or 15% above synchronous speed, whichever is lower. For the River Bend The Surveiliance Station the lower value results from the first criteria.
| |
| Frequency is controlled under the This SR has been modified by two Notes. The reason for Note 1 is that Surveii!ance credit may be taken for unplanned events that satisfy this SR. Examples Frequency Control of unplanned events may include:
| |
| Program.
| |
| : 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and
| |
| : 2) Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in
| |
| * conjunction with maintenance required to maintain OPERABILITY or reliability.
| |
| In order to ensure that the DG is tested under load conditions that are as close to design basis conditions as possible, Note 2 requires that, if synchronized to offsite power, testing be performed using a power factor
| |
| ::; 0.9. This power factor is chosen to be representative of the actual design basis inductive loading that the DG could experience.
| |
| (continued)
| |
| RIVER BEND B 3.8-19 Revision No. 443- 157
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.10 REQUIREMENTS This Surveillance demonstrates the DG capability to reject a full load, i.e.,
| |
| maximum expected accident load, without overspeed tripping or exceeding the predetermined voltage limits. The DG full load rejection may occur because of a system fault or inadvertent breaker tripping. This Surveillance ensures proper engine generator load response under the simulated test conditions. This test simulates the loss of the total connected load that the DG experiences following a full load rejection and verifies that the DG does not trip upon loss of the load. These acceptance criteria provide DG damage protection. While the DG is not expected to experience this transient during an event and continue to be available, this response ensures that the DG is not degraded for future application, including reconnection to the bus if the trip initiator can be corrected or isolated.
| |
| In order to ensure that the DG is tested under load conditions that are as close to design basis conditions as possible, testing must be performed using a power factor:;::; 0.9. This power factor is chosen to be The Surveillance representative of the actual design basis inductive loading that the DG Frequency is would experience.
| |
| controlled under the Surveillance The 24 month Frequency is intended to be consistent 1.vith expected fuel Frequency Control cycle lengths.
| |
| Program.
| |
| This SR has been modified by a Note. The reason for the Note is that credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:
| |
| : 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and
| |
| . 2) Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.
| |
| (continued)
| |
| RIVER BEND B 3.8-20 Revision No. 143
| |
| | |
| AC Sources - Operating.
| |
| B 3.8.1 BASES SURVEILLANCE SR 3.8.1.11 REQUIREMENTS (continued) As required by Regulatory Guide 1.108 (Ref. 9), paragraph 2.a.(1 ), this Surveillance demonstrates the as designed operation of the standby power sources during loss of the offsite source. This test verifies all actions encountered from the loss of offsite power, including shedding of the Division I and II nonessential loads and energization of the emergency buses and respective loads from the DG. It further demonstrates the capability of the DG to automatically achieve the required voltage and frequency within the specified time.
| |
| The DG auto-start time of 1O seconds for DG 1A and DG 1 B and 13 seconds for DG 1C is derived from requirements of the accident analysis to respond to a design basis large break LOCA. The Surveillance should be continued for a minimum of 5 minutes in order to demonstrate that all starting transients have decayed and stability has been achieved.
| |
| The requirement to verify the connection and power supply of permanent and auto-connected loads is intended to satisfactorily show the relationship of these loads to the DG loading logic. In certain circumstances, many of these loads cannot actually be connected or loaded without undue hardship or potential for undesired operation. For instance, ECCS injection valves are not desired to be stroked open, systems are not capable' of being operated at full flow, or RHR systems performing a decay heat removal function are not desired to be realigned to the ECCS mode of operation. In lieu of actual demonstration of the connection and loading of these loads, testing that adequately shows the capability of the DG system to perform these functions is acceptable. This The Surveillance testing may include any series of sequential, overlapping, or total steps so Frequency is that the entire connection and loading sequence is verified.
| |
| control!ed under the Surveiilance The Frequency of 24 months takes into consideration unit conditions Frequency Control required to perform the Surveillance, ahd is intended to be consistent with Program. expected fuel cycle lengths.
| |
| (continued)
| |
| RIVER BEND B 3.8-21 Revision No. 143
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.12 (continued)
| |
| REQUIREMENTS This SR is modified by two Notes. T.he reason for Note 1 is to minimize The Surveillance wear and tear on the DGs during testing. For the purpose of this testing, Frequency is the DGs must be started from standby conditions, that is, with the engine controlled under the coolant and oil being continuously circulated and temperature maintained Surveillance consistent with manufacturer recommendations for DG 1A and DG 1B.
| |
| Frequ&ncy Centro! For DG 1C, standby conditions mean that the lube oil is heated by the Program. jacket water and continuously circulated through a portion of the system as recommended by the vendor. Engine jacket water is heated by an immersion heater and circulates through the system by natural circulation.
| |
| (Note 2 is not applicable to DG 1C) The reason for Note 2 is that during operation with the reactor critical, performance of this SR could cause perturbations to the electrical distribution systems that could challenge continued steady state operation and, as a result, plant safety systems.
| |
| Credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:
| |
| : 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and
| |
| : 2) Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.
| |
| SR 3.8.1.13 This Surveillance demonstrates that DG non-critical protective functions (e.g., high jacket water temperature)
| |
| (continued)
| |
| RIVER BEND B 3.8-23 Revision No. 143
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.13 (continued)
| |
| REQUIREMENTS are bypassed on an ECCS initiation test signal and critical protective functions trip the DG to avert substantial damage to the DG unit. The non-critical trips are bypassed during DBAs and provide alarms on abnormal engine conditions. These alarms provide the operator with necessary information to react appropriately. The DG availability to mitigate the OBA is more critical than protecting the engine against minor The Surveillance problems that are not immediately detrimental to emergency operation of Frequency is the DG.
| |
| controlled under U1e 4,1 Surveiiiance The 24 month Frequency is based on engineering judgment, taking into Frequency Control consideration plant conditions required to perform the Surveillance, and is Program. intended to be consistent with expected fuel cycle lengths.
| |
| The SR is modified by a Note. (The Note is not applicable to DG1C) The reason for the Note is that performing the Surveillance removes a required DG from service. Credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:
| |
| : 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and
| |
| : 2) Post corrective maintenance testing that requires performance of this Surveillance in order to1 restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.
| |
| SR 3.8.1.14 This surveillance requires demonstration once per 24 months that the DGs can start and run continuously at full load capability for an interval of not less than 24 hours-22 hours of whi'ch is at a load (continued)
| |
| RIVER BEND B 3.8-24 Revision No. 143
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.14 (continued)
| |
| REQUIREMENTS equivalent to the continuous rating of the DG, and 2 hours of which is at a load equivalent to 110% of the continuous duty rating of the DG. An exception to the loading requirements is made for DG 1A and DG 18. DG 1A and DG 1Bare operated for 24 hours at a load greater than or equal to the maximum expected post.accident load. Load carrying capability testing of the Transamerica Delaval Inc. (TOI) diesel generators (DG 1A and DG 18) has been limited to a load less than that which corresponds to 201 psig brake mean effective pressure (BMEP). Therefore, full load testing is performed at a load:?: 3050 kW but< 3130 kW. The DG starts for this Surveillance can be performed eith~r from standby or hot conditions. The provisions for prelube and warmup, discussed in SR 3.8.1.2, and for gradual loading, discussed in SR 3.8.1.3, are applicable to this SR.
| |
| In order to ensure that the DG is tested under load conditions that are as close to design conditions as possible, testing must be performed using a The Surveil!ance power factor::::; 0.9. This power factor is chosen to be representative of Frequency is the actual design basis inductive loading that the DG could experience.
| |
| control!ecl under the SuNeiHance Frequency Control Program.
| |
| This Surveillance is modified by two Notes. Note 1 states that momentary transients do not invalidate this test. The lower limit of the load band ensures the generator is sufficiently loaded during the test and the upper limit of the load band is to avoid an overload of the diesel generator during the routine test. The upper and lower limits provide a reasonable band to operate the DG in for the specified run time while achieving the intent of a full-load. The Note recognizes that there are external grid conditions that can cause a shift in load sharing with the DG and allows the operator time to recognize and adjust load back into the band without invalidating the performance of the surveillance. It also allows for momentary transients where the DG governor system acts to bring the load back into the load band. Momentary DG load "spikes" which are beyond the ability of the operator to monitor and control with normal control room instrumentation,
| |
| . and which the governor acted to maintain proper DG load band do not invalidate the test and the DG can be considered to have met the intent of operating "at full rated load" for the specified duration. Similarly, momentary power factor transients above the limit do not invalidate the test. The reason for Note 2 is that credit may be taken for unplanned events (continued)
| |
| RIVER BEf)JD B 3.8-25 Revision No. 162
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.14 (continued)
| |
| REQUIREMENTS that satisfy this SR. Examples of unplanned events may include:
| |
| : 1) Unexpected operational events which cause the eq\Jipment to
| |
| ,Perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and
| |
| : 2) Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.
| |
| SR 3.8.1.15 This Surveillance demonstrates that the diesel engine can restart from a hot condition, such as subsequent to shutdown from normal Surveillances, and achieve the required voltage and frequency within 1O seconds for DG 1A and DG 1B and within 13 seconds for DG 1C. The time requirements are derived from the requirements of the accident analysis to respond to a design basis large break LOCA. '
| |
| The Surveillance _ /This SR has been modified by ~o Notes. Note 1 ensures that the test is Frequency is performed with the diesel sufficiently hot. The requirement that the diesel controiled under the has operated for at least 1 hour at full load conditions prior to performance Surveiliance of this Surveillance and longer if necessary to stabilize the operating Frequency Control temperature, is based on manufacturer recommendations for achieving Program. hot conditions. Momentary transients do not invalidate this test. The lower limit of the load band ensures the generator is sufficiently loaded during the test and the upper limit of the load band is to avoid an overload of the diesel generator during the routine test. The upper and lower limits provide a reasonable band to operate the DG in for the specified run time while achieving the intent of a full-load. The Note recognizes that there are external grid conditions that can cause a shift in load sharing with the DG and allows the operator time to recognize and adjust load back into the band without invalidating the performance of the surveillance. It also allows for momentary transients where the DG governor system acts to bring the load back into the load band. Momentary DG load "spikes" which are beyond the ability of the operator to monitor and control with normal control room instrumentation, and which the governor acted to maintain proper DG load band do not invalidate the test and the DG can be considered to have met the intent of operating "at full rated load" for the specified duration. Note 2 allows all DG starts to be preceded by an engine prelube period to minimize wear and tear on the diesel during testing.
| |
| (continued)
| |
| RIVER BEND B 3.8-26 Revision No. 151
| |
| __ J
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.16 REQUIREMENTS (continued) As required by Regulatory Guide 1.108 (Ref. 9), paragraph 2.a.(6)/this Surveillance ensures that the manual synchronization and load transfer from the respective DG to each required offsite power source can be made and that the respective DG can be returned to ready-to-load status when offsite power is restored. It also ensures that the undervoltage logic is reset to allow the DG to reload if a subsequent loss of offsite power occurs. The DG is considered to be in ready-to-load status when the DG is at rated speed and voltage, the output breaker is open and can receive an auto-close signal on bus undervoltage, and the load sequence timers are reset.
| |
| Portions of the synchronization circuit are associated with the DG and portions with the respective offsite circuit. If a failure in the synchronization requirement of the Surveillance occurs, depending on the The Surveillance specific affected portion of the synchronization circuit, either the DG or the Frequency is associated offsite circuit is declare inoperable.
| |
| contro!ied under tilr:,
| |
| Surveillance The Frequency of 24 months takes into consideration plant conditions Frequency Control required to perform the Surveillance.
| |
| Program.
| |
| This SR is modified by a Note. (The Note is not applicable to DG 1C) The reason for the Note is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems. Credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:
| |
| : 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and
| |
| : 2) Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.
| |
| (continued)
| |
| RIVER BEND B 3.8-27 Revision No. 143
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.17 REQUIREMENTS (continued) Demonstration of the test mode override ensures that the DG availability under accident conditions is not compromised as the result of testing.
| |
| Interlocks to the LOCA sensing circuits cause the DG to automatically reset to ready-to-load operation if an ECCS initiation signal is received during operation in the test mode. Ready-to-load operation is defined as the DG running at rated speed and voltage with the DG output breaker open. These provisions for automatic switchover are required by IEEE-308 (Ref. 13), paragraph 6.2.6(2).
| |
| The requirement to automatically energize the emergency loads with offsite power is essentially identical to that of SR 3.8.1 '. 13. The intent in the requirement associated with SR 3.8.1.18.b is to show that the emergency loading is not affected by the DG operation in test mode. In lieu of actual demonstration of connection and loading of loads, testing that adequately shows the capability of the emergency loads to perform these functions is acceptable. This testing may include any series of The Surveillance sequential, overlapping, or total steps so that the entire connection and Frequency is loading sequence is verified.
| |
| controlled uncier the Surveillance Frequency Control required to perform the Surveillance; and is intended to be consistent with Prograrn. expected fuel cycle lengths.
| |
| This SR has been modified by a Note. (The Note is not applicable to DG1 C) The reason for the Note is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems. Credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:
| |
| : 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and (continued)
| |
| RIVER BEND B 3.8-28 Revision No. 143
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.17 (continued)
| |
| REQUIREMENTS
| |
| : 2) Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.
| |
| SR 3.8.1.18 Under accident conditions, loads are sequentially connected to the bus by the load sequencing logic. The sequencing logic controls the permissive and starting signals to motor breakers to prevent overloading of the bus power supply due to high motor starting currents. ,The 10% load sequence time tolerance ensures that sufficient time exists for the bus power supply to restore frequency and voltage prior to applying the next load and that safety analysis assumptions regarding ESF equipment time delays are not violated. (Note that this surveillance requirement pert~ins only to the load sequence timer itself, and not to the interposing logic The S,Jrveillance . which comprises the remainder of the circuit.) Reference 2 provides a Frequency is . summary of the automatic loading of ESF buses.
| |
| control!ed under tile Surveiliance Frequency c:ontrol required to perform the Surveillance; and is intended to be consistent with Program. expected fuel cycle lengths.
| |
| This SR is modified by a Note. (The Note is not applicable to DG1C) The reason for the Note is that performing the Surveillance during these MODES would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge plant safety systems. Credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:
| |
| : 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and (continued)
| |
| RIVER BEND B 3.8-29 Revision No. 143
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.18 (continued)
| |
| REQUIREMENTS
| |
| : 2) Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.
| |
| SR 3.8.1.19 In the event of a OBA coincident with a loss of offsite power, the DGs are required to supply the necessary power to ESF systems so that the fuel, RCS, and containment design limits are not exceeded.
| |
| This Surveillance demonstrates the DG operation, as discussed in the Bases for SR 3.8.1.12, during a loss of offsite power actuation test signal in conjunction with an ECCS initiation signal. In lieu of actual demonstration of connection and loading of loads, testing that adequately shows the capability of the DG system to perform these functions is acceptable. This testing may include any series of sequential, The Surveillance overlapping, or total steps so that the entire connection and loading Frequency is sequence is verified.
| |
| controlled under the Surveiliance The Frequency of 24 months takes into consideration plant conditions Frequency Control required to perform the Surveillance and is intended to be consistent 'Nith Program, an expected fuel cycle length of 24 months.
| |
| This SR is modified by two Notes. (Note 2 is not applicable to DG 1C)
| |
| The reason for Note 1 is to minimize wear and tear on the DGs during testing. For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine coolant and oil being continuously circulated and temperature maintained consistent with manufacturer recommendations for DG 1A and DG 1 B. For DG 1C, standby conditions mean that the lube oil is heated by the jacket water and continuously circulated through a portion of the system as recommended by the vendor. Engine jacket water is heated by an immersion heater and circulates through the system by natural circulation.
| |
| The reason for Note 2 is that performing the Surveillance would remove a required offsite circuit from (continued)
| |
| RIVER BEND B 3.8-30 Revision No. 143
| |
| | |
| AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.19 (continued)
| |
| REQUIREMENTS service, perturb the electrical distribution system, and challenge plant safety systems. Credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:
| |
| : 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and
| |
| : 2) Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.
| |
| SR 3.8.1.20 This Surveillance demonstrates that the DG starting independence has not been compromised. Also, this Surveillance demonstrates that each Tf1e Surveillance engine can achieve proper speed within the specified time when the DGs Frequency is are started simultaneously.
| |
| C'Jntroiied under the Sun;eillance The 1O year Frequency is consistent with the recommendations of Frequency Control Regulatory Guide 1.108 (Ref. 9).
| |
| Program.
| |
| This SR is modified by a Note. The reason for the Note is to minimize wear on the DG during testing. For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine coolant and oil continuously circulated and temperature maintained consistent with manufacturer recommendations for DG 1A and DG 1 B. For DG 1C, standby conditions mean that the lube oil is heated by the jacket water and continuously circulated through a portion of the system as
| |
| * recommended by the vendor. Engine jacket water is heated by an immersion heater and circulates through the system by natural circulation.
| |
| (continued)
| |
| (continued)
| |
| RIVER BEND B 3.8-31 Revision No. 102
| |
| | |
| AC Sources - Operating B 3.8.1 BASES REFERENCES 1. 10 CFR 50, Appendix A, GDC 17.
| |
| : 2. USAR, Chapter 8.
| |
| : 3. Regulatory Guide 1.9.
| |
| : 4. USAR, Chapter 6.
| |
| : 5. USAR, Chapter 15.
| |
| : 6. Regulatory Guide 1.93.
| |
| : 7. Generic Letter 84-15, July 2, 1984.
| |
| : 8. 10 CFR 50, Appendix A, GDC 18.
| |
| : 9. Regulatory Guide 1.108.
| |
| : 10. Regulatory Guide 1.137.
| |
| : 11. ANSI C84.1, 1982.
| |
| : 12. ASME, Boiler and Pressure Vessel Code, Section XI.
| |
| : 13. IEEE Standard 308.
| |
| : 14. 1O cr=R 50.65.
| |
| : 15. Regulatory Guide 1.160.
| |
| 4e14. NEDC-32988, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected End States for BWR Plants, December 2002 (continued)
| |
| RIVER BEND B 3.8-32 .Revision No. 161
| |
| | |
| AC Sources Operating B 3.8.1 BASES PAGE INTENTIONALLY LEFT BLANK RIVER BEND B 3.8-33 Revision No. 3-1
| |
| | |
| Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES ACTIONS E.1 (continued)
| |
| With a Required Action and associated Completion Time not met, or the stored diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than addressed by Conditions A through D, the associated DG may be incapable of performing its intended function and must be immediately declared inoperable.
| |
| SURVEILLANCE SR 3.8.3.1 REQUIREMENTS This SR provides verification that there is an adequate inventory of fuel oil in the storage tanks to support each DG's operation for 7 days at maximum expected post LOCA loading. The 7 day period is sufficient time to place the unit in a safe shutdown condition and to bring in replenishment fuel from an offsite location.
| |
| The 31 day Frequency is adequate to ensure that a sufficient supply of fuel oil is available, since 101.v level alarms are provided and unit operators would be aware of any large uses of fuel oil during this period.
| |
| The Surveillance SR 3.8.3.2 Frequency is controlled under the This Surveillance ensures that sufficient lube oil inventory is available to Surveillance support at least 7 days of maximum expected post LOCA load operation Frequency Control for each DG. This requirement is based on the DG manufacturer's Program. consumption values for the run time of the DG. Implicit in this SR is the requirement to verify the capability to transfer the lube oil from its storage location to the DG when the DG lube oil sump does not hold adequate inventory for 7 days of maximum expected post LOCA load operation without the level reaching the manufacturer's recommended minimum level. Note, the LCO for diesel generators I, II, and Ill lube oil inventory is based on volumes in the sump while the particular diesel is running and does not include the volume that would drain back to the sump in standby conditions.
| |
| A 31 day Frequency is adequate to ensure that a sufficient lube oil supply is onsite, since DG starts and run times are closely monitored by the plant staff:.
| |
| (continued)
| |
| RIVER BEND B 3.8-45 Revision No. 155
| |
| | |
| Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE SR 3.8.3.3 (continued)
| |
| REQUIREMENTS The Frequency of these Surveillances on the stored fuel oil takes into consideration fuel oil degradation trends indicating that overall fuel oil quality is unlikely to change between Frequency intervals.
| |
| SR 3.8.3.4 This Surveillance ensures that, without the aid of the refill compressor, sufficient air start capacity for each DG is available. For DG 1A and 1B, each starting air system is sized to have the capacity for at least one emergency DG start attempt above the air pressure interlock, and multiple manual start attempts below the interlock, without recharging its start receiver(s). For DG 1C, the starting air system is sized to have the capacity for at least five successive start attempts without recharging its air start receiver(s). For each DG, either the forward or rear air start subsystem has the capacity to satisfy these multiple start requirements.
| |
| The pressure specified in this SR reflects the value at which this can be The Surveillance accomplished, but is not so high as to result in failing the limit due to Frequency is normal cycling of the recharge compressor.
| |
| control!ecl under the Sur-vei!lsnce The 31 day Frequency takes into account the capacity, capability, Frequency Control redundancy, and diversity of the AC sources and other indications Program. available in the control room, including alarms, to alert the operator to below normal air start pressure.
| |
| SR 3.8.3.5 Microbiological fouling is a major cause of fuel oil degradation. There are numerous bacteria that can grow in fuel oil and cause fouling, but all must have a water environment in order to survive. Periodic Removal removal of water from the storage tanks once every 31 days eliminates the necessary environment for bacterial survival. This is the most effective means of controlling microbiological fouling. In addition, it eliminates the potential for water entrainment in the fuel oil during DG operation. Water may come from any of several sources, including condensation, ground water, rain water, contaminated fuel oil, and from breakdown (continued)
| |
| RIVER BEND B 3.8-48 Revision No. 3-2
| |
| | |
| Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE SR 3.8.3.5 (continued)
| |
| REQUIREMENTS of the fuel oil by bacteria. Frequent checking for and removal of The Surveillance r\ accumulated water minimizes fouling and provides data regarding the Frequency is I \ watertight integrity of the fuel oil system. The Surveillance frequencies controlled under the are established by Regulatory Guide 1.137 (Ref. 2). This SR is for Surveillance preventive maintenance. The presence of water does not necessarily Frequency Control represent a failure of this SR provided that accumulated water is removed Program. during performance of the Surveillance.
| |
| REFERENCES 1. USAR, Section 9.5.4.
| |
| : 2. Regulatory Guide 1.137.
| |
| : 3. ANSI N195, Appendix B, 1976.
| |
| : 4. USAR, Chapter 6.
| |
| : 5. USAR, Chapter 15.
| |
| : 6. ASTM Standards: 04057-81; 0975-81; 04176-82; 01522-79; 02622-82; 02276-78.
| |
| : 7. ASME, Boiler and Pressure Vessel Code, Section XI.
| |
| RIVER BEND B 3.8-49 Revision No. 134
| |
| | |
| DC Sources - Operating B 3.8.4 BASES SI IRVEll 1 4NCF SR 3 8 4 1 SURVEILLANCE REQUIREMENTS SR 3.8.4.1 Verifying battery terminal voltage while on float charge helps to ensure the effectiveness of the charging system and the ability of the batteries to perform their intended function. Float charge is the condition in which the charger is supplying the continuous charge required to overcome the internal losses of a battery (or battery cell) and maintain the battery (or battery cell) in a fully charged state. The voltage requirements are based on the nominal design voltage of the battery and are consistent with the initial voltages assumed in the battery sizing calculations. The 7 day Frequency is conservative vvith manufacturer's recommendations and IEEE 450 (Ref. 8).
| |
| The Surveil!ance SR 3.8.4.2 Frequency is controlled under the Visual inspection to detect corrosion of the battery cells and connections, Su,vei!iance or measurement of the resistance of each inter-cell, inter-rack, inter-tier, Frequency Contra! and terminal connection, provides an indication of physical damage or Program. abnormal deterioration that could potentially degrade battery performance.
| |
| Only those terminals and connectors which have visible corrosion must be measured for connection resistance.
| |
| conditions that can cause po1.ver losses due to resistance heating, is 92 days. This Frequency is considered acceptable based on operating experience related to detecting corrosion trends.
| |
| SR 3.8.4.3 Visual inspection of the battery cells, cell plates, and battery racks provides an indication of physical damage or abnormal deterioration that could potentially degrade battery performance.
| |
| (continued)
| |
| RIVER BEND B 3.8-54 Revision No. 161
| |
| | |
| DC Sources - Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.3 (continued)
| |
| REQUIREMENTS The 24 month Frequency of the Surveillance is based on engineering judgement, taking into consideration the desired unit conditions to perform SR 3.8.4.4 and SR 3.8.4.5 The Surveillance Frequency is Visual inspection and resistance measurements of inter-cell, inter-rack, contro!iecl under the inter-tier, and terminal connections provides an indication of physical Surveillance damage or abnormal deterioration that could indicate degraded battery Frequency Control condition. The anti-corrosion material is used to ensure good electrical Program. connections and to reduce terminal deterioration. The visual inspection for corrosion is not intended to require removal of and inspection under each terminal connection.
| |
| The removal of visible corrosion is a preventive maintenance SR. The presence of visible corrosion does not necessarily represent a failure of this SR, provided visible corrosion is removed during performance of this Surveillance.
| |
| The 24 month Frequency of the Surveillance is based on engineering judgement, taking into consideration the desired unit conditions to perform the Surveillance.
| |
| SR 3.8.4.6 Battery charger capability requirements are based on the design capacity of the chargers (Ref. 4). According to Regulatory Guide 1.32 (Ref. 9), the battery charger supply is required to be based on the largest combined demands of the various steady state loads and the charging capacity to restore the battery from the design minimum charge state to (continued)
| |
| RIVER BEND B 3.8-55 Revision No. 143
| |
| | |
| DC Sources - Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.6 (continued)
| |
| REQUIREMENTS the fully charged state, irrespective of the status of the unit during these demand occurrences. The minimum required amperes and duration ensure that these requirements can be satisfied. Momentary transients that are not attributable to charger performance do not invalidate this test.
| |
| The Surveillance Frequency is acceptable, given the unit conditions
| |
| * required to perform the test and the other administrative controls existing to ensure adequate charger performance during these 24 month intervals.
| |
| In addition, this Frequency is intended to be consistent 1uith expected fuel cycle lengths.
| |
| SR 3.8.4.7 A battery service test is a special test of the battery's capability, as found, to satisfy the design requirements (battery duty cycle) of the DC electrical power system. The discharge rate and test length correspond to the design duty cycle requirements as specified in Reference 4.
| |
| This SR is modified by two Notes. Note 1 allows the once per 60 months performance of SR 3.8.4.8 in lieu of SR 3.8.4.7. This substitution is acceptable because the battery performance test (SR 3.8.4.8) represents a more severe test of battery capacity than the battery service test (SR 3.8.4.7). Because both the battery service test and the battery performance test involve battery capacity determination, complete battery replacement invalidates the previous performance of these surveillance requirements. In addition to requiring the re-performance of both of these I surveillance tests prior to declaring the battery OPERABLE, complete battery replacement also resets the 60 month time period used for substitution of the service test by the performance test. For this reason, substitution is acceptable for performance testing conducted within the first two years of service of a new battery as required by Reference 8.
| |
| The reason for Note 2 is that performing the Surveillance would remove a
| |
| * required DC electrical power subsystem from service, perturb the electrical distribution system, and challenge safety systems. The Division Ill test may be performed in Mode 1, 2, or 3 in conjunction with HPCS system outages. Credit may be taken for unplanned events that satisfy the Surveillance. Examples of unplanned events may include: .
| |
| : 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and (continued)
| |
| RIVER BEND B 3.8-56 Revision No. 143
| |
| | |
| DC Sources - Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.7 (continued)
| |
| REQUIREMENTS
| |
| : 2) Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in .
| |
| conjunction with maintenance required to maintain OPERABILITY or reliability.
| |
| SR 3.8.4.8 A battery performance test is a test of constant current capacity of a battery, normally done in the as found condition, after having been in service, to detect any change in the capacity determined by the acceptance test. The test is intended to determine overall battery degradation due to age and usage.
| |
| The acceptance criteria for this Surveillance is consistent with IEEE-450 (Ref. 8) and IEEE-485 (Ref. 11). These references recommend that the battery be replaced if its capacity is below 80% of the manufacturer's rating. A capacity of 80% shows that the battery rate of deterioration is increasing, even if there is ample capacity to meet the load requirements.
| |
| The Surveillance Frequency for this test is normally 60 months. If the battery shows degradation, or if the battery has reached 85% of its expected life the Surveillance Frequency is reduced to 18 months.
| |
| Degradation is indicated, according to IEEE-450 (Ref. 8), when the battery capacity drops by more than 10% of rated capacity relative to its capacity on the previous performance test, or when it is ~ 10% below the manufacturer's rating. These Frequencies are based on the recommendations in IEEE-450 (Ref. 8).
| |
| This SR is modified by a Note. The reason for the Note is that performing the Surveillance would remove a required DC electrical power subsystem from service, perturb the electrical distribution system, and challenge safety systems. The Division Ill test may be performed in Mode 1, 2, or 3 in conjunction with HPCS system outages. Credit may be taken for unplanned events that satisfy the Surveillance. Examples of unplanned events may include:
| |
| (continued)
| |
| RIVER BEND B 3.8-57 Revision No. 120
| |
| | |
| Battery Cell Parameters B 3.8.6 BASES ACTIONS A.1, A.2, and A.3 (continued)
| |
| Continued operation is only permitted for 31 days before battery cell parameters must be restored to within Category A and B limits. Taking into consideration that while battery capacity is degraded, sufficient capacity exists to perform the intended function and to allow time to fully restore the battery cell parameters to normal limits, this time is acceptable for operation prior to declaring the DC batteries inoperable.
| |
| When any battery parameter is outside the Category C limit for any connected cell, sufficient capacity to supply the maximum expected load requirement is not assured and the corresponding DC electrical power subsystem must be declared inoperable. Additionally, other potentially extreme conditions, such as not completing the Required Actions of Condition A within the required Completion Time or average electrolyte temperature of representative cells falling below 60° F, also are cause for immediately declaring the associated DC electrical power subsystem inoperable.
| |
| SURVEILLANCE SR 3.8.6.1 REQUIREMENTS The SR verifies that Category A battery cell parameters are consistent with IEEE-450 (Ref. 3), which recommends regular battery inspections including float voltage, specific gravity, and electrolyte level of pilot cells.
| |
| The 7 day Frequency ensures that these inspections are performed within the frequency recommended by IEEE 450 (Ref. 3).
| |
| SR 3.8.6.2 The quarterly inspection of specific gravity and voltage is consistent with IEEE-450 Ref. 3 7 In addition, within 72 hours of a battery overcharge
| |
| . > 144 V, the battery must be demonstrated to meet Category B limits.
| |
| This inspection is also consistent with IEEE-450 (Ref. 3), which recommends special inspections following a severe overcharge, to ensure that no significant degradation of the battery occurs as a consequence of such overcharge. '
| |
| (continued)
| |
| RIVER BEND B 3.8-65 Revision No. 0
| |
| | |
| Battery Cell Parameters B 3.8.6 BASES SURVEILLANCE SR 3.8.6.3 REQUIREMENTS (continued) This Surveillance verification that the av~rage temperature of representative (at least one out ofI six connected) cells is ~ 60°F is consistent with a recommendation of IEEE-450 (Ref. 3), which states that the temperature of electrolytes in representative cells should be determined on a quarterly basis.
| |
| Lower than normal temperatures act to inhibit or reduce battery capacity.
| |
| This SR ensures that the operating t~mperatures remain within an acceptable operating range. This limit is based on manufacturer's recommendations.
| |
| The Surveillance Table 3.8.6-1 Frequency is controlled the This table delineates the limits on electrolyte level, float voltage, and Surveiiiance specific gravity for three different categories. The meaning of each Frequency category is discussed below.
| |
| Category A defines the normal parameter limit for each designated pilot cell in each battery. The cells selected as pilot cells are those whose corrected electrolyte specific gravity approximate the state of charge of the entire battery.
| |
| The Category A limits specified for electrolyte level are based on manufacturer's recommendations and are consistent with the guidance in IEEE-450 (Ref. 3), with the extra.1/4 inch allowance above the high water level indication for operating margin to account for temperature and charge effects. In addition to this allowance, footnote a to Table 3.8.6-1 permits the electrolyte level to be above the specified maximum level during equalizing charge, provided (continued)
| |
| RIVER BEND B 3.8-66 Revision No. 1
| |
| | |
| Inverters - Operating B 3.8.7 SURVEILLANCE SR 3.8.7.1 REQUIREMENTS This Surveillance verifies that the inverters are functioning properly with all required circuit breakers closed and AC vital buses energized from the inverter. The verification of proper voltage and frequency output ensures that the required power is readily available for the instrumentation connected to the AC vital buses. The 7 day Frequency takes into account the redundant capability of the inverters and other indications available in the control room that alert the operator to inverter malfunctions.
| |
| (continued)
| |
| The Surveillance Frequency is controlied underithe Survei!!ance Frequency Controi Program.
| |
| RIVER BEND B 3.8-72a Revision No. 161
| |
| | |
| Inverters - Shutdown B 3.8.8 BASES SURVEILLANCE SR 3.8.8.1 (continued)
| |
| REQUIREMENTS closed and AC vital buses energized from the inverter. The verification of proper voltage and frequency output ensures that the required power is readily available for the instrumentation connected to the AC vital buses.
| |
| The 7 day Frequency takes into account the redundant capability of the inverters and other indications available in the control room that alert the operator to inverter malfunctions.
| |
| REFERENCES 1. USAR, Chapter 6:
| |
| : 2. USAR, Chapter 15.
| |
| RIVER BEND B 3.8-77 Revision No. O
| |
| | |
| Distribution Systems-Operating B 3.8.9 "
| |
| BASES ACTIONS With the Division Ill electrical power distribution system inoperable, the Division Ill powered systems are not capable of performing their intended functions. Immediately declaring the high pressure core spray inoperable allows the ACTIONS of LCO 3.5.1, "ECCS - Operating," to apply appropriate limitations on continued reactor operation.
| |
| F.1 Condition F corresponds to a level of degradation in the electrical
| |
| - distribution system that causes a required safety function to be lost.
| |
| When more than one Condition is entered, and this results in the loss of a required function, the plant is in a condition outside the accident analysis.
| |
| Therefore, no additional time is justified for continued operation. LCO 3.0.3 must be entered immediately to commence a controlled shutdown.
| |
| SURVEILLANCE SR 3.8.9.1 REQUIREMENTS Meeting this Surveillance verifies that the AC, DC, and AC vital bus electrical power distribution systems are functioning properly, with the correct circuit breaker alignment. The correct breaker alignment ensures the appropriate separation and independence of the electrical divisions is maintained, and the appropriate voltage is available to each required bus.
| |
| The verification of proper voltage availability on the buses ensures that the required voltage is readily available for motive as well as control Frequency is functions for critical 'system loads connected to these buses. The 7 day Frequency takes into account the redundant papability of the AC, DC, and AC vital bus electrical pov,er distribution subsystems, and other indications available in the control room that alert the operator to subsystem malfunctions.
| |
| (continued)
| |
| RIVER BEND B 3.8-86 Revision No. 161
| |
| | |
| Distribution Systems-Shutdown B 3.8.10 BASES ACTIONS A.1, A.2.1, A.2.2, A.2.3, A.2.4, and A.2.5 (continued)
| |
| The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. The restoration of the required distribution subsystems should be completed as quickly as possible in order to minimize the time the plant safety systems may be without power.
| |
| SURVEILLANCE SR 3.8.10.1 REQUIREMENTS This Surveillance verifies that the required AC, DC, and AC vital bus electrical power distribution subsystems are functioning properly, with the buses energized. The verification of proper voltage availability on the required buses ensures that the required power is readily available for The Surveillance Frequency is I\ ~otive as well as control functions for critical system loads connected to
| |
| [ \these buses. The 7 day Frequency takes into account the redundant controlled under the capability of the electrical power distribution subsystems, as well as other Surveillance indications available in the control room that alert the operator to Frequency Control subsystem malfunctions.
| |
| Program.
| |
| REFERENCES 1. USAR, Chapter 6.
| |
| : 2. USAR, Chapter 15.
| |
| /
| |
| \
| |
| RIVER BEND B 3.8-92 Revision No. 0
| |
| | |
| Refueling Equipment Interlocks B 3.9.1 BASES ACTIONS to allow control rods to be withdrawn in accordance with LCO 3.10.6 while (continued) complying with these actions. This verification that all required control rods are fully inserted is in addition to the periodic verifications required by SR 3.9.3.1 and SR 3.10.6.2. Like Required Action A.1, Required Actions A.2.1 and A.2.2 ensure that unacceptable operations are blocked (e.g.,
| |
| loading fuel into a cell with the control rod withdrawn.)
| |
| The alternative option (Required Actions A.2.1 and A.2.2) also allows fuel movement to continue rather than halting refueling activities to perform SR 3.9.1.1 should it become due before completion of fuel movement activities. This option should not be used to eliminate the first performance of the SR before starting in-vessel fuel movements. The objective of the option is to provide flexibility under limited circumstances, not to disable the refueling interlocks indefinitely and is only allowed for a period not to exceed 31 days, after which time the performance of the SR 3.9.1.1 would be required.
| |
| SURVEILLANCE SR 3.9.1.1 REQUIREMENTS Performance of a CHANNEL FUNCTIONAL TEST demonstrates each required refueling equipment interlock will function properly when a simulated or actual signal indicative of a required condition is injected into the logic. The CHANNEL FUNCTIONAL TEST may be performed by any series of sequential, overlapping, or total channel steps so that the entire The Surveil!ance channel is tested.
| |
| Frequency is The 7 day Frequency is based on engineering judgment and is considered controlled the adequate in view of other indications of refueling interlocks and their Surveillance assoeiated input status that are available to unit operations personnel.
| |
| Frequency Control Program. Should this SR become due before completion of fuel movement
| |
| *activities, f,uel movement may continue rather than halting refueling activities to perform the SR provided that required Actions A.2.1 and A.2.2 are met. As discussed above, this option should not be used to eliminate the first performance of the SR before starting in-vessel fuel movements and is only allowed for a period not to exceed 31 days, after which time the performance of the SR 3.9.1.1 would be required.
| |
| REFERENCES 1. 10 CFR 50, Appendix A, GDC 26.
| |
| : 2. USAR, Section 7.7.1.5.
| |
| : 3. USAR, Section 15.4.1.1.
| |
| RIVER BEND B 3.9-4. Revision No. 119
| |
| | |
| Refueling Position One-Rod-Out Interlock B 3.9.2 BASES ACTIONS A.1 and A.2 (continued) fuel assemblies. Action must continue until all such control rods are fully inserted. Control rods in core cells containing no fuel assemblies do not affect the reactivity of the core and, therefore, do not have to be inserted.
| |
| SURVEILLANCE SR 3.9.2.1 REQUIREMENTS Proper functioning of the refuel position one-rod-out interlock requires the reactor mode switch to be in refuel. During control rod withdrawal in MODE 5, improper positioning of the reactor mode switch could, in some instances, allow improper bypassing of required interlocks. Therefore, this Surveillance imposes an additional level of assurance that the refuel position one-rod-out interlock will be OPERABLE when required. By "locking" the reactor mode switch in the proper position (i.e., removing the reactor mode switch key from the console while the reactor mode switch is positioned in refuel), an additional administrative control is in place to The Surveillance preclude operator errors from resulting in unanalyzed opera!ion.
| |
| Frequency is controlled the Surveillance Frequency Control Program. SR 3.9.2.2 Performance of a CHANNEL FUNCTIONAL TEST on each channel demonstrates the associated refuel position one-rod-out interlock will function properly when a simulated or actual signal indicative of a required condition is injected into* the logic. Th_l:l CHANNEL FUNCTIONAL TEST may be performed by any series of sequential, overlapping, or total channel steps so that the entire channel is tested. The 7 day Frequency is considered adequate because of demonstrated circuit reliability, procedural controls on control rod i.vithdrawals, and indications available in the control room to alert the operator of control rods not fully inserted.
| |
| To perform the required testing, the applicable condition must be entered (i.e., a control rod must be withdrawn from its full-in position). Therefore, this SR has been modified .
| |
| (continued)
| |
| RIVER BEND B 3.9-7 Revision No. O
| |
| | |
| Control Rod Position B 3.9.3 BASES SURVEILLANCE SR 3.9.3.1 (continued)
| |
| REQUIREMENTS The 12 hour Frequency takes into consideration the procedural controls functions of the refueling interlocks.
| |
| * f on control rod movement during refueling as well as the redundant REFERENCES 1. 10 CFR 50, Appendix A, GDC 26./
| |
| : 2. USAR Section 15.4.1.1.
| |
| r--T-hA-~-S-u-rv-e-iil_a_nr-ve---,r----------------'/
| |
| Frequency is controi!ecl under the Surveillance Frequency Control Program.
| |
| RIVER BEND B 3.9-11 Revision No. O
| |
| | |
| Control Rod OPERABILITY - Refueling B 3.9.5 BASES SURVEILLANCE SR 3.9.5.1 and SR 3.9.5.2 (continued)
| |
| REQUIREMENTS The Surveillance Frequencies are controlled uncler the SR 3.9.5.1 is modified by a Note that allows 7 days after withdrawal of the Surveillance control rod to perform the Surveillance. This acknowledges that the Frequency Control control rod must first be withdrawn before performance of the Surveillance Pro(Jram. and therefore avoids potential conflicts with SR 3.0.3 and SR 3.0.4.
| |
| REFERENCES 1. 10 CFR 50, Appendix A, GDC 26.
| |
| : 2. USAR, Section 15.4.1.1.
| |
| RIVER BEND B 3.9-18 Revision No. O
| |
| | |
| RPV Water Level-Irradiated Fuel B 3.9.6 BASES SURVEILLANCE SR 3.9.6.1 (continued)
| |
| REQUIREMENTS The Frequency of 24 hours is based on engineering judgment and is considered adequate in viev>' of the large volume of *Nater and the normal procedural controls on valve positions, 1Nhich make significant unplanned level changes unlikely. f REFERENCES .1. Regulatory Guide 1.183 .
| |
| : 2. USAR, Section 15.7.4.
| |
| : 3. NUREG-0800, Section 15.7.4.
| |
| : 4. 10 CFR 50.67.
| |
| The Surveillance Frequency is controiled under the Surveiilance Frequency Control Program.
| |
| RIVER BEND B 3.9-21 Revision No. 115
| |
| | |
| RPV Water Level- New Fuel or Control Rods B 3.9.7 BASES SURVEILLANCE SR 3.9.7.1 (continued)
| |
| REQUIREMENTS operations is met. Water at the required level limits the consequences of The Surveillance \ ~amaged fuel rods, which are postulated to result from a fuel handling Frequency is \accident in containment (Ref. 2). _
| |
| controlled under the The Frequency of 24 hours is based on engineering judgment and is Surveillance considered adequate in view of the large volume of 'Nater and the normal Frequency Control procedural controls on valve positions, which make significant unplanned Program. level changes unlikely.
| |
| REFERENCES 1. Regulatory Guide 1.183.
| |
| : 2. USAR, Section 15.7.4.
| |
| : 3. NUREG-0800, Section 15.7.4.
| |
| : 4. 10 CFR 50.67.
| |
| RIVER BEND B 3.9-24 Revision No. 115
| |
| | |
| RHR-High Water Level B 3.9.8 BASES SURVEILLANCE SR 3.9.8.1 REQUIREMENTS The Surveillance SR 3.9.8.2 Frequency ls controlled under the RHR Shutdown Cooling System piping and components have the Surveillance potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper Frequency Control operation of the required RHR shutdown cooling subsystem(s) and may Program. also prevent water hammer, pump cavitation, and pumping of noncondensible gas into the reactor vessel.
| |
| Selection of RHR Shutdown Cooling System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration.
| |
| Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions.
| |
| The RHR Shutdown Cooling System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible location exceeds and acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent ev?luation that the RHR Shutdown Cooling System is not
| |
| * rendered inoperable by the accumulated gas (i.e., the system is sufficiently filled with water), the Surveillance may be declared met.
| |
| Accumulated gas should be eliminated or brought within the acceptance criteria limits.
| |
| RHR Shutdown Cooling System locations susceptible to gas accumulation are monitored and, if gas is found, the gas volume is compared to the acceptance criteria for the' location. Susceptible locations in the same system flow path which are subject to the same gas intrusion mechanisms may be verified by monitoring a representative sub-
| |
| / set'of susceptible locations. Monitoring may not be practical for locations that are inaccessible due to radiological or environmental conditions, the plant configuration, or personnel safety. For these locations alternative (continued)
| |
| RIVER BEND B 3.9-28a Revision No. 163
| |
| | |
| RHR-High Water Level B 3.9.8 BASES SURVEILLANCE SR 3.9.8.2 (continued)
| |
| REQUIREMENTS (continued) methods (e.g., operating parameters, remote monitoring) may be used to monitor the susceptible location. Monitoring is not required for susceptible locations where the maximum potential accumulated gas void volume has been evaluated and determined to not challenge system OPERABILITY. The accuracy of the method used for monitoring the susceptible locations and trend of the results should be sufficient to assure system OPERABILITY during the Surveillance interval.
| |
| The 31 day Frequency takes into consideration the gradual nature of gasaccumulation in the RHR Shutdovm Cooling System piping and theprocedural controls governing system operation.
| |
| f REFERENCES None. /
| |
| .---T-h_e_S_L_Jr-ve--i-i!a_n_r_,e_~t--------~/
| |
| Frequency is controlleci the Surveiilance Frequency Control Program. The Surveillance Frequency may va1y by location susceptible to Qas accumulation.
| |
| RIVER BEND B 3.9-28b Revision No. 163
| |
| | |
| RHR - Low Water Level B 3.9.9 BASES ACTIONS C.1 and C.2 (continued) out of service, and normal decay heat removal systems are lost or intentionally turned off, especially during periods of high decay heat load.
| |
| SURVEILLANCE SR 3.9.9.1 REQUIREMENTS Tile Surveillance SR 3.9.9.2 Frequency is controlled under the RHR Shutdown Cooling System piping and components have the Survei!iance potential to develop voids and pockets of entrained gases. Preventing and managing gas intrusion and accumulation is necessary for proper Frequen'cy Control operation of the RHR shutdown cooling subsystems and may also Program. prevent water hammer, pump cavitation, and pumping of noncondensible gas into the reactor vessel.
| |
| Selection of RHR Shutdown Cooling System locations susceptible to gas accumulation is based on a review of system design information, including piping and instrumentation drawings, isometric drawings, plan and elevation drawings, and calculations. The design review is supplemented by system walk downs to validate the system high points and to confirm the location and orientation of important components that can become sources of gas or could otherwise cause gas to be trapped or difficult to remove during system maintenance or restoration.
| |
| Susceptible locations depend on plant and system configuration, such as stand-by versus operating conditions.
| |
| The RHR Shutdown Cooling System is OPERABLE when it is sufficiently filled with water. Acceptance criteria are established for the volume of accumulated gas at susceptible locations. If accumulated gas is discovered that exceeds the acceptance criteria for the susceptible location (or the volume of accumulated gas at one or more susceptible location exceeds and acceptance criteria for gas volume at the suction or discharge of a pump), the Surveillance is not met. If it is determined by subsequent evaluation that the RHR Shutdown Cooling System is not rendered inoperable by the accumulated gas (i.e., the system is sufficiently filled with water), the Surveillance may be declared met.
| |
| Accumulated gas should be eliminated or brought within the acceptance criteria limits.
| |
| RHR Shutdown Cooling System locations susceptible to gas accumulation are monitored and, if gas is found, the gas volume is compared to the acceptance criteria for the location. Susceptible (continued)
| |
| RIVER BEND B 3.9-32a Revision No. 163
| |
| | |
| RHR - Low Water Level B 3.9.9 BASES SURVEILLANCE SR 3.9.9.2 (continued)
| |
| REQUIREMENTS (continued) locations in the same system flow path which are subject to the same gas intrusion mechanisms may be verified by monitoring a representative sub-set of susceptible locations. Monitoring may not be practical for locations that are inaccessible due to radiological or environmental conditions, the plant configuration, or personnel safety. For these locations alternative methods (e.g., operating parameters, remote monitoring) may be used to monitor the susceptible location. Monitoring is not required for susceptible locations where the maximum potential accumulated gas void volume has been evaluated and determined to not challenge system OPERABILITY. The accuracy of the method used for monitoring the susceptible locations and trending of the results should be sufficient to assure system OPERABILITY during the Surveillance interval.
| |
| The 31 day Frequency takes into consideration the gradual nature of gas accumulation in the RHR Shutdown Cooling System piping and the procedural controls governing system operation.
| |
| . t .
| |
| REFERENCES None. /
| |
| .--_r_h_e_s-**L-1r-ve-..:l-i!a-r-1c-*e---.i--------~/
| |
| Frequency is controlled under the
| |
| .Surveillance Freqi.iency Control Prograrn. The Surveillance Frequency may vary by location susceptible to gas accumulation.
| |
| RIVER BEND B 3.9-32b Revision No. 163
| |
| | |
| Reactor Mode Switch Interlock Testing B 3.10.2 BASES (continued)
| |
| ACTIONS A.1. A.2. A.3.1. and A.3.2 These Required Actions are provided to restore compliancewith the Technical Specifications overridden by this Special Operations LCO.
| |
| Restoring compliance will also result_ in exiting the Applicability of this Special Operations LCO. '
| |
| All CORE ALTERATIONS except control rod insertion, if in progress, are immediately suspended in accordance with Required Action A.1, and all insertable control rods in core cells that contain one or more fuel assemblies are fully inserted within 1 hour, in accordance with Required Action A.2. This will preclude potential mechanisms that could lead to criticality. Suspension of CORE ALTERATIONS shall not preclude the completion of movement of a component to a safe condition. Placing the reactor mode switch in the shutdown position will ensure that all inserted control rods remain inserted and result in operation in accordance with Table 1.1-1. Alternatively, if in MODE 5, the reactor mode switch may be placed in the refuel position, which will also result in operating in accordance with Table 1.1-1. A Note is added to Required Action A.3.2 to indicate that this Required Action is not applicable in MODES 3 and 4, since only the shutdown position is allowed in these MODES. The allowed Completion Time of 1 hour for Required Actions A.2, A.3.1, and A.3.2 provides sufficient time to normally insert the control rods and place the reactor mode switch in the required position, based on operating experience, and is acceptable given that all operations that could increase core reactivity have been suspended.
| |
| SURVEILLANCE SR 3.10.2.1 and SR 3.10.2.2 REQUIREMENTS Meeting the requirements of this Special Operations LCO maintains operation consistent with or conservative to operating with the reactor mode switch in the shutdown position (or the refuel position for MODE 5). The functions of the reactor mode switch interlocks that are not in effect, due to the testing in progress, are adequately compensated for by the Special Operations LCO requirements. The administrative controls are to be periodically verified to ensure that the operational requirements continue to be met. The Surveillances performed at the 12 hour and 24 hour f * (continued)
| |
| -------~ / (continued)
| |
| The Surveillance ~
| |
| Frequencies are controllecl under the Surveillance Frequenc\t Control Program.
| |
| RIVER BEND B 3.10-9 Revision No. O
| |
| | |
| Reactor Mode Switch Interlock Testing B 3.10.2 BASES (continued)
| |
| SURVEILLANCE SR 3.10.2.1 and SR 3.10.2.2 (continued)
| |
| REQUIREMENTS Frequencies are intended to provide appropriate assurance that each operating shift is aware of and verify compliance 1.Nith these Special Operations LCO requirements.
| |
| REFERENCES 1. USAR, Section 7.2.1.1.
| |
| : 2. USAR, Section 15.4.1.1.
| |
| RIVER BEND B 3.10-10 Revision No. O
| |
| | |
| Single Control Rod Withdrawal- Hot Shutdown B 3.10.3 BASES ACTIONS A.1 (continued).
| |
| of any other LCO's Required Action to insert all control rods. This Required Action includes exiting this Special Operations Applicability LCO by returning the reactor mode switch to the shutdown position. A second Note has been added, which cl~rifies that this Required Action is only applicable if the requirements not met are for an affected LCO.
| |
| A.2.1 and A.2.2 Required Actions A.2.1 and A.2.2 are alternative Required Actions that can be taken instead of Required Action A.1 to restore compliance with the normal MODE 3 requirements, thereby exiting this Special Operations LCO's Applicability. Actions must be initiated im*mediately to insert all insertable control rods. Actions must continue until all such control rods are fully inserted. Placing the reactor mode switch in the shutdown position will ensure that all inserted rods remain inserted and restore operation in accordance with Table 1.1-1. The allowed Completion Time of 1 hour to place the reactor 'mode switch in the shutdown position provides sufficient time to normally insert the control rods.
| |
| SURVEILLANCE SR 3.10.3.1, SR 3.10.3.2, and SR 3.10.3.3 REQUIREMENTS '
| |
| The other LCOs made applicable in this Special Operations LCO are required to have their Surveillances met to establish that this Special Operations LCO is being met. If the local array of control rods is inserted and disarmed while the scram function for the withdrawn rod .is not available, periodic verification in accordance with SR 3.10.3.2 is required to preclude the possibility of criticality. SR 3.10.3.2 has been modified by a Note, which clarifies that this SR is not required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.d.1 requirements, since SR 3.10.3.2 demonstrates that the alternative LCO 3.10.3.d.2 requirements are satisfied. Also, SR 3.10.3.3 verifies that all control rods other than the control rod being withdrawn are fully inserted. The 24 hour Frequency is acceptable because of the administrative1
| |
| _ (continued)
| |
| (continued)
| |
| The Surveillance 1.
| |
| Frequencies are under Surveillance Frequency Control Program.
| |
| RIVER BEND B 3.10-14 Revision No. O
| |
| )
| |
| | |
| Single Control Rod Withdrawal- Hot Shutdown B 3.10.3 BASES SURVEILLANCE SR 3.10.3.1, SR 3.10.3.2, and SR 3.10.3.3 REQUIREMENTS controls on control rod withdrawals, the protection afforded by the LCOs involved, and hardv.iare interlocks that preclude additional control rod withdra'Nals.
| |
| REFERENCES 1. USAR, Section 15.4.1.1.
| |
| )
| |
| RIVER BEND B3.10-15 Revision No. 0
| |
| | |
| Single Control Rod Withdrawal- Cold Shutdown B 3.10.4 BASES (continued)
| |
| SURVEILLANCE SR 3.10.4.1, SR 3.10.4.2, SR 3.10.4.3, and SR 3.10.4.4 REQUIREMENTS The other LCOs made applicable by this Special Operations LCO are required to have their associated Surveillances met to establish that this Special Operations LCO is being met. If the local array of control rods is inserted and disarmed while the scram function for the withdrawn rod is not available, periodic verification is required to ensure that the possibility of criticality remains precluded. Verification that all the other control rods are fully inserted is required to meet the SOM requirements. Verification that a control rod withdrawal block has been inserted ensures that no other control rods can be inadvertently withdrawn under conditions when position
| |
| ~indication instrumentation is inoperable for the affected control rod. Th-e-24 hour Frequency is acceptable because of the administrative controls on control rod withdrawals, the protection afforded by the LCOs involved, and hardware interlocks to preclude an additional control rod withdrawal.
| |
| SR 3.10.4.2 and SR 3.10.4.4 have been modified by Notes, which clarify that these SRs are not required to be met if the alternative requirements demonstrated by SR 3.10.4.1 are satisfied.
| |
| REFERENCES 1. USAR, Section 15.4.1.1.
| |
| RIVER BEND 83.10-20 Revision No. O
| |
| --- - __J
| |
| | |
| Single CRD Removal - Refueling B 3.10.5 BASES (continued)
| |
| ACTIONS A.1, A.2.1, and A.2.2 If one or more of the requirements of this Special Operations LCO are not met, the immediate implementation of these Required Actions restores operation consistent with the normal requirements for failure to meet LCO 3.3.1.1, LCO 3.3.8.2, LCO 3.9.1, LCO 3.9.2, LCO 3.9.4, and LCO 3.9.5 (i.e., all control rods inserted) or with the allowances of this Special Operations LCO. The Completion Times for Required Action A.1, Required Action A.2.1, and Required Action A.2.2 are intended to require these Required Actions be implemented in a very short time and carried through in an expeditious manner to either initiate action to restore the CRD and insert its control rod, or initiate action to restore compliance with this Special Operations LCO. Actions must continue until either Required Action A.2.1 or Required Action A.2.2 is satisfied.
| |
| * SURVEILLANCE SR 3.10.5.1, SR 3.10.5.2, SR 3.10.5.3, SR 3.10.5.4, and SR 3.10.5.5 REQUIREMENTS Verification that all the control rods, other than the control rod withdrawn for the removal of the associated CRD, are fully inserted is required to ensure the SOM is within limits. Verification that the local five by five array of control rods other than the control rod withdrawn for the removal of the associated CRD, is inserted and disarmed, while the scram function for the withdrawn rod is not available, is required to ensure that the possibility of criticality remains precluded. Verification that a control rod withdrawal block has been inserted ensures that no other control rods can be inadvertently withdrawn under conditions when position indication instrumentation is inoperable for the withdrawn control rod. The Su'rveillance for LCO 3.1.1, "SHUTDOWN MARGIN (SOM)," which is made applicable by this Special Operations LCO, is required in order to establish that this Special Operations LCO is being met. Verification that no other CORE ALTERATIONS are being made is required to ensure the assumptions of the safety analysis are satisfied.
| |
| Periodic verification of the administrative controls established by this Special Op~rations LCO is prudent to preclude the possibility of an inadvertent criticality. ::i:h-e (continued)
| |
| (continued)
| |
| The Surveillance Frequencies are controlled under the Surveillance *Control Program.
| |
| RIVER BEND B 3.10-24 Revision No. O
| |
| | |
| Single CRD Removal - Refueling B 3.10.5 BASES SURVEILLANCE SR 3.10.5.1, SR 3.10.5.2, SR 3.10.5.3, SR 3.10:5.4, and SR 3.10.5.5 REQUIREMENTS (continued) 24 hour Frequency is acceptable, given the administrative controls on control rod removal and hardware interlocks to block an additional control rod withdrai.val.
| |
| REFERENCES 1. USAR, Section 15.4.1.1.
| |
| RIVER BEND B 3.10-25 Revision No. O
| |
| | |
| Multiple Control Rod Withdrawal- Refueling B 3.10.6 BASES (continued)
| |
| APPLICABILITY Operation in MODE 5 is controlled by existing LCOs. The exceptions from other LCO requirements (e.g., the ACTIONS of LCO 3.9.3, LCO 3.9.4 or LCO 3.9.5) allowed by this Special Operations LCO are appropriately controlled by requiring all fuel to be removed from cells whose "full in" indicators are allowed to be bypassed.
| |
| ACTIONS A.1, A.2, A.3.1, and A.3.2 If one or more of the requirements of this Special Operations LCO are not met, the immediate implementation of these Required Actions commences activities which will restore operation consistent with the normal requirements for refueling (i.e., all control rods inserted in core cells containing one or more fuel assemblies) or with the exceptions granted by this Special Operations LCO. The Completion Times are intended to require that these Required Actions be implemented in a very short time and carried through in an expeditious manner.
| |
| SURVEILLANCE SR 3.10.6.1, SR 3.10.6.2, and SR 3.'10.6.3 REQUIREMENTS Periodic verification of the administrative controls established by this Special Operations LCO is prudent to preclude the possibility of an inadvertent criticality. The 24 hour Frequency is acceptable, given the administrative controls on fuel assembly and control rod removal, and takes into account other indications of control rod status available in the control room.
| |
| tI REFERENCES 1. USAR, Section 15.4.1.1.
| |
| The Surveiilance Frequencies are controlled under the Surveillance Frequency Control Program.
| |
| RIVER BEND B 3.10-28 Revision No. 0
| |
| | |
| SOM Test- Refueling B 3.10.8 BASES (continued)
| |
| SURVEILLANCE SR 3.10.8.1, SR 3.10.8.2 and SR 3.10.8.3 REQUIREMENTS The other LCOs made applicable in this Special Operations LCO are required to have applicable Surveillances met to establish that this Special Operations LCO is being met. However, the control rod withdrawal sequences during the SOM tests may be enforced by the RPC (LCO 3.3.2.1, Function 1b, MODE 2 requirements) or by a second licensed operator or other qualified member of the technical staff. As noted, either the applicable SRs for the RPC (LCO 3.3.2.1) must be satisfied according to the applicable Frequencies (SR 3.10.8.2), or the proper movement of control rods must be verified (SR 3.10.8.3). This latter verification (i.e., SR 3.10.8.3) must be performed during control rod movement to prevent deviations from the specified sequence. These.surveillances provide adequate assurance that the specified test sequence is being followed.
| |
| SR 3.10.8.4 Periodic verification of the administrative controls established by this LCO will ensure that the reactor is operated within the bounds of the safety analysis. The 12 hour Frequency is intended to provide appropriate assurance that each operating shift is avvare of and verifies compliance with these Special Operations LCO requirements.
| |
| SR 3.10.8.5 Coupling verification is performed to ensure the control rod is connected to the control rod drive mechanism and will perform its intended function when necessary. The verification is required to be performed any time a control rod is withdrawn to the "full out" notch position or prior to declaring the control rod OPERABLE after work on the control rod or CRD System that could affect coupling. This Frequency is acceptable, considering the low probability that a control rod will become uncoupled when it is not being moved as well as operating experience related to uncoupling events.
| |
| (continued)
| |
| RIVER BEND B 3.10-37 Revision No. 0
| |
| _J
| |
| | |
| SOM Test- Refueling B 3.10.8 BASES SURVEILLANCE SR 3.10.8.6 REQUIREMENTS (continued) CRD charging water header pressure verification is performed to ensure the motive force is available to scram the control rods in the event of a scram signal. A minimum accumulator pressure is specified, below which the The Surveillance capability of the accumulator to perform its intended function becomes Frequency is degraded and the accumulator is considered inoperable. The minimum controlled under the accumulator pressure of 1540 psig is well below the expected pressure of Surveillance 1750 psig. The 7 day Frequency has been sho'J'm to be acceptable through Frequency Control operating experience and takes into account indications available in the Program. control room.
| |
| REFERENCES 1. NEDE-24011-P-A, "General Electric Standard Application for Reactor Fuel, GESTAR 11" (latest approved revision).
| |
| : 2. Letter, T.A. Pickens (BWROG) to G.C. Lainas (NRC),
| |
| "Amendment 17 to General Electric Licensing Topical Report NEDE-24011-P-A," August 15, 1986.
| |
| RIVER BEND B 3.10-38 Revision No. 6-14
| |
| | |
| Attachment 6 RBG-47799 Proposed No Significant Hazards Consideration
| |
| _J
| |
| -Proposed No Significant Hazards Consideration RBG-47799 Page 1 of 2 Description of Amendment Request: The change requests the adoption of an approved change to the standard t,echnical specifications (STS) for General Electric Plants, BWR/6 (NUREG-1434), to allow relocation of specific TS surveillance frequencies to a licensee-controlled program. The proposed change is described in Technical Specification Task Force (TSTF) Traveler, TSTF--425, Revision 3 (Rev. 3) (ADAMS Accession No. ML090850642) related to the Relocation of Surveillance Frequencies to Licensee Control-RITSTF Initiative Sb and was described in the Notice of Availability published in the Federal Register on July 6, 2009 (74 FR 31996).
| |
| The proposed changes are consistent with NRG-approved Industry/Technical Specification Task Force (TSTF) Traveler, TSTF--425, Rev. 3, "Relocate Surveillance Frequencies to Licensee Control-RITSTF Initiative Sb." The proposed change relocates surveillance frequencies to a licensee-controlled program, the SFCP. This change is applicable to licensees using probabilistic risk guidelines contained in NRG-approved NEI 04-10, "Risk-Informed Technical Specifications Initiative Sb, Risk-Informed Method for Control of Surveillance Frequencies," (ADAMS Accession No. ML071360456).
| |
| Basis for proposed no significant hazards consideration: As required by 10 CFR 50.91 (a),
| |
| the Entergy's analysis of the issue of no significant hazards consideration is presented below:
| |
| : 1. Do~s the proposed change involve a significant increase in the probability or consequences of any accident previously evaluated?
| |
| Response: No.
| |
| The proposed change relocates the specified frequencies for periodic surveillance requirements to licensee control under a new Surveillance Frequency Control Program.
| |
| Surveillance frequencies are not an initiator to any acciderit previously evaluated. As a result, the probability of any accident previously evaluated is not significantly increased.
| |
| The systems and components required by the technical specifications for which the surveillance frequencies are relocated are still required to be operable, meet the acceptance criteria for the surveillance requirements, and be capable of performing any mitigation function assumed in the accident analysis. As a result, the consequences of any accident previously evaluated are not significantly increased.
| |
| Therefore, the proposed change does not involve a significant increase in the probability or consequences of an accident previously evaluated .
| |
| . 2. Does the proposed change create the possibility of a new or different kind of accident from any previously evaluated?.
| |
| Response: No.
| |
| * No new or different accidents result from utilizing the proposed change. The changes do not involve a physical alteration of the plant (i.e., no new or different type of equipment will be installed) or a change in the methods governing normal plant operation. In addition, the changes do not impose any new or different requirements. The changes do
| |
| -Proposed No Significant Hazards Consideration RBG-47799 Page 2 of 2 not alter assumptions made in the safety analysis. The proposed changes are consistent with the safety analysis assumptions and current plant operating practice.
| |
| Therefore, the proposed changes do not create the possibility of a new or different kind of accident from any accident previously evaluated.
| |
| : 3. Does the proposed change involve a significant reduction in the margin of safety?
| |
| Response: No.
| |
| The design, operation, testing methods, and acceptance criteria for systems, structures, and components (SSCs), specified in applicable codes and standards (or alternatives approved for use by the NRC) will continue to be met as described in the plant licensing basis (including the final safety analysis report and bases to TS), since these are not affected by changes to the surveillance frequencies. Similarly, there is no impact to safety analysis acceptance criteria as described in the plant licensing basis. To evaluate a change in the relocated surveillance frequency, Entergy will perform a probabilistic risk evaluation using the guidance contained in NRC approved NEI 04-10, Rev. 1 in accordance with the TS SFCP. NEI 04-10, Rev. 1, methodology provides reasonable acceptance guidelines and methods for evaluating the risk increase of proposed
| |
| *changes to surveillance frequencies consistent with Regulatory Guide 1.177.
| |
| Therefore, the proposed changes do not involve a significant reduction in a margin of safety.
| |
| * Based upon the reasoning presented above, licensee concludes that the requested change does not involve a significant hazards consideration as set forth in 10 CFR50.92(c),
| |
| Issuance of amendment.
| |
| | |
| \
| |
| Attachment 7 RBG-47799 River Bend Station (RBS}, Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference r
| |
| J
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 )
| |
| Page 1 of 34 Legend:
| |
| RBS SR Frequency Identified for Relocation or Included in TSTF-425 and NA for RBS = White Row RBS SR Frequency Identified for RelQcation Not Included in TSTF-425 = Gray Row RB.S SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment Section 3.1, Reactivity Control Systems SR 3.1.3.1 SR 3.1.3.1 Determine the position of each control 24 hours Yes Yes rod.
| |
| SR 3.1.3.2 NA DELETED None Yes (7 day NA (SR 3.1.3.2 in Frequency)
| |
| TSTF-425)
| |
| SR 3.1.3.3 SR 3.1.3.2 Insert each withdrawn control rod at 31 days (Note: Applies to partially Yes Yes (SR 3.1.3.3 in least one notch. withdrawn rod - whereas NUREG-TSTF-425) 1434 applies to each withdrawn rod (partial and full). See TSTF-475)
| |
| SR 3.1.4.2 SR 3.1.4.2 Verify, for a representative sample, 200 days cumulative operation in Yes (120 days Yes each tested control rod scram time is MODE1 cumulative ... )
| |
| within the limits of Table 3.1.4-1 with reactor steam dome pressure <::: 950 psig.
| |
| SR 3.1.5.1 SR 3.1.5.1 Verify each control rod scram 7 days Yes Yes accumulator pressure ...
| |
| SR 3.1.6.1 SR 3.1.6.1 Verify all Operable .control rods 24 hours Yes Yes comply with BPWS.
| |
| SR 3.1.7.1 SR3.1.7.1 Verify available volume of sodium 24 hours Yes Yes pentaborate solution is greater than or equal to the minimum required -
| |
| available solution volume.
| |
| SR 3.1.7.2 SR 3.1.7.2 Verify temperature of sodium 24 hours Yes Yes pentaborate solution is ...
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference -*
| |
| RBG-47799 Page 2 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency
| |
| *Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment NA SR 3.1.7.3 Verify temperature of pump suction NA Yes NA '
| |
| piping is within the limits of [Figure 3.1.7-1].
| |
| SR 3:1.?:3 NA Verify that the SLC System satisfies 31 days NA Yes the following equation ...
| |
| SR 3.1.7.4 SR 3.1.7.4 Verify continuity of explosive charge. 31 days Yes Yes SR 3.1.7.5 SR 3.1.7.5 Verify the available weight of Boron- 31 days Yes (31 day' Yes (31 day 10 is ;:: 170 lbs, and the percent Frequency only) Frequency only) weight concentration of sodium AND pentaborate in solution is:,; 9.5% by weight, and determine the minimum Once with 24 hours after water or required available solution volume. boron ...
| |
| AND Once within 24 hours after solution ...
| |
| SR 3.1.7.6 SR 3.1.7.6 Verify each SLC subsystem manual, 31 days Yes Yes power operated, and automatic valve ... is in the correct position, or can be aligned to the correct position.
| |
| SR 3.1.7.7 SR3.1.7.7 Verify each pump develops a flow In accordance with the 1ST Program Yes (92 day No rate ;:: 41.2 gpm at a discharge Frequency only -
| |
| pressure;:: 1250 psig. i.e., does not apply if the Frequency being used isthelST Program)
| |
| SR 3.1.7.8 SR 3.1.7.8 Verify flow through one SLC 24 months on a Staggered Test Basis Yes Yes subsystem from pump into reactor
| |
| ~- pressure vessel.
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs/Cross-Reference RBG-47799 Page~ of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment NA SR 3.1.7.9 NA NA Yes NA SR 3:1.8.1 SR 3.1.8.1 Verify each SDV vent and drain valve 31 days Yes Yes is open.
| |
| SR 3.1.8.2 SR 3.1.8.2 Cycle each SDV vent and drain valve 92 days Yes Yes to the fully closed and fully open position.
| |
| SR 3.1.8.3 SR 3.1.8.3 Verify each SDV vent and drain valve: 24 months Yes Yes
| |
| : a. Closes in ... ; and
| |
| : b. Opens when ...
| |
| Section 3.2, Power Distribution Limits SR 3.2.1.1 SR 3.2.1.1 Verify all APLHGRs are less than or Once with 12 hours ... Yes (24 hours Yes (24 hours equal to the limits specified in the thereafter thereafter COLR. AND Frequency only) Frequency only) 24 hours thereafter SR 3.2.2.1 SR 3.2.2.1 Verify all MCPRs are greater than or Once with 12 hours ... Yes (24 hours Yes (24 hours equal to the limits specified in the thereafter thereafter COLR. AND Frequency only) Frequency only) 24 hours thereafter SR 3.2.3.1 SR 3.2.3.1 Verify all LHGRs are less than or Once with 12 hours ... Yes (24 hours Yes (24 hours equal to the limits specified in the thereafter thereafter COLR. AND Frequency only) Frequency only) 24 hours thereafter
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| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 4 of 34 RBS SR NUREG-1434 RBS Surveillance Description
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| * RBS Surveillance Frequency STSSR SR Frequency
| |
| * Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR3.2.4.1 NA Verify [Fraction of Core Boiling 24 hours NA Yes (24 hour Boundary] FCBB ::; 1.0. Frequency only)
| |
| AND Once with 15 minutes ...
| |
| NA SR 3.2.4.1 NA NA Yes (24 hour NA Frequency only)
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| NA SR 3.2.4.2 NA NA Yes NA Section 3.3, Instrumentation SR3.3.1.1.1 SR 3.3.1.1.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.1.1.2 SR 3.3.1.1.2 Verify the absolute difference 7 days Yes Yes between the average power range monitor (APRM) channels and the calculated power ...
| |
| SR 3.3.1.1.3 SR 3.3.1.1.3 Adjust the flow control trip reference Once within 7 days after reaching Yes (7 day No card to conform to reactor flow. equilibrium conditions following Frequency) refueling outage SR 3.3.1.1.4 SR 3.3.1.1.4 Perform Channel Functional Test. 7 days Yes Yes SR 3.3.1.1.5 SR 3.3.1.1.5 Perform Channel Functional Test. 7 days Yes Yes
| |
| ;8R3.3.1.1.7 NA Verify the_ IRM and APRM channels 7 days No (STS SR Yes overlap. deleted per TSTF-264)
| |
| SR 3.3.1.1.8 SR 3.3.1.1.6 Calibrate the local power range 2000 MWDrr average core exposure Yes(1000 Yes monitors. MWDff average core exposure Frequency)
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 5 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR.3.3.1.1.9 SR 3.3.1.1.7 Perform Channel Functional Test. 92 days . Yes Yes SR 3.3.1.1.10 SR 3.3.1.1.8 Calibrate the trip units. 92 days Yes Yes SR 3.3.1.1.11 SR 3.3.1.1.9 Perform Channel Calibration. 184 days Yes Yes SR3.3.1.1.12 SR 3.3.1.1.10 Perform Channel Functional Test. 24 months Yes Yes SR3.3.1.1.13 SR 3.3.1.1.11 Perform Channel Calibration. 24 months Yes Yes SR 3.3.1.1.14 SR 3.3.1.1.12 Verify the APRM Flow Biased 24 months Yes Yes Simulated Thermal Power - High time*
| |
| constant is within the limits specified in the COLR.
| |
| SR 3.3.1.1.15 SR 3.3.1.1.13 Perform Logic System Functional 24 months Yes Yes Test.
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| SR 3.3.1.1.16 SR 3.3.1.1.14 Verify Turbine Stop Valve Closure 24 months Yes Yes and Turbine Control Valve Fast Closure Trip Oil Pressure - Low Functions are not bypassed when Thermal Power is .:: 40% RTP. I
| |
| *sR 3.3.1~ 1.17 NA Calibrate the flow reference 24 months NA Yes transmitters.
| |
| SR 3.3.1.1.18 SR 3.3.1.1.15 Verify the RPS Response Time is 24 months on Staggered Test Basis Yes Yes
| |
| .. within limits. (Includes deletion (Includes deletion of SR Note 2) of SR Note 3)
| |
| SR 3.3.1.2.1 SR 3.3.1.2.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.1.2.2 SR 3.3.1.2.2 Verify an Operable SRM detector is 12 hours Yes Yes located in ...
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| SR 3.3.1.2.3 SR 3.3.1.2.3 Perform Channel Check. 24 hours Yes Yes
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| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 6 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed
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| . TSTF-425 License (Yes/No/NA) Amendment SR 3.3.1.2.4 SR 3.3.1.2.4 Verify count rate is ... 12 hours during Core Alter~!ions Yes (both Yes (both Frequencies) Frequencies)
| |
| AND 24 hours NA SR 3.3.1.2.5 NA NA Yes NA SR 3.3.1.2.5 SR 3.3.1.2.6 Perform Channel Functional Test. 31 days Yes Yes SR 3.3.1.2.6 SR 3.3.1.2.7 Perform Channel Calibration. 24 months Yes Yes SR3,3.1 .3.1 NA Verify each Operable channel of 12 hours NA Yes PBDS instrumentation not in Hi-Hi DR Alarm .
| |
| . SR3.3.1.3.2 NA P.erform Channel Check. 12 hours NA Yes SR 3.3.1.3:3 NA Perform Channel Functional Test. 24 months NA Yes SR 3.3.2.1.1 SR 3.3.2.1.1 Perform Channel Functional Test 92 days Yes Yes SR 3.3.2.1.2 SR 3.3.2.1.2 - Perform Channel Functional Test 92 days Yes Yes SR 3.3.2.1.3 SR 3.3.2.1.3 Perform Channel Functional Test 92 days Yes Yes SR 3.3.2.1.4 SR 3.3.2.1.4 Perform Channel Functional Test 92 days Yes Yes SR 3.3.1.2.5 SR 3.3.1.2.5 Calibrate the low power setpoint frip 92 days Yes Yes units.
| |
| SR 3.3.1.2.6 SR 3.3.1.2.6 Verify the RWL high power Function 92 days Yes. Yes is not bypassed ...
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| SR 3.3.2.1.7 SR 3.3.2.1.7 Perform Channel Calibration. 184 days Yes Yes SR 3.3.2.1.8 SR 3.3.2.1.8 Perform Channel Functional Test. 24 months Yes Yes SR 3;3.3.1.1 SR 3.3.3.1.1 Perform Channel Check. 31 days Yes Yes
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 7 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.3.3.1.3 SR 3.3.3.1.2 Perform Channel Calibration. 24 months Yes Yes SR 3.3.3.2.1 SR 3.3.3.2.1 PerformChannelCheckforeach 31 days Yes Yes required instrumentation channel. ..
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| SR 3.3.3.2.2 SR 3.3.3.2.2 Verify each required control circuit 24 months Yes Yes and transfer switch is capable ...
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| SR 3.3.3.2.3 SR 3.3.3.2.3 Perform Channel Calibration for each 24 months - Yes Yes required instrumentation channel. ..
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| SR 3.3.4.1.1 SR 3.3.4.1.1 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.4.1.2 SR 3.3.4.1.2 Calibrate the trip units. 92 days Yes Yes SR 3.3.4.1.3 SR 3.3.4.1.3 Perform Channel Calibration. The 24 months Yes Yes Allowable Value ...
| |
| SR 3.3.4.1.4 SR 3.3.4.1.4 Perform Logic System Functional 24 months Yes Yes Test...
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| SR 3.3.4.1.5 SR 3.3.4.1.5 Verify TSV Closure and TCV Fast 24 months Yes Yes Closure, Trip Oil Pressure - Low Functions are not bypassed ...
| |
| SR 3.3.4.1.6 SR 3.3.4.1.6 Verify the EOC-RPT System 24 months on a Staggered Test Basis Yes Yes Response Time is within limits.
| |
| SR 3.3.4.1.7 SR 3.3.4.1.7 Determine RPT breaker interruption 60 months Yes Yes time. .,
| |
| SR 3.3.4.2.1 SR 3.3.4.2.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.4.2.2 SR 3.3.4.2.2 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.4.2.3 SR 3.3.4.2.3 Calibrate the trip units. 92 days Yes Yes SR 3.3.4.2.4 SR 3.3.4.2.4 Perform Channel Calibration. The 24 months Yes Yes Allowable Value ...
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 8 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.3.4.2.5 SR 3.3.4.2.5 Perform Logic System Functional 24 months Yes Yes Test. ..
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| SR 3.3.5.1.1 SR 3.3.5.1.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.5.1.2 SR 3.3.5.1.2 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.5.1.3 SR 3.3.5.1.3 Calibrate the trip unit. 92 days Yes Yes SR 3.3.5.1.4 SR 3.3.5.1.4 Perform Channel Calibration. 92 days Yes Yes SR 3.3.5.1.5 SR 3.3.5.1.5 Perform Channel Calibration. 24 months Yes Yes SR 3.3.5.1.6 SR 3.3.5.1.6 Perform Logic System Functional 24 months Yes Yes Test.
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| NA SR 3.3.5.1.7 NA NA Yes NA Refer to SR 3.5.1.8 SR 3.3.5.2.1 SR 3.3.5.2.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.5.2.2 SR 3.3.5.2.2 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.5.2.3 SR 3.3.5.2.3 Calibrate the trip units. 92 days Yes Yes SR 3.3.5.2.4 SR 3.3.5.2.4 Perform Channel Calibration. 24. months Yes Yes SR 3.3.5.2.5 SR 3.3.5.2.5 Perform Logic System Functional 24 months Yes Yes Test.
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| SR 3.3.6.1.1 SR 3.3.6.1.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.6.1.2 SR 3.3.6.1.2 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.6.1.3 SR 3.3.6.1.3 Calibrate the trip unit. 92 days Yes Yes SR 3.3.6.1.4 SR 3.3.6.1.4 Perform Channel Calibration. 92 days Yes Yes SR 3.3.6.1.5 SR 3.3.6.1.5 Perform Channel Calibration. 24 months Yes Yes
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference
| |
| * RBG-47799 Page 9 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.3.6.1.6 SR 3.3.6.1.6 Perform Logic System Functional 24 months Yes Yes Test.
| |
| SR 3.3.6.1.7 SR 3.3.6.1.7 Verify the Isolation System Response 24 months on a Staggered Test Basis Yes Yes Time ...
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| SR 3.3.6.2.1 SR 3.3.6.2.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.6.2.2 SR 3.3.6.2.2 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.6.2.3 SR 3.3.6.2.3 Calibrate the trip unit. 92 days Yes Yes SR 3.3.6.2.4 SR 3.3.6.2.4 Perform Channel Calibration. 24 months Yes Yes SR 3.3.6.2.5 SR 3.3.6.2.5 Perform Logic System Functional 24 months Yes Yes Test.
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| NA SR 3.3.6.2.6 NA NA Yes NA SR 3.3.6.3.1 SR 3.3.6.3.1 Perform Channel Check. 24 hours Yes (12 hour Yes Frequency)
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| SR 3.3.6.3.2 SR 3.3.6.3.2 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.6.3.3 SR 3.3.6.3.3 Calibrate the trip unit. 92 days Yes Yes NA SR 3.3.6.3.4 NA NA Yes NA SR 3.3.6.3.4 SR 3.3.6.3.5 Perform Channel Calibration. 24 months Yes Yes SR 3.3.6.3.5 SR 3.3.6.3.6 Perform Logic System Functional 24 months Yes Yes Test.
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| NA STS 3.3.6.4, Suppression Pool Makeup (SPMU) System Instrumentation, and associated SRs are NA for RBS SR 3.3.6.4.1 SR 3.3.6.5.1 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.6.4.2 SR 3.3.6.5.2 Calibrate the trip unit. 92 days Yes Yes SR 3.3.6.4.3 SR 3.3.6.5.3 Perform Channel Calibration. The 24 months Yes Yes Allowable Value ...
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 10 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS
| |
| - Proposed SR Number modified.by TSTF-425 License (Yes/No/NA) Amendment SR,3.3.6.4.4
| |
| \
| |
| SR 3.3.6.5.4 Perform Logic System Functional 24 months Yes Yes Test.
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| SR 3.3.7.1.1 SR 3.3.7.1.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.7.1.2 SR 3.3.7.1.2 Perform Channel Functional Test. 92 days Yes Yes SR 3.3.7.1.3 SR 3.3.7.1.3 Calibrate the trip units. 92 days Yes Yes SR 3.3.7.1.4 SR 3.3.7.1.4 Perform Channel Calibration. 24 months Yes Yes SR 3.3.7.1.5 SR 3.3.7.1.5 Perform Logic System Functional 24 months Yes Yes Test.
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| SR 3.3.8.1.1 SR 3.3.8.1.1 Perform Channel Check. 12 hours Yes Yes SR 3.3.8.1.2 SR 3.3.8.1.2 Perform Channel Functional Test. 31 days Yes Yes SR 3.3.8.1.3 SR 3.3.8.1.3 Perform Channel Calibration. 24 months Yes Yes SR 3.3.8.1.4 SR 3.3.8.1.4 Perform Logic System Functional 24 months Yes Yes Test.
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| SR 3.3.8.2.1 SR 3.3.8.2.1 Perform Channel Functional Test. 184 days Yes Yes SR 3.3.8.2.2 SR 3.3.8.2.2 Perform Channel Calibration. The 24 months Yes Yes Allowable Value SR 3.3.8.2.3 SR 3.3.8.2.3 Perform a system functional test. 24 months Yes Yes Section 3.4, Reactor Coolant System (RCS)
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| SR.3.4.1.1 SR 3.4.1.1 Verify recirculation loop jet pump flow 24 hours Yes Yes mismatch with both recirculation loops in operation is ...
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| SR 3.4.2.1 SR 3.4.2.1 Verify each FCV fails "as is" on loss 24 months Yes Yes of hydraulic pressure at the hydraulic unit.
| |
| - River Bend Station {RBS), Unit 1 TS Surveillance Requirements {SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 11 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.4.2.2 SR 3.4.2.2 Verify average rate of each FCV 24 months Yes Yes movement is ...
| |
| SR 3.4.3.1 SR 3.4.3.1 Verify at least two of the following 24 hours Yes Yes criteria (a, b, and c) are satisfied for each operating recirculation loop ...
| |
| SR 3.4.4.1 SR 3.4.4.1 Verify the safety function lift setpoints I~ accordance with the 1ST Program Yes (18 month No of the required S/RVs are as Frequency only -
| |
| follows ... i.e., does not apply if the Frequency being used is the 1ST Program)
| |
| SR 3.4:4.2 SR 3.4.4.2 . Verify each required relief function 24 months Yes Yes S/RV actuates on an actual or simulated automatic initiation signal.
| |
| SR 3.4.4.3 SR 3.4.4.3 Verify each required S/RV relief mode In accordance with the 1ST Yes (18 months No actuator strokes when manually Program ... on a Staggered actuated. Test Basis ... )
| |
| SR 3.4.5.1 SR 3.4.5.1 Verify RCS ... Leakage ... within limits. 12 hours Yes (Frequency Yes of 8 hours)
| |
| SR 3.4.6.1 SR 3.4.6.1 Verify equivalent leakage of each In accordance with the 1ST Program Yes (18 month No RCS PIV is ... Frequency only -
| |
| i.e., does not apply if the Frequency being used is the 1ST Program)
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference
| |
| * RBG-47799 Page 12 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.4.7.1 SR 3.4.7.1 Perform Channel Check of required 12 hours Yes Yes drywell atmospheric monitoring system.
| |
| SR 3.4.7.2 SR 3.4.7.2 Perform Channel Functional Test of 31 days Yes Yes required leakage detection instrumentation.
| |
| SR 3.4.7.3 SR 3.4.7.3 Perform Channel Calibration of 24 months Yes Yes required leakage detection instrumentation.
| |
| SR 3.4.8.1 SR 3.4.8.1 Verify reactor coolant DOSE 7 days -- Yes Yes EQUIVALENT 1-131 specific activity is s 0.2 µ Ci/gm.
| |
| SR 3.4.9.1 SR 3.4.9.1 Verify one RHR shutdown cooling 12 hours Yes Yes subsystem or recirculation pump is operating.
| |
| SR3A~9.2 NA VerifyRHR shutdown cooling 31 days NA Yes
| |
| ;(Refer to TSTF- subsystem locations susceptible to (Refer to TSTF-
| |
| *523) gas accumulation are sufficiently filled 523) with water.
| |
| SR 3.4.10.1 SR 3.4.10.1 Verify one RHR shutdown cooling 12 hours Yes - Yes subsystem or recirculation pump is operating.
| |
| SR 3.4.10.2 NA Verify RHR shutdown cooling 31 days NA Yes (Refer to TSTF- subsystem locations susceptible to (Refer to TSTF-523) gas accumulation are sufficiently filled 523) _,
| |
| with water.
| |
| | |
| I - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 13 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.4.11.1 SR 3.4.11.1 Verify: 30 minutes Yes ~
| |
| Yes
| |
| : a. RCS pressure and RCS temperature ... , and
| |
| : b. RCS heatup and cooldown rates are ...
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| C. RCS heatup and cooldown rates are ...
| |
| SR3.4.11.5 SR 3.4.11.7 Verify reactor vessel flange and head 30 minutes Yes Yes flange temperatures ...
| |
| SR 3.4.11.6 SR 3.4.11.8 Verify reactor vessel flange and head 30 minutes Yes Yes flange temperatures ...
| |
| SR3.4.11.7 SR 3.4.11.9 Verify reactor vessel flange and head 12 hours Yes Yes flange temperatures ...
| |
| SR 3.4.12.1 s*R 3.4.12.1 Verify'reactor steam dome 12 hours Yes Yes pressure ...
| |
| Section 3.5, Emergency Core Cooling Systems (ECCS) and Reactor Core Isolation Cooling (RCIC) System SR3.5.1.1 SR 3.5.1.1 Verify, for each ECCS injection/spray
| |
| * 31 days Yes Yes subsystem, locations susceptible to gas accumulation are sufficiently filled with water.
| |
| SR 3.5.1.2 SR 3.5.1.2 Verify each ECCS injection/spray subsystem manual, power operated, and automatic valve ... is in the 31 days Yes Yes correct position.
| |
| SR 3.5.1.3 SR 3.5.1.3 Verify ADS accumulator supply 31 days Yes Yes pres~ure is ...
| |
| | |
| / - River Bend Station (RaS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 14 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.5.1.4 SR 3.5.1.4 Verify each ECCS pump develops the In accordance with the 1ST Program Yes (92 day No specified flow rate with the specified Frequency only -
| |
| pump differential pressure ... i.e., does not apply if the Frequency being used is the 1ST Program)
| |
| SR 3.5.1.5 SR 3.5.1.5 Verify each ECCS injection/spray 24 months Yes Yes subsystem actuates ...
| |
| -~
| |
| SR 3.5.1.6 SR 3.5.1.6 Verify the ADS actuates ... 24 months Yes Yes SR 3.5.1.7 SR 3.5.1.7 Verify each ADS valve relief mode In accordance with the 1ST Program Yes (18 month No actuator strokes...
| |
| * on a Staggered Test Basis Frequency on a
| |
| ,_ Staggered Test Basis ... )
| |
| SR 3.5.1.8 SR 3.3.5.1.7 Verify the ECCS Response Time for 24 months Yes Yes each ECCS injection/spray subsystem is within limits.
| |
| SR 3.5.2.1 SR 3.5.2.1 Verify, for each required low pressure 12 hours Yes Yes ECCS injection/spray subsystem, the suppression pool water level is ...
| |
| SR 3.5.2.2 SR 3.5.2.2 Verify, for the required High Pressure 12 hours Yes Yes Core Spray (HPCS) System, the:
| |
| : a. Suppression pool water level is ... ;
| |
| or
| |
| : b. Condensate storage tank water I level is ...
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference
| |
| * RBG-47799 Page 15 of 34 RBS SR . NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.5.2.3 SR 3.5.2.3 Verify, for each required ECCS 31 days Yes Yes injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.
| |
| SR 3.5.2.4 SR 3.5.2.4 Verify each required ECCS 31 days Yes Yes injection/spray subsystem manual, power operated, and automatic valve
| |
| ... is in the correct position.
| |
| SR 3.5.2.5 SR 3.5.2.5 Verify each required ECCS pump In accordance with the 1ST Program Yes (92 day No develops the specified flow rate with Frequency only -
| |
| the specified pump differential i.e., does not pressure. apply if the Frequency being used is the 1ST Program) ,-
| |
| SR 3.5.2.6 SR 3.5.2.6 Verify each required ECCS 24 months - Yes Yes
| |
| - injection/spray subsystem actuates ...
| |
| SR 3.5.3.1 SR 3.5.3.1 Verify the RCIC System locations 31 days Yes Yes susceptible to gas accumulation are sufficiently filled with water.
| |
| SR 3.5.3.2 SR 3.5.3.2 Verify each RCIC System manual, 31 days Yes Yes power operated, and automatic valve ... is in the correct position.
| |
| SR 3.5.3.3 SR 3.5.3.3 Verify, with RCIC steam supply 92 days Yes Yes pressures 1075 psig and 2! 920 psig ... the RCIC pump can develop a flow rate ...
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 16 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.5.3.4 SR 3.5.3.4 Verify, with RCIC steam supply 24 months Yes Yes pressure::;; 165 psig and .: 150 psig ... the RCIC pump can develop a flow rate ...
| |
| SR 3.5.3.5 SR 3.5.3.5 Verify the RCIC System actuates ... 24 months Yes Yes Section 3.6, Containment Systems SR 3.6:1.2.2 SR 3.6.1.2.2 Verify primary containment air lock 7 days Yes Yes seal air flask pressure ...
| |
| SR 3.6.1.2.3 SR 3.6.1.2.3 Verify only one door in the primary 184 days Yes (24 month Yes containment air lock can be opened Frequency) at a time.
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| SR 3.6.1.2.4 SR 3.6.1.2.4 Verify, from an initial pressure of 90 24 months Yes Yes psig, the primary containment air lock seal pneumatic system pressure does not decay at a rate equivalent to ...
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| NA SR 3.6.1.3.1 NA NA Yes NA SR 3.6.1.3.1 SR 3.6.1.3.2 Verify each 36 inch primary 31 days Yes Yes containment purge valve is closed.
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| SR 3.6.1.3.2
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| * SR 3.6.1.3.3 Verify each primary containment 31 days Yes Yes isolation manual valve and blind flange that is located outside primary containment. .. is closed.
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| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 17 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STS SR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.6.1.3.4 SR 3.6.1.3.5 Verify the isolation time of each In accordance with the 1ST Program Yes (92 day No power operated and each automatic c
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| * Frequency only -
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| PCIV, except MSIVs, is within limits. i.e., does not apply if the
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| * Frequency being used is the 1ST Program)
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| SR 3.6.1.3.5 SR 3.6.1.3.6 Perform leakage rate testing for each In accordance with the Primary Yes (184 day No primary containment purge valve with Containment Leakage Rate Testing Frequengy only -
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| resilient seals. Program. i.e., does not apply if the Frequency being used is based on condition of valve open)
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| SR 3.6.1.3.6 SR 3.6.1.3.7 Verify the isolation time of each MSIV . In accordance with the 1ST Program Yes (18 month No is ... Frequency only -
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| i.e., does not apply if the Frequency being used is the 1ST Program)
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| SR 3.6.1.3.7 SR 3.6.1.3.8 Verify each automatic PCIV actuates 24 months Yes Yes to the isolation position ...
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| SR 3.6.1.3.8 NA Verify in°1eakage rate of:;; 340 scfh 24 months NA Yes (Similar to SR for each of the following valve groups (Refer to STS SR 3.6.5.2.4) when tested at 11.5 psid for MS- 3.6.5.2.4) -
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| PLCS valves ...
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| SR 3.6.1.3.12 SR 3.6.1.3.12 Deleted NA Yes NA
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| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 18 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License j
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| (Yes/No/NA) Amendment SR 3.6.1.4.1 SR 3.6.1.4.1 Verify primary containment pressure 12 hours Yes Yes is within limits.
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| SR 3.6.1.5.1 SR 3.6.1.5.1 Verify primary containment average 24 hours Yes Yes air temperature is within limit.
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| SR 3.6.1.6.1 SR 3.6.1.6.1 Verify each LLS valve relief mode In accordance with the 1ST Program Yes (18 month No actuator strokes when manually on a Staggered Test Basis Frequency on a actuated. Staggered Test Basis ... )
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| SR 3.6.1.6.2 SR 3.6.1.6.2 Verify the LLS System actuates on an 24 months Yes Yes actual or simulated automatic initiation signal.
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| SR 3.6.1.7.1 NA Verify each required primary 31 days Yes Yes (Similar to SR containment unit cooler pressure 3.6.1.7.1) relief and backdraft damper. .. is in the correct position.
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| SR 3.6.1.7.2 NA Verify each required primary 92 days Yes (92 day Yes (Similar to SR containment unit cooler develops a Frequency only -
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| 3.6.1.7.2) flow rate ... i.e., does not apply if the Frequency being used is the 1ST Program)
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| SR 3.6.1.7.3 NA Verify each required primary 24 months Yes Yes (Similar to SR containment unit cooler actuates 3.6.1.7.3) throughout its emergency operating sequence on ...
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| NA SR 3.6.1.7.4 NA NA Yes (10 year NA Frequency only)
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| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 19 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment NA (Refer to SR 3.6.1.8.1 NA NA Yes NA SR 3.6.1.9.1)
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| NA SR 3.6.1.8.2 NA NA Yes NA SR 3.6.1.9.1 SR 3.6.1.8.1 Verify air pressure in each associated 24 hours Yes Yes PVLCS subsystem ...
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| SR 3.6.1.9.2 SR 3.6.1.9.1 Operate each PVLCS compressor ... 31 days Yes Yes NA SR 3.6.1.9.2- NA NA Yes NA
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| $R 3.6.1.9.3 SR 3.6.1.9.3 Perform a system functional test of 24 months Yes Yes each MS-PLCS-subsystem.
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| SR 3.6.1.10.1 NA Verify each penetration flow path, 31 days NA Yes required to be closed during accident
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| . conditions, is closed.
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| SR 3.6.2.1.1 SR 3.6.2.1.1 Verify suppression pool average 24 hours Yes (24 hour Yes (24 hour temperature is within the applicable Frequency only) Frequency only) limits. AND 5 minutes when performing testing ...
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| SR 3.6.2.2.1 SR 3.6.2.2.1 Verify suppression pool water level is 24 hours Yes Yes within limits.
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| SR 3.6.2.3.1 SR 3.6.2.3.1 Verify each RHR suppression pool 31 days Yes Yes cooling subsystem manual, power operated, and automatic valve ... is in the correct position or can be aligned to the correct position.
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| SR3.6.2.3.2. _NA Verify RHR suppression pool cooling 31 days NA Yes 1
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| (Refer to TSTF- subsystem locations susceptible to (Refer to TSTF-523) gas accumulation are sufficiently filled 523) with water.
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| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 20 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.6.2.3.3 SR 3.6.2.3.2 Verify each RHR pump develops a In accordance with the 1ST Program Yes (92 day No flow rate ... to the suppression pool. Frequency only -
| |
| i.e., does not apply if the Frequency being used is the 1ST Program)
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| NA STS 3.6.2.4, Suppression Pool Makeup (SPMU) System, and associated SRs are NA for RBS SR 3.6.3.2.1 SR 3.6.3.1.1 Energize each primary containment 184 days Yes Yes and drywell hydrogen igniter division ...
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| SR 3.6.3.2.2 SR 3.6.3.1.2 Energize each primary containment 92 days ..
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| Yes Yes and drywell hydrogen igniter division ...
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| SR 3.6.3.2.3 SR 3.6.3.1.3 Verify each required igniter in 24 months Yes Yes inaccessible areas develops sufficient current draw ...
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| SR 3.6.3.2.4 SR 3.6.3.1.4 Verify each required igniter in 24 months Yes Yes accessible areas develops a surface temperature ...
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| SR 3.6.3.3.1 SR 3.6.3.2.1 Operate each primary Every Cold Shutdown, if not Yes (92 day No
| |
| ' containment/drywell hydrogen mixing performed within the previous 92 Frequency) subsystem ... days SR 3.6.3.3.2 SR 3.6.3.2.2 Verify each primary 24 months Yes Yes containment/drywell hydrogen mixing subsystem flow rate ...
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| SR 3.6.4.1.1 SR 3.6.4.1.1 Verify shield building annulus and 24 hours Yes Yes auxiliary building vacuum ...
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference ,
| |
| RBG-47799 Page 21 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) - Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.6.4.1.2 SR 3.6.4.1.2 Verify all secondary containment 31 days Yes Yes equipment hatches are closed ...
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| SR 3.6.4.1.3 SR 3.6.4.1.3 Verify each secondary containment 31 days Yes Yes access door is closed ...
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| SR 3.6.4.1.4 SR 3.6.4.1.4 Verify each standby gas treatment 24 months on a Staggered Test Basis Yes Yes (SGT) subsystem will draw down the shield building annulus and auxiliary building ...
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| SR 3.6.4.1.6 SR 3.6.4.1.5 Verify each SGT subsystem can 24 months on a Staggered Test Basis Yes Yes maintain ... vacuum water gauge in the shield building annulus and auxiliary building, respectively, for 1 hour.
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| NA SR 3.6.4.2.1 NA NA Yes NA SR 3.6.4.2.1 SR 3.6.4.2.2 Verify the isolation time of each 92 days Yes (92 day Yes required power operated automatic Frequency only -
| |
| SCIO and FBIO is within limits. i.e., does not
| |
| - apply if the Frequency being used is the 1ST Program)
| |
| SR 3,6.4.2.2 SR 3.6.4.2.3 Verify each required automatic SCIO 24 months Yes Yes and FBIO actuates to the isolation position ... ~
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| SR 3.6.4.3.1 SR 3.6.4.3.1 Operate each SGT subsystem for ... 31 days Yes Yes SR 3.6.4.3.3 SR 3.6.4.3.3 Verify each SGT subsystem 24 months Yes Yes actuates ...
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| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799
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| \
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| Page 22 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS
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| (
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| SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.6.4.3.4 SR 3.6.4.3.4 Verify each SGT filter cooling bypass 24 months Yes Yes damper can be opened and the fan started.
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| SR 3.6.4.5.1 NA Verify fuel building vacuum ...* 24 hours NA Yes
| |
| . (Similar to SR (Refer to STS SR 3.6.4.1.1) .- 3.6.4.1.1)
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| SR*3.6.4.5.2 NA Verify all fuel building equipment 31 days NA Yes (Similar to SR hatches are installed. (Refer to STS SR 3.6.4.1.2) 3.6.4.1.2)
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| SR 3:6.4.5,3: NA Verify each fuel building access door 31 days NA Yes.,*
| |
| (Similar to SR is closed.:. (Refer to STS SR 3.6.4.1.3)
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| * 3.6.4.1.3)
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| SR3.6.4.7.1. NA Verify one fuel building ventilation 12 hours NA Yes charcoal filtration subsystem in operation.
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| SR 3.6.4.7.2 NUREG-1431, Operate each fuel building ventilation 31 days Yes (Refer to Yes SR 3.7.13.1 charcoal filtration subsystem for ... NUREG-1431, SR 3.7.13.1)
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| SR 3.6.4.7.4 NUREG-1431, Verify each fuel building ventilation 24 months Yes (Refer to Yes SR 3.7.13.3 charcoal filtration subsystem NUREG-1431, actuates ... SR 3.7.13.3)
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| SR 3.6.4.7.5 NUREG-1431, Verify each fuel building ventilation 24 months Yes (Referto Yes SR 3.7.13.5 charcoal filtration filter cooling bypass NUREG-1431, damper can be opened and the fan SR 3.7.13.5) started.
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| SR 3.6.5.1.1* NA Verify personnel door inflatable seal 7 days NA Yes (Similar to SR air flask pressure ... . (Refer to STS SR 3.6.5.2.2) 3.6.5.2.2)
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| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 23 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.6.5.1.2 NA Verify from an initial pressure of 75 24 months NA Yes (Similar to SR psig, the personnel door inflatable (Refer to STS SR 3.6.5.2.5) seal pneumatic system pressure does 3.6.5.2.5) not decay ...
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| SR 3.6.5.1.3 SR 3.6.5.1.1 Verify bypass leakage is less than or 24 months following 2 consecutive Yes (18 month Yes (180 month (Refer to RBS equal to the bypass leakage limit. tests with bypass leakage greater Frequency) Frequency only -
| |
| License than the bypass leakage limit. .. Refer to RBS Amendment However, during the first unit startup License 191) following bypass leakage testing ... AND Amendment 191) 48 months following a test with bypass leakage greater than the bypass leakage limit AND 180 months SR 3.6.5.1.4 SR 3.6.5.1.2 Visually inspect the exposed Once prior to performance of each Yes (40 month No accessible interior and exterior Type A test required by SR 3.6.1.1.1 Frequency) surfaces of the drywell.
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| SR 3.6.5.1.6 NA Verify drywell air lock leakage by 24 months NA Yes (Similar to SR performing an air lock barrel leakage (Refer to STS SR 3.6.5.2.4) test. .. 3.6.5.2.4)
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| SR 3.6.5.2.1 SR 3.6.5.2.1 Deleted NA Yes NA SR 3.6.5.2.2 SR 3.6.5.2.2 Verify drywell airlock seal air flask 7 days Yes Yes pressure ...
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| SR 3.6.5.2.3 SR 3.6.5.2.3 Verify only one door in the drywell air 24 months Yes Yes lock can be opened at a time.
| |
| SR 3.6.5.2.4 SR 3.6.5.2.4 Deleted NA Yes NA
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| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference
| |
| * RBG-47799 Page 24 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STS SR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.6.5.2.5 SR 3.6.5.2.5 Verify from an initial pressure of 75 24 months Yes -- Yes psig, the drywell airlock seal pneumatic system pressure does not decay ...
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| SR 3.6.5.3.1 SR 3.6.5.3.1 Verify each 24 inch drywell purge 31 days Yes Yes isolation valve is sealed closed.
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| SR 3.6.5.3.2 NA Verify each primary 31 days Yes Yes (Similar to SR containment/drywell hydrogen mixing 3.6.5.3.2) isolation valve is closed.
| |
| SR 3.6.5.3.4 SR 3.6.5.3.4 Verify the isolation time of each In accordance with the 1ST Program Yes (92 day No power operated and each automatic Frequency only -
| |
| drywall isolation valve is within limits. i.e., does not apply if the Frequency being used is the 1ST Program)
| |
| SR 3.6.5.3.5 SR 3.6.5.3.5 Verify each automatic drywall 24 months Yes Yes isolation valve actuates to the isolation position ...
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| SR 3.6.5.3.6 NA Verify the cumulative time that the 31 days NA Yes primary containment/drywall -
| |
| hydrogen mixing inlet or outlet penetrations are open ...
| |
| NA SR 3.6.5.3.6 NA NA Yes NA SR 3.6.5.4.1 SR 3.6.5.4.1 Verify drywell-to-primary containment 12 hours Yes Yes differential pressure is within limits.
| |
| SR 3.6.5.5.1 SR 3.6.5.5.1 Verify drywell average air 24 hours Yes Yes temperature is within limit.
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| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 25 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number --.. modified by Proposed TSTF-425 License (Yes/No/NA) Amendment NA STS 3.6.5.6, Drywell Vacuum Relief System, and associated SRs are NA for RBS Section 3.7, Plant Systems -
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| SR 3.7.1.1 SR 3.7.1.1 Verify the water level of UHS cooling 24 hours Yes Yes tower basin ...
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| NA SR 3.7.1.2 NA NA Yes NA SR 3.7.1.2 SR 3.7.1.3 Verify the average water temperature 24 hours Yes Yes of UHS ...
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| SR3.7.1.3 SR 3.7.1.4 Operate each cooling tower fan cell. .. 31 days Yes Yes SR 3.7.1.4 SR 3.7.1.5 Verify each required SSW subsystem 31 days Yes Yes manual, power operated, and automatic valve ... is in the correct position. --
| |
| SR 3.7.1.5 SR 3.7.1.6 Verify each SSW subsystem 24 months Yes Yes actuates ...
| |
| NA STS 3. 7.2, High Pressure Core Spray (HPCS) Service Water System (SWS), and associated SRs are NA for RBS SR 3.7.2.1 SR 3.7.3.1 Operate each CRFA subsystem for ... 31 days Yes Yes
| |
| . SR 3.7.2.3 SR 3.7.3.3 Verify each CRFA subsystem 24 months Yes Yes actuates ...
| |
| SR 3.7.3.1 SR 3.7.4.1 Verify each control room AC 24 months Yes Yes subsystem has the capability to remove the assumed heat load ...
| |
| SR 3.7.4.1 SR 3.7.5.1 Verify the gross gamma activity rate Once within 4 hours after... Yes (31 day No of the noble gases ... Frequency only)
| |
| SR 3.7.4.2 Verify the gross gamma activity rate 31 days Yes of the noble gases ...
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs_Cross-Reference RBG-47799 Page 26 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed
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| - TSTF-425 License (Yes/No/NA) Amendment SR 3.7.5.1 SR 3.7.6.1 Verify one complete cycle of each 31 days Yes Yes main turbine bypass valve.
| |
| SR 3.7.5.2 SR 3.7.6.2 Perform a system functional test. 24 months Yes Yes SR 3.7.5.3 SR 3.7.6.3 Verify the Turbine Bypass System 24 months Yes Yes Response Time ...
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| SR 3.7.6.1 SR 3.7.7.1 Verify the fuel pool water level is .... 7 days Yes Yes Section 3.8, Electrical Systems \
| |
| SR 3.8.1.1 SR 3.8.1.1 Verify correct breaker alignment and 7 days Yes Yes indicated power availability ...
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| SR 3.8.1.2 SR 3.8.1.2 Verify each DG starts from standby 31 days Yes Yes conditions and achieves ...
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| SR 3.8.1.3 SR 3.8.1.3 Verify each DG operates for <:: 60 31 days Yes Yes minutes ...
| |
| SR 3.8.1.4 SR 3.8.1.4 Verify each day tank contains ... 31 days Yes ~
| |
| Yes SR 3.8.1.5 SR 3.8.1.5 Check for and remove accumulated 31 days Yes Yes water from each day tank. -
| |
| SR 3.8.1.6 SR 3.8.1.6 Verify the fuel oil transfer system 31 days Yes Yes operates to automatically transfer fuel oil. ..
| |
| SR 3.8.1.7 SR 3.8.1.7 Verify each DG starts from standby 184 days Yes Yes conditions and achieves ...
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| SR 3.8.1.8.a SR 3.8.1.8 Verify manual transfer of unit power 24 months Yes Yes supply ... '
| |
| SR 3.8.1.8.b Verify automatic transfer of bus ... 24 months Yes
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 27 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency /
| |
| STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.8.1.9 SR 3.8.1.9 Verify each DG rejects a load greater 24 months Yes Yes than or equal to its associated single largest post accident load and following load rejection ...
| |
| SR 3.8.1.10 SR 3.8.1.10 Verify each DG operating at a power 24 months Yes Yes factor!> 0.9 does not trip and voltage is maintained ...
| |
| SR3.8.1.11 SR 3.8.1.11 Verify on an actual or simulated loss 24 months Yes Yes of offsite powE;lr signal. ..
| |
| SR 3.8.1.12 SR 3.8.1.12 Verify on an actual or simulated 24 months Yes Yes Emergency Core Cooling System (ECCS) initiation signal each DG auto-starts from standby condition and ...
| |
| SR3.8.1.13 SR 3.8.1.13 Verify each DG's automatic trips are 2:.t months Yes Yes bypassed on an actual or simulated I
| |
| ECCS initiation signal except. ..
| |
| SR 3.8.1.14 SR 3.8.1.14 Verify each DG operating at a power 24 months Yes Yes factor!> 0.9, operates for~ 24 hours ...
| |
| SR 3.8.1.15 SR 3.8.1.15 Verify each DG starts and achieves ... 24 months Yes Yes SR 3.8.1.16 SR 3.8.1.16 Verify each DG ... 24 months Yes Yes SR 3.8.1.17 SR3.8.1.17 Verify, with a DG operating in test 24 months Yes Yes mode and connected to its bus, an
| |
| . actual or simulated ECCS initiation signal overrides the test mode by ...
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Refer..ence RBG-47799 Page 28 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.8.1.18 SR 3.8.1.18 Verify sequence time is within +/-10% 24 months Yes Yes of design for each load sequencer timer.
| |
| SR 3.8.1.19 SR 3.8.1.19 Verify, on an actual or simulated loss 24 months
| |
| - Yes Yes
| |
| - of offsite power signal in conjunction with an actual or simulated ECCS initiation signal ...
| |
| SR 3.8.1.20 SR 3.8.1.20 Verify, when started simultaneously 10 years Yes Yes from standby condition, each DG achieves ...
| |
| SR 3.8.3.1 SR 3.8.3.1 Verify each fuel oil storage tank 31 days Yes Yes contains ...
| |
| SR 3.8.3.2 SR 3.8.3.2 Verify lube oil inventory is ... 31 days - Yes Yes SR 3.8.3.4 SR 3.8.3.4 Verify each required DG air start 31 days Yes Yes receiver pressure ...
| |
| SR 3.8.3.5 SR 3.8.3.5 Check for and remove accumulated 31 days Yes Yes water from each fuel oil storage tank ...
| |
| SR 3.8.4.1 SR 3.8.4.1 Verify battery terminal voltage is ... on 7 days Yes Yes float charge.
| |
| | |
| Attachment 7 - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 29 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.8.4.2 NA Verify no visible corrosion at battery 92 days NA Yes (Deleted by terminals and connectors.
| |
| TSTF-360)
| |
| OR Verify battery connection resistance ...
| |
| AND Verify the total resistance for ...
| |
| SR 3.8.4.3- NA Verify battery cells, cell plates, and 24 months .. NA Yes (Deleted by racks show no visual indication of TSTF-360) physical damage or abnormal deterioration.
| |
| * SR3.8.4.4 *NA Remove visible corrosion, and verify 24 months NA Yes (Deleted by battery cell to cell and terminal
| |
| -* TSTF-360) connections are ...
| |
| SR 3.8.4.5 NA Verify battery connection resistance 24 months NA Yes (Deleted by is ...
| |
| *TSTF-360)
| |
| AND Verify the total resistance ...
| |
| SR 3.8.4.6 SR 3.8.4.2 ve-rify each battery charger 24 months Yes Yes supplies ... amps ...
| |
| SR 3.8.4.7 SR 3.8.4.3 Verify battery capacity is adequate to 24 months Yes Yes -
| |
| supply, and maintain in Operable status, the required emergency loads ...
| |
| | |
| I I - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 30 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.8.4.8 SR 3.8.6.6 Verify battery capacity is 2:: 80% ... 60 months Yes (60 month Yes (60 month (Moved to STS when subjected to a performance Frequency only - Frequency only) 3.8.6 per TSTF- discharge test. AND STS SR 3.8.6.6) 360) 18 months (Note: ... when battery shows degradation or has reached 85% of expected life.)
| |
| NA SR 3.8.6.1 NA NA Yes NA (Added by TSTF-360)
| |
| SR 3.8.6.1 SR 3.8.6.2 - pilot Verify battery cell parameters meet 7 days Yes (31 day Yes (Deleted by cell voltage Table 3.8.6-tCategory A limits (i.e., Frequency for a TSTF-360) pilot cell). STS SR 3.8.6.2)
| |
| SR 3.8.6.2 SR 3.8.6.3- Verify battery cell parameters meet 92 days Yes (31 days for Yes (92 days (Deleted by electrolyte level Table 3.8.6-1 Category B limits (i.e., STS SR 3.8.6.3 only)
| |
| TSTF-360) SR 3.8.6.5 - float connected cells). AND and 92 days for voltage STS SR 3.8.6.5)
| |
| Once within 72 hours after. ..
| |
| SR 3.8.6.3 SR 3.8.6.4 Verify average electrolyte 92 days Yes (31 day Yes temperature of representative cells Frequency) is ... -
| |
| SR 3.8.7.1 SR 3.8.7.1 Verify correct inverter voltage, 7 days Yes Yes frequency, and alignment to required AC vital buses.
| |
| SR 3.8.8.1 SR 3.8.8.1 Verify correct inverter voltage, 7 days - Yes Yes frequency, and alignments to required AC vital buses.
| |
| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 31 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.8.9.1 SR 3.8.9.1 Verify correct breaker alignments and 7 days Yes Yes voltage to required AC, DC, and AC vital bus electrical power distribution subsystems. '
| |
| SR 3.8.10.1 SR 3.8.10.1 Verify correct breaker alignments and 7 days Yes Yes voltage to required AC, DC, and AC vital bus electrical power distribution subsystems.
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| Section 3.9, Refueling Operations SR 3.9.1.1 SR 3.9.1.1 Perform Channel Functional Test on 7 days Yes Yes each of the following required refueling equipment interlock ...
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| SR 3.9.2.1 SR 3.9.2.1 Verify reactor mode switch locked in 12 hours Yes Yes refuel position.
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| SR 3.9.2.2 SR 3.9.2.2 Perform Channel Functional Test. 7 days Yes Yes SR 3.9.3.1 SR 3.9.3.1 Verify all control rods are fully 12 hours Yes Yes inserted.
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| SR 3.9.5.1 SR 3.9.5.1 Insert each withdrawn control rod at 7 days Yes Yes least one notch.
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| SR 3.9.5.2 SR 3.9.5.2 Verify each withdrawn control rod 7 days Yes Yes scram accumulator pressure ...
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| SR 3.9.6.1 SR 3.9.6.1 Verify RPV water level. .. 24 hours Yes Yes
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| -SR 3.9.7.1 SR 3.9.7.1 Verify RPV water level. .. 24 hours Yes* Yes SR 3.9.8.1 SR 3.9.8.1 Verify one RHR shutdown cooling 12 hours Yes Yes subsystem is operating.
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| I I - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 32 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment
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| ),R-3.9.8.2 NA Verify required RHR shutdown 31 days NA Yes
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| : (Refer to TSTF- cooling subsystem locations (Refer to TSTF-
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| * 523) susceptible to gas accumulation 523)
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| I*
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| are ....
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| SR 3.9.9.1 SR 3.9.9.1 Verify one RHR shutdown cooling 12 hours Yes Yes subsystem is operating.
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| SR 3.9,9.2 NA Verify required RHR shutdown 31 days NA Yes
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| . (Refer to TSTF- cooling subsystem locations (Refer to TSTF-523). susceptible to gas accumulation 523) are ...
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| Section 3.10, Special Operations SR 3.10.2.1 SR 3.10.2.1 Verify all control rods are fully 12 hours Yes Yes inserted in core cells ...
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| SR 3.10.2.2 SR 3.10.2.2 Verify no Core Alterations are in 24 hours Yes Yes progress.
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| SR 3.10.3.2 SR 3.10.3.2 Verify all control rods ... are disarmed. 24 hours Yes Yes SR 3.10.3.3 SR 3.10.3.3 Verify all control rods ... are fully 24 hours Yes Yes inserted.
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| SR 3.10.4.2 SR 3.10.4.2 Verify all control rods ... are disarmed. 24 hours Yes Yes SR 3.10.4.3 SR 3.10.4.3 Verify all control rods ... are fully .24 hours Yes Yes inserted.
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| SR 3.10.4.4 SR 3.10.4.4 Verify a control rod withdrawal block 24 hours Yes Yes is inserted.
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| SR 3.10.5.1 SR3.10.5.1 Verify all control rods ... are fully 24 hours Yes Yes inserted.
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| SR 3.10.5.2 SR 3.10.5.2 Verify all control rods ... are disarmed, 24 hours Yes Yes
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| - River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 33 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 License (Yes/No/NA) Amendment SR 3.10.5.3 SR 3.10.5.3 Verify a control rod withdrawal block 24 hours Yes Yes is inserted.
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| SR 3.10.5.5 SR 3.10.5.5 Verify no Core Alterations are in 24 hours Yes Yes
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| 'progress.
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| SR 3.10.6.1 SR 3.10.6.1 Verify the four fuel assemblies are 24 hours Yes Yes removed.,.
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| SR 3.10.6.2 SR 3.10.6.2 Verify all other control rods ... are fully 24 hours Yes Yes inserted.
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| SR 3.10.6.3 SR 3.10.6.3 Verify fuel assemblies being loaded 24 hours Yes Yes are in compliance with an approved spiral reload sequence.
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| SR 3.10.8.4 SR 3.10.8.4 Verify no other Core Alterations are in 12 hours Yes Yes progress.
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| SR 3.10.8.6 SR 3.10.8.6 Verify CRD charging water header 7 days Yes Yes pressure ...
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| NA STS 3.10.9, Recirculation Loops - Testing, and associated SRs are NA for RBS NA STS 3.10.10, Training Startups, and associated SRs are NA for RBS Section 5.5, Programs and Manuals. -
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| 5:5.7 5.5.8 ... required testing of Engineered 24 months No Yes Safety Feature (ESF) filter ventilation systems at the frequencies specified in Regulatory Guide 1.52, Revision 2, except that testing specified at a frequency of 18 months is required at a frequency ...
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| .Attachment t- River Bend Station (RBS), Unit 1 TS Surveillance Requirements (SRs) to NUREG-1434 SRs Cross-Reference RBG-47799 Page 34 of 34 RBS SR NUREG-1434 RBS Surveillance Description RBS Surveillance Frequency STSSR SR Frequency Number Revision 4 (STS) Frequency modified in RBS SR Number modified by Proposed TSTF-425 Li~ense (Yes/No/NA) Amendment 5.5.9.c 5.5.10.c Total particulate concentration of the 31 days No Yes fuel oil in the storage tanks is < 10 mg/I when tested every 31 days in accordance with ...
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| 5.5.14.c 5.5.15.c ... (ii) assessing CRE habitability at 24 months No Yes the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0, except that testing specified at a frequency of 18 months is required at a frequency of 24 months.
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| 5.5.14.d 5.5.15.d Measurement ... of the CRE pressure 24 months on a Staggered Test Basis Yes Yes (Previously SR ... at a Frequency of 24 months on a (Refer to SR 3.7.3.4; moved Staggered Test Basis ... 3.7.3.4 and per TSTF-448) TSTF-448)}}
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