GO2-15-007, License Amendment Request for Adoption of Technical Specification Task Force Traveler-425, Revision 3: Difference between revisions

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{{#Wiki_filter:W. Grover Hettel Vice President, Operations P.O. Box 968, Mail Drop PE23 Richland, WA 99352-0968 Ph. 509-377-8311 F. 509-377-4674 wghettel@energy-northwest.com March 17, 2015 GO2-15-007 10 CFR 50.90 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, D.C. 20555-0001
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==Subject:==
COLUMBIA GENERATING STATION, DOCKET NO. 50-397 LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3
 
==References:==
: 1. Nuclear Energy Institute (NEI) 04-10, Revision 1, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies," dated April 2007
: 2. Technical Specifications Task Force (TSTF) Standard Technical Specifications (STS) Change TSTF-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5b,"
dated March 18, 2009
: 3. "Notice of Availability of Technical Specification Improvement To Relocate Surveillance Frequencies to Licensee Control - Risk-Informed Technical Specification Task Force (RITSTF) Initiative 5b, Technical Specification Task Force - 425, Revision 3," Federal Register published July 6, 2009 (74 FR 31996)
 
==Dear Sir or Madam,==
 
In accordance with the provisions of Title 10 of the Code of Federal Regulation (10 CFR Part 50.90), "Application for amendment of license, construction permit, or early site permit," Energy Northwest requests an amendment to the Technical Specifications (TS) for Columbia Generating Station (Columbia). The proposed amendment would modify the Columbia 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 5b, Risk-Informed Method for Control of Surveillance Frequencies" (Reference 1).
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3 Page 2 of 3 The changes are consistent with NRC-approved Industry Technical Specifications Task Force (TSTF) Standard Technical Specifications (STS) change TSTF-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5b," dated March 18, 2009 (Reference 2); however, Energy Northwest is proposing certain variations and deviations from TSTF-425 as discussed in Attachment 1. The Federal Register notice published on July 6, 2009 (Reference 3), announced the availability of this TS improvement as part of the consolidated line item improvement process (CLIIP).
The following attachments are included as part of this request:
x  Attachment 1 provides a description of the proposed change, the requested confirmation of applicability, and plant-specific verifications.
x  Attachment 2 provides documentation of Probabilistic Risk Assessment (PRA) technical adequacy.
x  Attachment 3 provides the existing Columbia TS pages marked up to show the proposed changes.
x  Attachment 4 provides the proposed clean typed Columbia TS pages.
x  Attachment 5 provides the existing Columbia TS Bases pages marked up to show the appropriate changes. The marked up TS Bases pages are provided for information only and do not require NRC approval.
x  Attachment 6 provides a Columbia Surveillance Requirements (SRs) versus TSTF-425 SRs Cross-Reference.
x  Attachment 7 provides the proposed No Significant Hazards Consideration.
There are no regulatory commitments contained in this request.
Energy Northwest requests approval of the proposed license amendment within one year of the date of this letter. Once approved, the amendment will be implemented within 120 days. This implementation period will provide adequate time for the affected station documents to be revised using the appropriate change control mechanisms.
In accordance with 10 CFR 50.91, "Notice for public comment; State consultation,"
paragraph (b), Energy Northwest is notifying the State of Washington of this application for license amendment by transmitting a copy of this letter and its attachments to the designated State Official.
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3 Page 3 of 3 If you have any questions concerning this letter, please contact Ms. L. L. Williams, Licensing Supervisor, at 509-377-8148.
I declare under penalty of perjury that the foregoing is true and correct. Executed on the_oday of        Fq                      , 20j.
Respectfully, WG Hettel Vice President, Operations
 
==Enclosure:==
OSM containing stated attachments cc:  NRC Region IV Administrator NRC NRR Project Manager NRC Sr. Resident Inspector 988C CD Sonoda BPN1399 (email)
WA Horin Winston & Strawn RR Cowley -WDOH (email)
EFSECutc.wa.gov-- EFSEC (email)
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3 Page 1 of 5
 
==1.0      DESCRIPTION==
 
The proposed amendment will modify the Columbia Generating Station (Columbia)
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 5b" (Reference 1).
Additionally, the change will add a new program, the Surveillance Frequency Control Program, to TS Section 5, Administrative Controls.
The changes are consistent with NRC-approved Industry/TSTF Standard Technical Specifications (STS) change TSTF-425, Revision 3 (Reference 1); however, Energy Northwest is proposing certain variations and deviations from TSTF-425 as discussed below in Section 2.2. The Federal Register notice published on July 6, 2009 (Reference 2), announced the availability of this TS improvement as part of the consolidated line item improvement process (CLIIP).
2.0      ASSESSMENT 2.1      Applicability of Published Safety Evaluation Energy Northwest has reviewed the NRC's model safety evaluation dated July 6, 2009 (Reference 2). This review included a review of the NRC staff's evaluation, TSTF-425, Revision 3, and the requirements specified in NEI 04-10, Revision 1, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies," (i.e., Reference 3). includes Energy Northwest's documentation with regard to Probabilistic Risk Assessment (PRA) technical adequacy consistent with the requirements of Regulatory Guide 1.200, Revision 1 (Reference 4), Section 4.2, and describes any PRA models without NRC-endorsed standards, including documentation of the quality characteristics of those models in accordance with Regulatory Guide 1.200.
Energy Northwest has concluded that the justifications presented in the TSTF proposal and the safety evaluation prepared by the NRC staff are applicable to Columbia and justify this amendment to incorporate the changes to the Columbia TS.
2.2      Optional Changes and Variations The proposed amendment is consistent with the STS changes described in TSTF-425, Revision 3; however, Energy Northwest proposes variations or deviations from TSTF-425, as identified below.
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3 Page 2 of 5
: 1. The definition of STAGGERED TEST BASIS is being retained in Columbia TS Definition Section 1.1 because this terminology is mentioned in Administrative TS Section 5.5.14, "Control Room Envelope Habitability Program," which is not the
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3 Page 3 of 5 subject of this amendment request and is not proposed to be changed. This is an administrative deviation from TSTF-425 with no impact on the NRC staff's model safety evaluation dated July 6, 2009 (Reference 2).
: 2. Attachment 6 provides a cross-reference between the Columbia Surveillance Requirements (SRs) included in this amendment request versus the NUREG-1434 and, in some cases, NUREG-1433 SRs included in TSTF-425. Attachment 6 includes a listing of the referenced Columbia/TSTF-425 SRs and is provided for information purposes only and is not intended to be a verbatim description of the TS Surveillance Frequencies. This cross-reference highlights the following items.
: a. SRs included in TSTF-425 and corresponding Columbia SRs with identical SR numbers. These are not deviations from TSTF-425.
: b. SRs included in TSTF-425 and corresponding Columbia SRs with differing SR numbers. These are administrative deviations from TSTF-425 with no impact on the NRC staff's model safety evaluation (Reference 2).
: c. SRs included in TSTF-425 that are not contained in the Columbia TS.
These are not applicable to Columbia and are identified by use of "NA" in the Columbia Surveillance Requirement Number column. This is an administrative deviation from TSTF-425 with no impact on the NRC staff's model safety evaluation (Reference 2).
: d. Columbia plant-specific SRs that are not contained in the TSTF-425 mark-ups. These plant-specific SRs are identified by use of "NA" in the Equivalent NUREG-1434 Revision 4 Surveillance Requirement Number column of Attachment 6. Energy Northwest has determined that the relocation of the Frequencies for these Columbia plant-specific SRs is consistent with the intent of TSTF-425, Revision 3, and with the NRC staff's model safety evaluation (Reference 2), including the scope exclusions identified in Section 1.0, "Introduction," of the Reference 2 model safety evaluation, because the subject plant-specific SRs involve fixed periodic Frequencies.
In accordance with TSTF-425, changes to the plant-specific Frequencies for these SRs will be controlled under the Surveillance Frequency Control Program, as identified in TSTF-425. Therefore, the relocation of these plant-specific SR Frequencies to the Surveillance Frequency Control Program is acceptable and does not impact the NRC staff's model safety evaluation (Reference 2).
In addition, in some cases for both items a and b above, the wording of the actual Columbia SR is not identical to that for the TSTF-425/NUREG-1434 or NUREG-1433 TS SR. However, in these cases, the intent of the
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3 Page 4 of 5 Columbia SR is the same as the NUREG-1434 or NUREG-1433 SR. Therefore, these are administrative deviations from TSTF-425 with no impact on the NRC staff's model safety evaluation (Reference 2).
 
==3.0      REGULATORY ANALYSIS==
 
3.1      No Significant Hazards Consideration Energy Northwest has reviewed the proposed no significant hazards consideration (NSHC) determination published in the Federal Register dated July 6, 2009 (74 FR 31996). Energy Northwest has concluded that the proposed NSHC presented in the Federal Register notice is applicable to Columbia, and is provided as Attachment 7 to this amendment request, which satisfies the requirements of 10 CFR 50.91(a),
"Notice for public comment; State consultation."
3.2      Applicable Regulatory Requirements A description of the proposed changes and their relationship to applicable regulatory requirements is provided in TSTF-425, Revision 3 (i.e., Reference 1) and the NRC's model safety evaluation published in the Notice of Availability dated July 6, 2009 (i.e., Reference 2). Energy Northwest has concluded that the relationship of the proposed changes to the applicable regulatory requirements presented in the Federal Register notice is applicable to Columbia.
3.3      Conclusions In conclusion, based on the considerations discussed above, (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.
 
==4.0      ENVIRONMENTAL CONSIDERATION==
 
Energy Northwest has reviewed the environmental consideration included in the NRC staff's model safety evaluation published in the Federal Register on July 6, 2009 (i.e., Reference 2). Energy Northwest has concluded that the NRC's findings presented therein are applicable to Columbia, and the determination is hereby incorporated by reference for this application.
 
==5.0      REFERENCES==
: 1. TSTF-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control -
RITSTF Initiative 5b," dated March 18, 2009 (ADAMS Accession No. ML080280275)
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3 Page 5 of 5
: 2. "Notice of Availability of Technical Specification Improvement To Relocate Surveillance Frequencies to Licensee Control-Risk-Informed Technical Specification Task Force (RITSTF) Initiative 5b, Technical Specification Task Force-425, Revision 3," Federal Register published July 6, 2009 (74 FR 31996)
: 3. Nuclear Energy Institute (NEI) 04-10, Revision 1, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies," dated April 2007 (ADAMS Accession No. ML071360456)
: 4. Regulatory Guide 1.200, Revision 1, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities,''
dated January 2007 (ADAMS Accession No. ML070240001)
: 5. Regulatory Guide 1.177, "An Approach for Plant-Specific, Risk-Informed Decisionmaking: Technical Specifications," dated May 2011 (ADAMS Accession No. ML100910008)
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Documentation of Probabilistic Risk Assessment Technical Adequacy Page 1 of 11 Overview The implementation of the Surveillance Frequency Control Program (also referred to as Technical Specifications Initiative 5b) at Columbia will follow the guidance provided by NEI 04-10, Revision 1 in evaluating proposed surveillance test interval (STI; also referred to as "Surveillance Frequency") changes.
The following steps of the risk-informed STI revision process will be common to proposed changes to all STIs within the proposed licensee controlled program.
x  Each proposed STI revision will be reviewed to determine whether there are any commitments made to the NRC that may prohibit changing the interval. If there are no related commitments, or the commitments may be changed using a commitment change process based on NRC endorsed guidance, then evaluation of the STI revision would proceed. If a commitment exists and the commitment change process does not permit the change without NRC approval, then the proposed STI revision cannot be implemented. Only after receiving NRC approval to change the commitment could a proposed STI revision proceed.
x  A qualitative analysis will be performed for each proposed STI revision that involves several considerations as explained in NEI 04-10, Revision 1.
x  Each proposed STI revision will be reviewed by an expert panel that will include specialists with experience in surveillance tests and system or component reliability. If the expert panel approves the STI revision, the change will be documented, implemented, and available for future audits by the NRC. If the expert panel does not approve the STI revision, the STI value will be left unchanged.
x  Performance monitoring will be conducted as recommended by the expert panel.
In some cases, no additional monitoring may be necessary beyond that already conducted under the Maintenance Rule. The performance monitoring helps to confirm that no failure mechanisms related to the revised test interval become important enough to alter the information provided for the justification of the interval changes.
x  The expert panel will be responsible for periodic review of performance monitoring results. If it is determined that the time interval between successive performances of a surveillance test is a factor in the unsatisfactory performance of the surveillance, the expert panel will consider adjusting the STI as needed to provide reasonable assurance of continued satisfactory performance.
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Documentation of Probabilistic Risk Assessment Technical Adequacy Page 2 of 11 x  In addition to the above steps, the Columbia PSA will be used, when possible, to quantify the effect of a proposed individual STI revision compared to acceptance criteria in Figure 2 of NEI 04-10, Revision 1. Also, the cumulative impact of all risk-informed STI revisions on all hazards which have a PRA model (i.e., internal events, external events and shutdown) will be compared to the risk acceptance criteria as delineated in NEI 04-10.
For those cases where the STI cannot be modeled in the Columbia PSA (or where a particular PSA model does not exist for a given hazard group), a qualitative or bounding analysis will be performed to provide justification for the acceptability of the proposed test interval change.
The NEI 04-10 methodology endorses the guidance provided in RG 1.200. The guidance in RG 1.200 indicates that the following steps should be followed when performing PRA assessments:
: 1. Identify the parts of the PRA used to support the application.
x Structures, systems and components (SSCs), operational characteristics affected by the application and how these are implemented in the PRA model.
x A definition of the acceptance criteria used for the application.
: 2. Identify the scope of risk contributors addressed by the PRA model.
x If not full scope (i.e., internal and external), identify appropriate compensatory measures or provide bounding arguments to address the risk contributors not addressed by the model.
: 3. Summarize the risk assessment methodology used to assess the risk of the application.
x Include how the PRA model was modified to appropriately model the risk impact of the change request.
: 4. Demonstrate the Technical Adequacy of the PRA.
x Identify plant changes (design or operational practices) that have been incorporated at the site, but are not yet in the PRA model and justify why the change does not impact the PRA results used to support the application.
x Document peer review findings and observations that are applicable to the parts of the PRA required for the application, and for those that have not yet been addressed justify why the significant contributors would not be impacted.
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Documentation of Probabilistic Risk Assessment Technical Adequacy Page 3 of 11 x  Document that the parts of the PRA used in the decision are consistent with applicable standards endorsed by the Regulatory Guide (currently RG 1.200, Revision 1). Provide justification to show that where specific requirements in the standard are not adequately met, it will not unduly impact the results.
Because of the broad scope of potential Technical Specifications Initiative 5b applications and the fact that the impact of such assumptions differs from application to application, each of the issues encompassed in Items 1 through 3 will be covered with the preparation of each individual PRA assessment made in support of the individual STI interval requests. The purpose of the remaining portion of this appendix is to address the requirements identified in item 4 above.
Columbia PRA Technical Adequacy Introduction Adoption of TSTF-425 requires the utility to ensure that the Probabilistic Risk Assessment (PRA - commonly identified as Probabilistic Safety Assessment (PSA) at Columbia is technically adequate and meets the requirements of Regulatory Guide (RG) 1.200, Revision. 1, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities." Evaluation of risks will be completed using qualitative or quantitative methods for external events or fire risk in accordance with NEI 04-10, Revision 1.
The NRC has previously reviewed the Columbia PSA for technical adequacy as part of the approval for License Renewal. By letter dated January 19, 2010, Energy Northwest submitted an application to the NRC to issue a renewed operating license for Columbia for an additional 20 years. As part of this submittal, Columbia submitted an assessment of Severe Accident Mitigation Alternatives (SAMAs), based on what was then the most recent Columbia PSA (Revision 6.2). During the NRC review of the SAMAs, the NRC issued requests for additional information (RAIs), and Columbia responded to the requests. Also during this review process, the PSA was updated from Revision 6.2 to Revision 7.1. As part of the responses to the RAIs, Columbia provided updated PSA information to the NRC based on PSA Revision 7.1. The PSA Revision 7.1 model incorporated the following:
x  Resolution of Facts and Observations (F&Os) from the 2004 peer review; x  Resolution of areas of model incompleteness identified by Columbia internal technical reviews; x  Upgrades to meet NRC RG 1.200, Revision 2 and the associated ASME Standard RA-S-2008 for Level 1, LERF, and flooding modeling; and x  Other plant and procedure changes.
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Documentation of Probabilistic Risk Assessment Technical Adequacy Page 4 of 11 The above changes were first incorporated in the PSA Revision 7.0 model, for which a peer review was performed on Level 1 and 2 internal events (with internal flooding) in 2009 and a report was issued in January 2010. The F&Os from this peer review that could significantly impact the model quantification were incorporated into the Revision 7.1 model, and a review of the remaining F&Os associated with supporting requirements (SRs) that were graded as CC-1 or not met identified none that would significantly impact the results of the SAMA analysis.
The NRC reviewed the information provided by Columbia concerning the internal events PSA model, seismic PSA model, Fire PSA model, and "other" external events PSA model. This review is documented in NUREG-1437, Supplement 47, Volume 1, "Generic Environmental Impact Statement for the License Renewal pf Nuclear Plants Regarding Columbia Generating Station" (ADAMS Accession No. ML12096A334). The information regarding PSA revisions 6.2, 7.0, and 7.1 are included in NUREG-1437, Supplement 47, Volume 1, Section 5.3.2. In addition, the following statements of acceptability of the Columbia PSA model were made by the NRC in Section 5.3.2.
Internal Events "The Columbia internal events model has been peer-reviewed, the peer findings were all resolved and their impact assessed in a sensitivity analysis using the updated PSA model, and Energy Northwest has satisfactorily addressed NRC staff questions regarding the PSA. Based on this information, the NRC staff concludes that the internal events Level 1 PSA model is of sufficient quality to support the SAMA evaluation."
Seismic "The Columbia internal events modeling is an input to the seismic PSA model, the seismic PSA has been updated to a more recent external events PSA standard, the SAMA evaluation included a sensitivity analysis of the seismic CDF, and Energy Northwest has satisfactorily addressed NRC staff RAIs regarding the seismic PSA.
Based on this information, the NRC staff concludes that the seismic PSA model in combination with the sensitivity analysis of the seismic CDF provides an acceptable basis for identifying and evaluating the benefits of SAMA."
Fire "The Columbia internal events modeling is an input to the Fire PSA model, has been updated to incorporate industry fire data and NRC guidance, the fire PSA has been peer reviewed and the peer review findings were all addressed, and Energy Northwest has satisfactorily addressed NRC staff RAIs regarding the fire PSA.
Based on this information, the NRC staff concludes that the fire PSA model provides an acceptable basis for identifying and evaluating the benefits of SAMAs."
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Documentation of Probabilistic Risk Assessment Technical Adequacy Page 5 of 11 "Other" External Events "The NRC staff reviewed the Level 2 methodology and found that Energy Northwest adequately addressed NRC staff RAIs, the Level 2 PSA model was reviewed in more detail as part of the 1997 and 2004 peer reviews, and the findings from these peer reviews have been resolved and their impact assessed in a sensitivity analysis using the updated PSA model. Based on this information, the NRC staff concludes that the level 2 PSA provides an acceptable basis for evaluating the benefits associated with various SAMAs."
Columbia has recently updated the PSA internal events model to Revision 7.2. Based on the previous NRC review and acceptability of the Columbia PSA Revision 7.1 model, the remainder of this Attachment includes a general description of the PSA model and those changes from PSA Revision 7.1 to PSA Revision 7.2, and the basis for the technical adequacy of these changes.
General Description of the Columbia PSA Model The Columbia PSA is performed in accordance with the Capability Category II requirements of ASME / ANS Standard, as clarified by Regulatory Guide 1.200. The PSA is a full scope PSA (the shutdown PSA and the external events including earthquakes, fires and winds are reported elsewhere and not discussed in this section) which uses a Level 1 analysis to model core damage frequencies and a Level 2 analysis to model containment performance characteristics during severe accidents. In the Level 1 analysis, a mission time of 24 hours was generally assumed for all equipment which plays a role in providing core protection functions after a transient and in the Level 2 analysis, a period of up to 40 hours was used to simulate and monitor predictions of containment performance following the occurrence of an accident sequence initiating event. The phenomenological uncertainties embodied in the Level 2 analysis were held to a minimum by using referenced assumptions wherever possible.
The final results of the containment performance assessment are presented as "best point estimates."
The Columbia PSA uses the "large fault tree/small event tree" approach to identify and quantify individual accident sequences. With this approach, functionally descriptive event trees are used to model the possible accident sequences which result in core damage, and initiatorspecific containment event trees are used to represent possible containment behavior following a core melt accident. Detailed system fault trees are merged to quantify individual event tree sequences in both the Level 1 and Level 2 analyses. The CAFTA and PRAQuant computer codes are used to perform the quantification and both the RETRAN and MAAP computer codes were used to characterize plant, containment, and fission product behavior.
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Documentation of Probabilistic Risk Assessment Technical Adequacy Page 6 of 11 The effects of common cause failures are included as basic events in the Columbia system fault trees and are quantified by the alpha factor method. This method provides a numerical estimate for the common cause failure probability which should be assigned to account for the likelihood that the plant would experience simultaneous failures of two or more identical components in a single train or multiple trains in a single system.
To ensure that the role of the operating staff is fully credited by the analysis, pre accident and majority of the postaccident human actions were explicitly modeled in the detailed system fault trees, and recovery actions were linked to the functional headings in the event trees. A plant specific human reliability analysis (HRA) is used to predict preaccident and postaccident human error probabilities for each of the modeled human actions. The potential dependencies between multiple operator actions performed in accident sequences modeled by the PSA have been evaluated and modeled. The HRA dependency evaluation examines potential influences on the failure likelihood for a task from the failure or success of the immediately preceding task.
The Level 1 and Level 2 PSA analyses were performed following the methodology and major tasks as described in NUREG/CR2300, "PSA Procedures Guide" for Level 1 and Level 2 PSA. The major Level 1 tasks include information gathering of plant specific data, P&IDs, test, maintenance, operating procedures, and physical room, containment, and building information. The system analysis methodology utilizes the small event tree
/ large fault tree approach. The event trees combine the initiating event with system functional successes or failures to delineate the accident sequences. The fault trees are developed to the component, relay, and sensor level of detail. The system modeling includes human reliability and common cause failure events, utilizing plant specific failure data to the extent possible. The human reliability analysis (HRA) primarily utilizes the Cause-Based Decision Tree (CBDTM) methodology to estimate cognitive error probabilities for actions not constrained by timing, and the Human Cognitive Reliability/Operator Reliability Experiments (HCR/ORE) methodology for time constrained actions, and Technique for Human Error rate Predication (THERP) to estimate execution error probabilities. Common cause modeling is performed with the alpha factor method utilizing data from the NRC Parameter Estimation database. The PSA is quantified using the CAFTA and PRAQuant computer codes.
The Level 2 tasks include grouping the Level 1 sequences into several bins or plant damage states, characterizing containment failure modes and locations, developing and quantifying logic trees and containment event trees, determining the magnitude of the radionuclide release, and performing sensitivity studies. The MAAP computer program was used to provide an integrated approach for modeling of plant thermal hydraulic response and fission product transport during severe accidents. In addition, research results in the open literature, Industry Degraded Core Rulemaking Group (IDCOR) task reports, the Shoreham and Limerick PRAs, NUREGs, and engineering judgment were used in understanding accident progression and quantifying event trees.
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Documentation of Probabilistic Risk Assessment Technical Adequacy Page 7 of 11 The Level 1 analysis is coupled with the Level 2 analysis through the binning of the multitude of the Level 1 sequences into several groups of plant damage states with similar Level 2 characteristics. Results of a structural analysis performed for Columbia are used to assess containment strength, failure size and location. MAAP calculations, analytical models, and widely accepted research results are employed in the accident progression analysis. Based on this information, containment event trees and logic trees were developed to provide a description of the containment damage states. The containment event trees were quantified using the CAFTA and PRAQuant codes. The end states of the containment event trees were then grouped into a limited but complete set of unique release categories. Representative MAAP calculations include Large Early Release Frequency (LERF) were performed to provide an estimate of the fission product release to the environment. Finally, a sensitivity analysis was performed to investigate important parameters that could have large impact on the likelihood or time of containment failure and the magnitude of the source term. The results were used to identify the areas for which potential improvements of the plant might be considered.
Because of the consistency throughout the process and the linking and merging capabilities of the CAFTA and PRAQuant codes, dependencies, common cause effects, and system interaction are accounted for by the PSA.
CAFTA and PRAQuant, PCbased programs developed by Electric Power Research Institute (EPRI), are used to quantify the Level 1 and Level 2 accident sequences.
CAFTA is used to convert the systemlevel fault trees into a single master fault tree that solves all event tree sequences from a single top gate (specifically, one top gate for the Level 1 solution, and one top gate for the Level 2 solution).
Verification of the CAFTA results was performed by installing the software on inhouse PCs, its fault tree and sequence results were checked against a CAFTA sample quantification. They were found to be identical. CAFTA has been verified and validated in accordance with Energy Northwest's computer code Verification and Validation procedure.
Changes from PSA Revision 7.1 to PSA Revision 7.2 x  PRA Update - Update to the current as-built, as-operated plant, this included incorporation of outstanding Engineering Changes, current procedure revisions, and new reliability information. Also included in the update of the PRA model to Rev 7.2, was Revision 3 of Emergency Operating Procedures/Severe Accident Guidelines that were approved and implemented for addressing Fukushima lessons learned.
x  Conversion from WINUPRA computer code to CAFTA computer code.
Reconciled all cutsets to Rev. 7.1 event tree model above the Rev. 7.1 truncation level, 5E-12 (55,000+ cutsets). By reconciling the cutsets this provides a high
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Documentation of Probabilistic Risk Assessment Technical Adequacy Page 8 of 11 level of confidence in the conversion necessary for PRA applications and ensured continued support of Capability Category II.
x  Resolved 109 of 131 self-assessment including peer review comments accumulated over the last 5 years. The two open findings from the 2009 peer review remain open with this minor update. This effort addresses comments /
suggestions judged to be medium-or-higher priority, with the highest priority applied to the items addressing modeling enhancements. Additional suggestions and self-assessment findings that are documentation-related were postponed based upon risk impact. Resolving these open comments /
suggestions improved model realism to further support PSA Capability Category II. The two open Findings are discussed in the table below (Table 1) and the impacts identified.
x  Discovered and corrected support system dependency modeling in motor control center heating and ventilation including containment venting.
x  Credited and modeled a new operator action - Manual containment vent (MAN-VENTFAIL) x  Updated the HRA dependency analysis to utilize the HRA Calculator dependency module. This update was needed to assess dependence for the new HFE added to the model for manual containment vent, as well as include risk-significant dependent combinations missing in Rev. 7.1 (300 cutsets were reviewed for dependent HFE combinations in Rev. 7.1 versus 1.3 million cutsets in Rev. 7.2).
x  Updated the HRA Calculator development to utilize the CBDTM or human cognitive reliability / operator reliability experiment methods to estimate cognitive human error probabilities, rather than the combination sum (CBDTM + ASEP) approach, which follows industry and NRC guidance consensus.
These changes to the modeling were specifically focused on aligning the PSA model with the as built and as operated facility. It improved the realism of the PRA model and with the incorporation of the outstanding changes and addressing open suggestions and findings resolved issues that had been identified with the model.
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-
425, REVISION 3  - Documentation of Probabilistic Risk Assessment Technical Adequacy Page 9 of 11 Table 1 - Open Findings F&O Resolved Source 2009 SR        Level      Observations              Recommendations        Impact 2-2  Open      PR      DA-C6    Finding    The number of plant-      Update the estimates  As a sensitivity, the base data 2009                          specific demands on      for significant events for these failure modes were standby components was    based on surveillance  replaced by the following mainly documented for    test and maintenance  generic data (NUREG/CR-the maintenance rule and  records.              6928) and the model was MSPI components. Tier                            quantified. This change in 3 PSA documents for                              data produces a bounding PSA-2-DA-0002 show the                          delta CDF increase of 2%,
details. Estimates based                        which is a risk-significant on the surveillance tests                        difference, but relatively and maintenance acts as                          unlikely to change the described in this SR                            conclusions of risk-informed should be performed                              decisions. However, until this even though the major                            F&O finding is resolved, PRA components have been                            applications will perform this included in the MSPI                            sensitivity analysis to data.                                            examine whether the application is impacted.
Estimates based on the                          C---W2 = 9.2E-5/hr surveillance tests and                          (compressor loss of function) maintenance acts as                              C---W4 = 9.2E-5/hr described in DA-C6 and                          (compressor loss of function)
DA-C7 should be FN--R3 = 4.6E-3 (fan fails to performed for significant start) components whose data are not tracked in the                          FN--W4 = 1.1E-5/hr (fan fails MSPI data.                                      to run)
AHUSS3 = 1.2E-3 (standby (This F&O originated from                        air handling unit fails to start)
SR DA-C6)                                        AHURW4 = 1.4E-5/hr (running air handling unit fails to run)
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-
425, REVISION 3  - Documentation of Probabilistic Risk Assessment Technical Adequacy Page 10 of 11 F&O Resolved Source 2009 SR        Level      Observations              Recommendations        Impact 2-14 Open      PR      SY-A4    Finding    Interviews with plant      Perform and            SY-A4 only meets Capability 2009                          system engineers or        document the          Category I due to this open operators have not been    interviews with the    finding. Until this F&O finding documented and cannot      system engineers      is resolved, PRA applications be verified by the peer    and/or operators to    will perform this sensitivity review team. Original      confirm that the      analysis to examine whether interviews were            systems analysis      the application is impacted..
performed for the original correctly reflects the IPE.                      as-built, as-operated plant. It may be System and operations      reasonable to develop change over time, and      a process that, the system engineers and following an initial operators should be        interviews, the consulted with regard to  confirmation the the system models.        model matches the as-built, as-operated (This F&O originated from plant is confirmed SR SY-A4)                  through review or discussion with the system engineers -
typically through a periodic review of the notebook performed in accordance with plant procedures.
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Documentation of Probabilistic Risk Assessment Technical Adequacy Page 11 of 11 Conclusion Based on the above information, Energy-Northwest believes that the quality of the current PSA is sufficient to support Adoption of TSTF-425 and the remaining open F&Os do not unduly impact the result.
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TSTF - 425, REVISION 3  - Markup of Proposed Technical Specification Pages Page 1 of 1 MARKUP OF PROPOSED TECHNICAL SPECIFICATION PAGES 3.1.3-4      3.3.4.1-2    3.6.1.1-2      3.8.1-11 3.1.4-2      3.3.4.1-3    3.6.1.1-3      3.8.1-12 3.1.5-3      3.3.4.2-2    3.6.1.2-4      3.8.1-13 3.1.6-2      3.3.4.2-3    3.6.1.3-6      3.8.1-14 3.1.7-1      3.3.5.1-5    3.6.1.3-7      3.8.1-15 3.1.7-2      3.3.5.2-3    3.6.1.3-8      3.8.1-16 3.1.7-3      3.3.6.1-3    3.6.1.4-1      3.8.3-2 3.1.8-2      3.3.6.1-4    3.6.1.5-1      3.8.3-3 3.2.1-1      3.3.6.2-2    3.6.1.6-2      3.8.4-4 3.2.2-1      3.3.7.1-2    3.6.1.7-2      3.8.6-3 3.2.3-1      3.3.8.1-2    3.6.2.1-3      3.8.6-4 3.2.4-2      3.3.8.2-2    3.6.2.2-1      3.8.7-2 3.3.1.1-2    3.3.8.2-3    3.6.2.3-1      3.8.8-2 3.3.1.1-3    3.4.1-2      3.6.3.2-1      3.9.1-1 3.3.1.1-4    3.4.1-4      3.6.3.3-1      3.9.2-1 3.3.1.1-5    3.4.2-2      3.6.4.1-2      3.9.3-1 3.3.1.1-11    3.4.3-1      3.6.4.2-3      3.9.5-1 3.3.1.1-12    3.4.4-2      3.6.4.3-2      3.9.6-1 3.3.1.1-13    3.4.5-2      3.7.1-2        3.9.7-1 3.3.1.1-14    3.4.7-3      3.7.1-3        3.9.8-2 3.3.1.2-2    3.4.8-2      3.7.2-1        3.9.9-2 3.3.1.2-3    3.4.9-2      3.7.3-3        3.10.2-2 3.3.1.2-4    3.4.10-2    3.7.4-2        3.10.3-3 3.3.1.3-2    3.4.11-2    3.7.5-2        3.10.4-3 3.3.2.1-3    3.4.11-4    3.7.6-1        3.10.5-2 3.3.2.1-4    3.4.12-1    3.7.7-1        3.10.6-2 3.3.2.1-9    3.5.1-3      3.8.1-5        3.10.8-3 3.3.2.1-10    3.5.1-4      3.8.1-6        3.10.8-7 3.3.2.2-2    3.5.1-5      3.8.1-7        5.5-11 3.3.3.1-2    3.5.2-2      3.8.1-8 3.3.3.2-1    3.5.2-3      3.8.1-9 3.3.3.2-2    3.5.3-2      3.8.1-10
 
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      -------------------------------NOTE------------------------------          In accordance Not required to be performed until 31 days after the                          with the control rod is withdrawn and THERMAL POWER is                              Surveillance greater than the LPSP of the RWM.                                            Frequency
                  ---------------------------------------------------------------------    Control Program Insert each partially withdrawn control rod at least                  31 days one notch.
SR 3.1.3.3      Verify each control rod scram time from fully                          In accordance withdrawn to notch position 5 is d 7 seconds.                          with SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4 SR 3.1.3.4      Verify each control rod does not go to the withdrawn                  Each time the overtravel position.                                                  control rod is withdrawn to "full out" position AND Prior to declaring control rod OPERABLE after work on control rod or CRD System that could affect coupling Columbia Generating Station                      3.1.3-4              Amendment No. 212,216 225
 
Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS
------------------------------------------------------------NOTE-----------------------------------------------------------
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 t 800 psig.                                                              each reactor shutdown 
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 t 800 psig.                                                              MODE 1 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 SR 3.1.4.4                Verify each affected control rod scram time is within                    Prior to exceeding the limits of Table 3.1.4-1 with reactor steam dome                      40% RTP after pressure t 800 psig.                                                    fuel movement within the affected core cell AND Prior to exceeding 40% RTP after work on control rod or CRD System that could affect scram time In accordance with the Surveillance Frequency Control Program Columbia Generating Station                                3.1.4-2              Amendment No. 194,211 225
 
Control Rod Scram Accumulators 3.1.5 ACTION CONDITION                      REQUIRED ACTION                        COMPLETION TIME C. One or more control rod    C.1    Verify the associated                Immediately upon scram accumulators                  control rod is fully inserted.        discovery of charging inoperable with reactor                                                  water header steam dome pressure                                                      pressure < 940 psig
    < 900 psig.
AND C.2    Declare the associated                1 hour control rod inoperable.
D. Required Action B.1 or      D.1    ---------------NOTE--------------
C.1 and associated                  Not applicable if all Completion Time not                inoperable control rod met.                                scram accumulators are associated 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 days is t 940 psig.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.1.5-3              Amendment No. 169,216 225
 
Rod Pattern Control 3.1.6 ACTIONS CONDITION                  REQUIRED ACTION              COMPLETION TIME B (continued)                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      24 hours BPWS.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station            3.1.6-2          Amendment No. 149,169 225
 
SLC System 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7      Standby Liquid Control (SLC) System LCO 3.1.7            Two SLC subsystems shall be OPERABLE.
APPLICABILITY:        MODES 1, 2, and 3.
ACTIONS CONDITION                        REQUIRED ACTION              COMPLETION TIME A. One SLC subsystem            A.1      Restore SLC subsystem to    7 days inoperable.                          OPERABLE status.
B. Two SLC subsystems            B.1      Restore one SLC              8 hours inoperable.                          subsystem to OPERABLE status.
C. Required Action and          C.1      Be in MODE 3.                12 hours associated Completion Time not met.              AND C.2      Be in MODE 4.                36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.1.7.1        Verify available volume of sodium pentaborate          24 hours solution is t 4587 gallons.
SR 3.1.7.2        Verify temperature of sodium pentaborate solution is  24 hours within the limits of Figure 3.1.7-1.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                  3.1.7-1      Amendment No. 169,199 225
 
SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                        FREQUENCY SR 3.1.7.3      Verify continuity of explosive charge.                    31 days SR 3.1.7.4      Verify the concentration of boron in solution is within  31 days the limits of Figure 3.1.7-1.
AND Once within 24 hours after water or boron is added to solution AND Once within 24 hours after solution temperature is restored within the limits of Figure 3.1.7-1 SR 3.1.7.5      Verify each SLC subsystem manual and power                31 days operated 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 3.1.7.6      Verify each pump develops a flow rate t 41.2 gpm          In accordance at a discharge pressure t 1220 psig.                      with the Inservice Testing Program SR 3.1.7.7      Verify flow through one SLC subsystem from pump          24 months on a into reactor pressure vessel.                            STAGGERED TEST BASIS In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.1.7-2        Amendment No. 169,199 225
 
SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.1.7.8      Verify all heat traced piping between storage tank      24 months and pump suction valve is unblocked.
AND Once within 24 hours after solution temperature is restored within the limits of Figure 3.1.7-1 SR 3.1.7.9      Verify sodium pentaborate enrichment is t 44.0          Prior to addition to atom percent B-10.                                      SLC Tank In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.1.7-3        Amendment No. 199,221 225
 
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
: a. Closes in d 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 with the Surveillance Frequency Control Program Columbia Generating Station                      3.1.8-2              Amendment No. 149,169 225
 
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 t 25% RTP.
ACTIONS CONDITION                      REQUIRED ACTION                COMPLETION TIME A. Any APLHGR not within        A.1      Restore APLHGR(s) to        2 hours limits.                              within limits.
B. Required Action and          B.1      Reduce THERMAL              4 hours associated Completion                POWER to < 25% 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 t 25% RTP AND 24 hours thereafter In accordance with the Surveillance Frequency Control Program Columbia Generating Station                  3.2.1-1      Amendment No. 149,169 225
 
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 t 25% 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              4 hours associated Completion                POWER to < 25% 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 t 25% RTP AND 24 hours thereafter In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.2.2-1      Amendment No. 169,211 225
 
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 t 25% 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                    4 hours associated Completion              POWER to < 25% 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 t 25% RTP AND 24 hours thereafter In accordance with the Surveillance Frequency Control Program Columbia Generating Station                  3.2.3-1          Amendment No. 149,169 225
 
APRM Gain and Setpoint (Prior to Implementation of PRNM Upgrade) 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.2.4.1      -------------------------------NOTE------------------------------
Not required to be met if SR 3.2.4.2 is satisfied for LCO 3.2.4.b or LCO 3.2.4.c requirements.
Verify MFLPD is within limits.                                        Once within 12 hours after t 25% RTP AND 24 hours thereafter SR 3.2.4.2      -------------------------------NOTE------------------------------
Not required to be met if SR 3.2.4.1 is satisfied for LCO 3.2.4.a requirements.
Verify each required:                                                12 hours
: a. APRM Flow Biased Simulated Thermal Power -
High Function Allowable Value is modified by                      In accordance greater than or equal to the ratio of FRTP and                        with the the MFLPD; or                                                      Surveillance Frequency
: b. APRM gain is adjusted such that the APRM                          Control Program reading is t 100% times MFLPD.
Columbia Generating Station                      3.2.4-2              Amendment No. 169 225 226
 
RPS Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME E. As required by Required                E.1        Reduce THERMAL                          4 hours Action D.1 and                                  POWER to < 30% RTP.
referenced in Table 3.3.1.1-1.
F. As required by Required                F.1        Be in MODE 2.                            6 hours Action D.1 and referenced in Table 3.3.1.1-1.
G. As required by Required                G.1        Be in MODE 3.                            12 hours Action D.1 and referenced in Table 3.3.1.1-1.
H. As required by Required                H.1        Initiate action to fully insert          Immediately Action D.1 and                                  all insertable control rods in referenced in                                  core cells containing one or Table 3.3.1.1-1.                                more fuel assemblies.
SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTES----------------------------------------------------------
: 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.                                                  12 hours In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.1.1-2              Amendment No. 169 225 226
 
RPS Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.3.1.1.2    -------------------------------NOTE------------------------------
Not required to be performed until 12 hours after THERMAL POWER t 25% RTP.
Verify the absolute difference between the average                    7 days power range monitor (APRM) channels and the calculated power d 2% RTP plus any gain adjustment required by LCO 3.2.4, "Average Power Range Monitor (APRM) Gain and Setpoint," while operating at t 25% RTP.
SR 3.3.1.1.3    -------------------------------NOTE------------------------------    In accordance with the Not required to be performed when entering                                  Surveillance MODE 2 from MODE 1 until 12 hours after entering                        Frequency Control MODE 2.                                                                      Program Perform CHANNEL FUNCTIONAL TEST.                                      7 days SR 3.3.1.1.4    Perform CHANNEL FUNCTIONAL TEST.                                      7 days SR 3.3.1.1.5    Verify the source range monitor (SRM) and                            Prior to intermediate range monitor (IRM) channels overlap.                    withdrawing SRMs from the fully inserted position SR 3.3.1.1.6    -------------------------------NOTE------------------------------
Only required to be met during entry into MODE 2 from MODE 1.
Verify the IRM and APRM channels overlap.                            7 days SR 3.3.1.1.7    Calibrate the local power range monitors.                            1130 MWD/T average core exposure Columbia Generating Station                    3.3.1.1-3              Amendment No. 169 225 226
 
RPS Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.3.1.1.8    Perform CHANNEL FUNCTIONAL TEST.                                      92 days SR 3.3.1.1.9    ------------------------------NOTES-----------------------------
: 1. Neutron detectors are excluded.                                      In accordance with the Surveillance Frequency
: 2. For Function 2.a, not required to be performed                      Control Program when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2.
Perform CHANNEL CALIBRATION.                                          184 days SR 3.3.1.1.10    ------------------------------NOTES-----------------------------
: 1. Neutron detectors are excluded.
: 2. For Function 1, not required to be performed when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2.
Perform CHANNEL CALIBRATION.                                          18 months for Functions 1 through 4, 6, 7, and 9 through 11 AND 24 months for Functions 5 and 8 SR 3.3.1.1.11    Verify the APRM Flow Biased Simulated Thermal                        18 months Power - High Function time constant is d 7 seconds.
SR 3.3.1.1.12    Verify Turbine Throttle Valve - Closure, and Turbine                  18 months Governor Valve Fast Closure Trip Oil Pressure -
Low Functions are not bypassed when THERMAL POWER is t 30% RTP.
SR 3.3.1.1.13    Perform CHANNEL FUNCTIONAL TEST.                                      24 months Columbia Generating Station                    3.3.1.1-4              Amendment No. 169 225 226
 
RPS Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.3.1.1.14    Perform LOGIC SYSTEM FUNCTIONAL TEST.                                    24 months SR 3.3.1.1.15    ------------------------------NOTES-----------------------------
1 Neutron detectors are excluded.
: 2. Channel sensors for Functions 3 and 4 are excluded.
: 3. For Function 5, "n" equals 4 channels for the purpose of determining the STAGGERED TEST BASIS Frequency.
Verify the RPS RESPONSE TIME is within limits.                          24 months on a STAGGERED TEST BASIS In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.3.1.1-5              Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME I. As required by Required              I.1        Initiate alternate method to            12 hours Action D.1 and                                  detect and suppress referenced in                                  thermal hydraulic instability Table 3.3.1.1-1.                                oscillations.
AND
                                                      ---------------NOTE-------------
LCO 3.0.4 is not applicable.
I.2        Restore required channels                120 days to OPERABLE J. Required Action and                    J.1        Reduce THERMAL                          4 hours associated Completion                          POWER to less than the Time of Condition I not                        value specified in the met.                                            COLR.
SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTES----------------------------------------------------------
: 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.                                                  12 hours In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.1.1-11              Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.3.1.1.2    -------------------------------NOTE------------------------------
Not required to be performed until 12 hours after THERMAL POWER t 25% RTP.
Verify the absolute difference between the average                    7 days power range monitor (APRM) channels and the calculated power d 2% RTP while operating at t 25% RTP.
SR 3.3.1.1.3    -------------------------------NOTE------------------------------      In accordance with the Not required to be performed when entering                                    Surveillance MODE 2 from MODE 1 until 12 hours after entering                          Frequency Control MODE 2.                                                                        Program Perform CHANNEL FUNCTIONAL TEST.                                      7 days SR 3.3.1.1.4    Perform CHANNEL FUNCTIONAL TEST.                                      7 days SR 3.3.1.1.5    Verify the source range monitor (SRM) and                            Prior to intermediate range monitor (IRM) channels overlap.                    withdrawing SRMs from the fully inserted position SR 3.3.1.1.6    -------------------------------NOTE------------------------------
Only required to be met during entry into MODE 2 from MODE 1.
Verify the IRM and APRM channels overlap.                            7 days SR 3.3.1.1.7    Calibrate the local power range monitors.                            1130 MWD/T average core exposure Columbia Generating Station                    3.3.1.1-12            Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.3.1.1.8    Perform CHANNEL FUNCTIONAL TEST.                                      92 days SR 3.3.1.1.9    Deleted.
SR 3.3.1.1.10    ------------------------------NOTES-----------------------------
: 1. Neutron detectors are excluded.
In accordance with the
: 2. For Function 1, not required to be performed                      Surveillance Frequency when entering MODE 2 from MODE 1 until                                Control Program 12 hours after entering MODE 2.
: 3. For Functions 2.b and 2.f, the recirculation flow transmitters that feed the APRMs are included.
Perform CHANNEL CALIBRATION.                                          18 months for Functions 1, 3, 4, 6, 7, and 9 through 11 AND 24 months for Functions 2, 5, and 8 SR 3.3.1.1.11    Deleted.
SR 3.3.1.1.12    Verify Turbine Throttle Valve - Closure, and Turbine                  18 months Governor Valve Fast Closure Trip Oil Pressure -
Low Functions are not bypassed when THERMAL POWER is t 30% RTP.
SR 3.3.1.1.13    Perform CHANNEL FUNCTIONAL TEST.                                      24 months Columbia Generating Station                    3.3.1.1-13            Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.3.1.1.14    Perform LOGIC SYSTEM FUNCTIONAL TEST.                                24 months SR 3.3.1.1.15    ------------------------------NOTES-----------------------------
: 1. Neutron detectors are excluded.
: 2. Channel sensors for Functions 3 and 4 are excluded.
: 3. For Function 5, "n" equals 4 channels for the purpose of determining the STAGGERED TEST BASIS Frequency.
: 4. For Function 2.e, "n" equals 8 channels for the purpose of determining the STAGGERED TEST BASIS Frequency. Testing of APRM and oscillation power range monitor (OPRM) outputs shall alternate.
Verify the RPS RESPONSE TIME is within limits.                        24 months on a STAGGERED TEST BASIS SR 3.3.1.1.16    ------------------------------NOTES-----------------------------      In accordance with the
: 1. For Function 2.a, not required to be performed                      Surveillance Frequency when entering MODE 2 from MODE 1 until 12                          Control Program hours after entering MODE 2.
: 2. For Functions 2.b and 2.f, the CHANNEL FUNCTIONAL TEST includes the recirculation flow input processing, excluding the flow transmitters.
Perform CHANNEL FUNCTIONAL TEST.                                      184 days SR 3.3.1.1.17    Verify the OPRM is not bypassed when APRM                            24 months Simulated Thermal Power is greater than or equal to the value specified in the COLR and recirculation drive flow is less than the value specified in the COLR.
Columbia Generating Station                    3.3.1.1-14            Amendment No. 169 225 226
 
SRM Instrumentation 3.3.1.2 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME E. One or more required                  E.1        Suspend CORE                            Immediately SRMs inoperable in                              ALTERATIONS except for MODE 5.                                        control rod insertion.
AND E.2        Initiate action to fully insert          Immediately all insertable control rods in core cells containing one or more fuel assemblies.
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 In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.1.2-2              Amendment No. 149,169 225
 
SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY 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:                        12 hours
: 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 SR 3.3.1.2.4    -------------------------------NOTE------------------------------
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. t 3.0 cps with a signal to noise ratio t 2:1 or                  ALTERATIONS
: b. t 0.7 cps with a signal to noise ratio t 20:1.                  AND 24 hours In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.3.1.2-3              Amendment No. 149,169 225
 
SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.3.1.2.5    -------------------------------NOTE------------------------------
The determination of signal to noise ratio is 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.
Perform CHANNEL FUNCTIONAL TEST and                                    7 days determination of signal to noise ratio.
SR 3.3.1.2.6    -------------------------------NOTE------------------------------
Not required to be performed until 12 hours after IRMs on Range 2 or below.
Perform CHANNEL FUNCTIONAL TEST and                                    31 days determination of signal to noise ratio.
SR 3.3.1.2.7    ------------------------------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.                                          18 months In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.3.1.2-4              Amendment No. 149,169 225
 
OPRM Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.3 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 OPRM System maintains trip capability.
SURVEILLANCE                                                    FREQUENCY SR 3.3.1.3.1              Perform CHANNEL FUNCTIONAL TEST.                                        184 days SR 3.3.1.3.2              Calibrate the local power range monitors.                                1130 MWD/T average core exposure SR 3.3.1.3.3              -------------------------------NOTE------------------------------
Neutron detectors are excluded.
Perform CHANNEL CALIBRATION.                                            24 months SR 3.3.1.3.4              Perform LOGIC SYSTEM FUNCTIONAL TEST.                                    24 months SR 3.3.1.3.5              Verify OPRM is not bypassed when THERMAL                                24 months POWER is t 30% RTP and core flow d 60% rated core flow.
SR 3.3.1.3.6              -----------------------------NOTE--------------------------------
Neutron detectors are excluded.
Verify the RPS RESPONSE TIME is within limits.                          24 months on a STAGGERED TEST BASIS In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.1.3-2              Amendment No. 171 225 226
 
Control Rod Block Instrumentation (Prior to Implementation of PRNM Upgrade) 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 an RBM 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              Perform CHANNEL FUNCTIONAL TEST.                                        92 days SR 3.3.2.1.2              -------------------------------NOTE------------------------------
Not required to be performed until 1 hour after any control rod is withdrawn at d 10% RTP in MODE 2.
Perform CHANNEL FUNCTIONAL TEST.                                        92 days SR 3.3.2.1.3              -------------------------------NOTE------------------------------
Not required to be performed until 1 hour after THERMAL POWER is d 10% RTP in MODE 1.
Perform CHANNEL FUNCTIONAL TEST.                                        92 days SR 3.3.2.1.4              -------------------------------NOTE------------------------------
Neutron detectors are excluded.
Verify the RBM is not bypassed:                                          92 days
: a. When THERMAL POWER is t 30% RTP; and
: b. When a peripheral control rod is not selected.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.2.1-3              Amendment No. 169 225 226
 
Control Rod Block Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.3.2.1.5    -------------------------------NOTE------------------------------
Neutron detectors are excluded.
Perform CHANNEL CALIBRATION.                                          92 days SR 3.3.2.1.6    Verify the RWM is not bypassed when THERMAL                          24 months POWER is d 10% RTP.
SR 3.3.2.1.7    -------------------------------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 3.3.2.1.8    Verify control rod sequences input to the RWM are                    Prior to declaring in conformance with BPWS.                                            RWM OPERABLE following loading of sequence into RWM In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.3.2.1-4              Amendment No. 169 225 226
 
Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) 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 an RBM 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              Perform CHANNEL FUNCTIONAL TEST.                                          184 days SR 3.3.2.1.2              -------------------------------NOTE------------------------------
Not required to be performed until 1 hour after any control rod is withdrawn at d 10% RTP in MODE 2.
Perform CHANNEL FUNCTIONAL TEST.                                        92 days SR 3.3.2.1.3              -------------------------------NOTE------------------------------
Not required to be performed until 1 hour after THERMAL POWER is d 10% RTP in MODE 1.
Perform CHANNEL FUNCTIONAL TEST.                                        92 days In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.2.1-9              Amendment No. 169 225 226
 
Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.3.2.1.4      -------------------------------NOTE------------------------------
Neutron detectors are excluded.
Verify the RBM is not bypassed:                                        24 months
: a. Low Power Range - Upscale Function is not bypassed when APRM Simulated Thermal Power is  28% and < 63% RTP and peripheral control rod is not selected.
: b. Intermediate Power Range - Upscale Function is not bypassed when APRM Simulated Thermal Power is  63% and < 83% RTP and peripheral control rod is not selected.
: c. High Power Range - Upscale Function is not bypassed when APRM Simulated Thermal Power is  83% and peripheral control rod is not selected.
SR 3.3.2.1.5      -------------------------------NOTE------------------------------
Neutron detectors are excluded.
Perform CHANNEL CALIBRATION.                                          24 months SR 3.3.2.1.6      Verify the RWM is not bypassed when THERMAL                          24 months POWER is d 10% RTP.
SR 3.3.2.1.7      -------------------------------NOTE------------------------------      In accordance with the Not required to be performed until 1 hour after                              Surveillance reactor mode switch is in the shutdown position.                          Frequency Control
                  ---------------------------------------------------------------------          Program Perform CHANNEL FUNCTIONAL TEST.                                      24 months SR 3.3.2.1.8      Verify control rod sequences input to the RWM are                    Prior to declaring in conformance with BPWS.                                            RWM OPERABLE following loading of sequence into RWM Columbia Generating Station                      3.3.2.1-10            Amendment No. 169 225 226
 
Feedwater and Main Turbine High Water Level Trip Instrumentation 3.3.2.2 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 feedwater and main turbine high water level trip capability is maintained.
SURVEILLANCE                                                      FREQUENCY SR 3.3.2.2.1            Perform CHANNEL CHECK.                                                    24 hours SR 3.3.2.2.2            Perform CHANNEL FUNCTIONAL TEST.                                          92 days SR 3.3.2.2.3            Perform CHANNEL CALIBRATION. The Allowable                                24 months Value shall be d 56.0 inches.
SR 3.3.2.2.4            Perform LOGIC SYSTEM FUNCTIONAL TEST,                                      24 months including valve actuation.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.2.2-2              Amendment No. 149,169 225
 
PAM Instrumentation 3.3.3.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME E. As required by Required                E.1        Be in MODE 3.                            12 hours Action D.1 and referenced in Table 3.3.3.1-1.
F. As required by Required                F.1        Initiate action in accordance            Immediately Action D.1 and                                  with Specification 5.6.4.
referenced in Table 3.3.3.1-1.
SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTES----------------------------------------------------------
: 1.        These SRs apply to each Function in Table 3.3.3.1-1.
: 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 other required channel(s) in the associated Function is OPERABLE.
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 for Functions 1,                              18 months 2, 4, 5, and 10.
SR 3.3.3.1.4            Perform CHANNEL CALIBRATION for                                          24 months Functions 3, 6, and 7.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.3.1-2              Amendment No.189,190 225
 
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
-----------------------------------------------------------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.
SURVEILLANCE                                                      FREQUENCY SR 3.3.3.2.1            Perform CHANNEL CHECK for each required                                  31 days instrumentation channel that is normally energized.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.3.2-1              Amendment No. 169,187 225
 
Remote Shutdown System 3.3.3.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.3.3.2.2    Perform CHANNEL CALIBRATION for each                    18 months required instrumentation channel, except the suppression pool water level instrumentation channel.
SR 3.3.3.2.3    Perform CHANNEL CALIBRATION for the                    24 months suppression pool water level instrumentation channel.
SR 3.3.3.2.4    Verify each required control circuit and transfer      24 months switch is capable of performing the intended functions.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station              3.3.3.2-2          Amendment No. 149,169 225
 
EOC-RPT Instrumentation 3.3.4.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME B. One or more Functions                  B.1        Restore EOC-RPT trip                    2 hours with EOC-RPT trip                              capability.
capability not maintained.                          OR AND                                  B.2        Apply the MCPR limit for                2 hours inoperable EOC-RPT as MCPR limit for                                  specified in the COLR.
inoperable EOC-RPT not made applicable.
C. Required Action and                    C.1        Remove the associated                    4 hours associated Completion                          recirculation pump from Time not met.                                  service.
OR C.2        Reduce THERMAL                          4 hours POWER to < 30% RTP.
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.                                          92 days In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.4.1-2              Amendment No. 149,169 225
 
EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.3.4.1.2.a  Perform CHANNEL CALIBRATION. The Allowable                              24 months Value shall be:
TTV - Closure: d 7% closed.
SR 3.3.4.1.2.b  Perform CHANNEL CALIBRATION. The Allowable                              18 months Value shall be:
TGV Fast Closure, Trip Oil Pressure - Low:
t 1000 psig.
SR 3.3.4.1.3    Verify TTV - Closure and TGV Fast Closure, Trip                        18 months Oil Pressure - Low Functions are not bypassed when THERMAL POWER is t 30% RTP.
SR 3.3.4.1.4    Perform LOGIC SYSTEM FUNCTIONAL TEST,                                  24 months including breaker actuation.
SR 3.3.4.1.5    -------------------------------NOTE------------------------------
Breaker arc suppression time may be assumed from the most recent performance of SR 3.3.4.1.6.
Verify the EOC-RPT SYSTEM RESPONSE TIME is                              24 months on a within limits.                                                          STAGGERED TEST BASIS SR 3.3.4.1.6    Determine RPT breaker arc suppression time.                            60 months In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.3.4.1-3              Amendment No. 149,169 225
 
ATWS-RPT Instrumentation 3.3.4.2 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME C. Both Functions with                    C.1        Restore ATWS-RPT trip                    1 hour ATWS-RPT trip                                  capability for one Function.
capability 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 for Reactor Vessel                                  12 hours Water Level - Low Low, Level 2 Function.
SR 3.3.4.2.2            Perform CHANNEL FUNCTIONAL TEST.                                          92 days SR 3.3.4.2.3            Perform CHANNEL CALIBRATION. The Allowable                                18 months Values shall be:
: a. Reactor Vessel Water Level - Low Low, Level 2:                      In accordance with the t -58 inches; and                                                          Surveillance Frequency Control
: b. Reactor Vessel Steam Dome Pressure - High:                                    Program d 1143 psig.
Columbia Generating Station                              3.3.4.2-2              Amendment No. 149,169 225
 
ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                          FREQUENCY SR 3.3.4.2.4    Perform LOGIC SYSTEM FUNCTIONAL TEST,        24 months including breaker actuation.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station              3.3.4.2-3 Amendment No. 149,169 225
 
ECCS Instrumentation 3.3.5.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME H. Required Action and                    H.1        Declare associated                      Immediately associated Completion                          supported feature(s)
Time of Condition B, C,                        inoperable.
D, E, F, or G not met.
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, and 3.g; and (b) for up to 6 hours for Functions other than 3.c, 3.f, and 3.g provided the associated Function or the redundant Function maintains ECCS initiation capability.
SURVEILLANCE                                                      FREQUENCY SR 3.3.5.1.1            Perform CHANNEL CHECK.                                                    12 hours SR 3.3.5.1.2            Perform CHANNEL FUNCTIONAL TEST.                                          92 days SR 3.3.5.1.3            Perform CHANNEL CALIBRATION.                                              92 days SR 3.3.5.1.4            Perform CHANNEL CALIBRATION.                                              18 months SR 3.3.5.1.5            Perform CHANNEL CALIBRATION.                                              24 months SR 3.3.5.1.6            Perform LOGIC SYSTEM FUNCTIONAL TEST.                                    24 months In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.5.1-5                Amendment No. 150,169 225
 
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 4; and (b) for up to 6 hours for Functions 1 and 3 provided the associated Function maintains RCIC initiation capability.
SURVEILLANCE                                                      FREQUENCY SR 3.3.5.2.1            Perform CHANNEL CHECK.                                                    12 hours SR 3.3.5.2.2            Perform CHANNEL FUNCTIONAL TEST.                                          92 days SR 3.3.5.2.3            Perform CHANNEL CALIBRATION.                                              18 months SR 3.3.5.2.4            Perform LOGIC SYSTEM FUNCTIONAL TEST.                                    24 months In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.5.2-3              Amendment No. 149,169 225
 
Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME I. As required by Required              I.1        Declare associated standby              1 hour Action C.1 and                                  liquid control (SLC) referenced in                                  subsystem inoperable.
Table 3.3.6.1-1.
OR I.2        Isolate the Reactor Water                1 hour Cleanup (RWCU) System.
J. As required by Required                J.1        Initiate action to restore              Immediately Action C.1 and                                  channel to OPERABLE referenced in                                  status.
Table 3.3.6.1-1.
OR J.2        Initiate action to isolate the          Immediately Residual Heat Removal (RHR) Shutdown Cooling (SDC) System.
SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTES----------------------------------------------------------
: 1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Primary Containment 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 isolation capability.
SURVEILLANCE                                                      FREQUENCY SR 3.3.6.1.1            Perform CHANNEL CHECK.                                                    12 hours SR 3.3.6.1.2            Perform CHANNEL FUNCTIONAL TEST.                                          92 days In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.6.1-3              Amendment No. 149,169 225
 
Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.3.6.1.3    Perform CHANNEL FUNCTIONAL TEST.                                      184 days SR 3.3.6.1.4    Perform CHANNEL CALIBRATION.                                          18 months SR 3.3.6.1.5    Perform CHANNEL CALIBRATION                                          24 months SR 3.3.6.1.6    Perform LOGIC SYSTEM FUNCTIONAL TEST.                                24 months SR 3.3.6.1.7    -------------------------------NOTE------------------------------
Channel sensors for Functions 1.a, 1.b, and 1.c are excluded.
Verify the ISOLATION SYSTEM RESPONSE TIME                            24 months on a is within limits.                                                    STAGGERED TEST BASIS In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.3.6.1-4              Amendment No. 150,169 225
 
Secondary Containment Isolation Instrumentation 3.3.6.2 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME C. (continued)                            C.2.1      Place the associated                    1 hour standby gas treatment (SGT) subsystem in operation.
OR C.2.2      Declare associated SGT                  1 hour subsystem inoperable.
SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTES----------------------------------------------------------
: 1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment 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 isolation capability.
SURVEILLANCE                                                      FREQUENCY SR 3.3.6.2.1            Perform CHANNEL CHECK.                                                    12 hours SR 3.3.6.2.2            Perform CHANNEL FUNCTIONAL TEST.                                          92 days SR 3.3.6.2.3            Perform CHANNEL CALIBRATION.                                              18 months SR 3.3.6.2.4            Perform LOGIC SYSTEM FUNCTIONAL TEST.                                      24 months In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.6.2-2              Amendment No. 149,169 225
 
CREF System Instrumentation 3.3.7.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME D. Required Action and                    D.1        Place associated CREF                    1 hour associated Completion                          subsystem in the Time of Condition B or C                        pressurization mode of not met.                                        operation.
OR D.2        Declare associated CREF                  1 hour subsystem inoperable.
SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTES----------------------------------------------------------
: 1. Refer to Table 3.3.7.1-1 to determine which SRs apply for each CREF 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 CREF initiation capability.
SURVEILLANCE                                                      FREQUENCY SR 3.3.7.1.1            Perform CHANNEL CHECK.                                                    12 hours SR 3.3.7.1.2            Perform CHANNEL FUNCTIONAL TEST.                                          92 days SR 3.3.7.1.3            Perform CHANNEL CALIBRATION.                                              18 months SR 3.3.7.1.4            Perform LOGIC SYSTEM FUNCTIONAL TEST.                                      24 months In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.7.1-2              Amendment No. 187,199 225
 
LOP Instrumentation 3.3.8.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME D. Required Action and                    D.1        Declare associated DG                    Immediately associated Completion                          inoperable.
Time of Condition B or C not met.                            OR
                                            --------------------NOTE-------------------
Only applicable for Functions 1.c and 1.d.
D.2.1      Open offsite circuit supply              Immediately breaker to associated 4.16 kV ESF bus.
AND D.2.2      Declare associated offsite              Immediately circuit inoperable.
In accordance with the Surveillance Frequency SURVEILLANCE REQUIREMENTS                                                                              Control Program
-----------------------------------------------------------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 initiation capability.
SURVEILLANCE                                                      FREQUENCY SR 3.3.8.1.1            Perform CHANNEL FUNCTIONAL TEST.                                          31 days SR 3.3.8.1.2            Perform CHANNEL CALIBRATION.                                              18 months SR 3.3.8.1.3            Perform CHANNEL CALIBRATION                                              24 months SR 3.3.8.1.4            Perform LOGIC SYSTEM FUNCTIONAL TEST.                                    24 months Columbia Generating Station                              3.3.8.1-2              Amendment No. 149,169 225
 
RPS Electric Power Monitoring 3.3.8.2 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME D. Required Action and                    D.1        Initiate action to restore one          Immediately associated Completion                            electric power monitoring Time of Condition A or B                        assembly to OPERABLE not met in MODE 4 or 5                          status for inservice power with both RHR SDC                                supply(s) supplying suction isolation valves                        required instrumentation.
open.
OR D.2        Initiate action to isolate the          Immediately RHR SDC System.
E. Required Action and                    E.1        Initiate action to fully insert          Immediately associated Completion                            all insertable control rods in Time of Condition A or B                        core cells containing one or not met in MODE 5 with                          more fuel assemblies.
any control rod withdrawn from a core cell containing one or more fuel assemblies.
SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTE------------------------------------------------------------
When an RPS electric power monitoring assembly is placed in an inoperable status solely for performance of required Surveillances, entry into the associated Conditions and Required Actions may be delayed for up to 6 hours provided the other RPS electric power monitoring assembly for the associated power supply maintains trip capability.
SURVEILLANCE                                                    FREQUENCY SR 3.3.8.2.1              -------------------------------NOTE------------------------------          In accordance with Only required to be performed prior to entering                              the Surveillance MODE 2 or 3 from MODE 4, when in MODE 4 for                                  Frequency Control t 24 hours.                                                                        Program Perform CHANNEL FUNCTIONAL TEST.                                        184 days Columbia Generating Station                                3.3.8.2-2            Amendment No. 149,169 225
 
RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.3.8.2.2    Perform CHANNEL CALIBRATION. The Allowable            24 months Values shall be:
: a. Overvoltage d 133.8 V, with time delay 3.46 seconds;
: b. Undervoltage t 110.8 V, with time delay 3.46 seconds; and
: c. Underfrequency t 57 Hz, with time delay 3.46 seconds.
SR 3.3.8.2.3    Perform a system functional test.                      24 months In accordance with the Surveillance Frequency Control Program Columbia Generating Station              3.3.8.2-3        Amendment No. 169,179 225
 
Recirculation Loops Operating (Prior to Implementation of PRNM Upgrade) 3.4.1 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 drive flow mismatch with                    24 hours both recirculation loops in operation is:
In accordance
: a. d 10% of rated recirculation loop drive flow                          with the when operating at < 70% of rated core flow; and                    Surveillance Frequency
: b. d 5% of rated recirculation loop drive flow when                  Control Program operating at t 70% of rated core flow.
Columbia Generating Station                      3.4.1-2              Amendment No. 205 225 226
 
Recirculation Loops Operating (After Implementation of PRNM Upgrade) 3.4.1 ACTIONS 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 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 drive flow mismatch with                      24 hours both recirculation loops in operation is:
In accordance
: a. d 10% of rated recirculation loop drive flow                            with the when operating at < 70% of rated core flow; and                      Surveillance Frequency
: b. d 5% of rated recirculation loop drive flow when                    Control Program operating at t 70% of rated core flow.
Columbia Generating Station                        3.4.1-4              Amendment No. 205 225 226
 
Jet Pumps 3.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.4.2.1      ------------------------------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 > 25% RTP.
Verify at least two of the following criteria (a, b,                  24 hours and c) are satisfied for each operating recirculation loop:
In accordance
: a. Recirculation loop drive flow versus                                  with the recirculation pump speed differs by d 10% from                      Surveillance established patterns.                                                Frequency Control Program
: b. Recirculation loop drive flow versus total core flow differs by d 10% from established patterns.
: c. Each jet pump diffuser to lower plenum differential pressure differs by d 20% from established patterns, or each jet pump flow differs by d 10% from established patterns.
Columbia Generating Station                      3.4.2-2              Amendment No. 149,169 225
 
SRVs - 573 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3      Safety/Relief Valves (SRVs) -  25% RTP LCO 3.4.3            The safety function of 12 SRVs shall be OPERABLE, with two SRVs in the lowest two lift setpoint groups OPERABLE.
APPLICABILITY:      THERMAL POWER t 25% RTP.
ACTIONS CONDITION                        REQUIRED ACTION                  COMPLETION TIME A. One or more required        A.1      Reduce THERMAL                  4 hours SRVs inoperable.                    POWER to < 25% RTP.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                          FREQUENCY SR 3.4.3.1        Verify the safety function lift setpoints of the required    In accordance SRVs are as follows:                                        with the Inservice Testing Program Number of                  Setpoint SRVs                      (psig) 2                  1165 +/- 34.9 4                  1175 +/- 35.2 4                  1185 +/- 35.5 4                  1195 +/- 35.8 4                  1205 +/- 36.1 SR 3.4.3.2        Verify each required SRV opens when manually                24 months actuated.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                  3.4.3-1          Amendment No. 149,169 225
 
SRVs - < 25% RTP 3.4.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.4.4.2      -------------------------------NOTE------------------------------
Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test.
Verify each required SRV opens when manually                          24 months actuated.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.4.4-2              Amendment No. 149,169 225
 
RCS Operational LEAKAGE 3.4.5 ACTIONS 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 OR Pressure boundary LEAKAGE exists.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR 3.4.5.1        Verify RCS unidentified and total LEAKAGE and      12 hours unidentified LEAKAGE increase are within limits.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.4.5-2        Amendment No. 149,169 225
 
RCS Leakage Detection Instrumentation 3.4.7 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 other required leakage detection instrumentation is OPERABLE.
SURVEILLANCE                                                      FREQUENCY SR 3.4.7.1              Perform CHANNEL CHECK of required drywell                                12 hours atmospheric monitoring system.
SR 3.4.7.2              Perform CHANNEL FUNCTIONAL TEST of required                              31 days leakage detection instrumentation.
SR 3.4.7.3              Perform CHANNEL CALIBRATION of required                                  18 months leakage detection instrumentation.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                                3.4.7-3              Amendment No. 149,169 225
 
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 I-131                          7 days specific activity is d 0.2 PCi/gm.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.4.8-2              Amendment No. 149,169 225
 
RHR Shutdown Cooling System - Hot Shutdown 3.4.9 ACTIONS CONDITION                              REQUIRED ACTION                            COMPLETION TIME B. No RHR shutdown                  B.1        Initiate action to restore one          Immediately cooling subsystem in                        RHR shutdown cooling operation.                                  subsystem or one recirculation pump to AND                                        operation.
No recirculation pump in        AND operation.
B.2        Verify reactor coolant                  1 hour from discovery circulation by an alternate              of no reactor coolant method.                                  circulation AND Once per 12 hours thereafter AND B.3        Monitor reactor coolant                  Once per hour temperature and pressure.
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 than 48 psig.
Verify one RHR shutdown cooling subsystem or                            12 hours recirculation pump is operating.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                        3.4.9-2              Amendment No. 164,169 225
 
RHR Shutdown Cooling System - Cold Shutdown 3.4.10 ACTIONS CONDITION                      REQUIRED ACTION                COMPLETION TIME B. No RHR shutdown              B.1    Verify reactor coolant      1 hour from discovery cooling subsystem in                circulating by an alternate  of no reactor coolant operation.                          method.                      circulation AND                                                              AND No recirculation pump in                                          Once per 12 hours operation.                                                        thereafter AND 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.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.4.10-2          Amendment No. 149,169 225
 
RCS P/T Limits 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.4.11.1      -------------------------------NOTE------------------------------
Only required to be performed during RCS heatup and cooldown operations, and RCS inservice leak and hydrostatic testing.
Verify:                                                              30 minutes
: a. RCS pressure and RCS temperature are within the applicable limits specified in Figures 3.4.11-1, 3.4.11-2, and 3.4.11-3; In accordance with the
: b. RCS heatup and cooldown rates are  100&deg;F in Surveillance any 1 hour period; and Frequency Control Program
: c. RCS temperature change during inservice leak and hydrostatic testing is  20&deg;F in any 1 hour period when the RCS pressure and RCS temperature are not within the limits of Figure 3.4.11-2.
SR 3.4.11.2      Verify RCS pressure and RCS temperature are                          Once within within the criticality limits specified in                            15 minutes prior Figure 3.4.11-3.                                                      to control rod withdrawal for the purpose of achieving criticality SR 3.4.11.3      -------------------------------NOTE------------------------------
Only required to be met in MODES 1, 2, 3, and 4 during recirculation pump startup.
Verify the difference between the bottom head                        Once within coolant temperature and the reactor pressure vessel                  15 minutes prior (RPV) coolant temperature is d 145&deg;F.                                to each startup of a recirculation pump Columbia Generating Station                      3.4.11-2              Amendment No. 149,169 225
 
RCS P/T Limits 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.4.11.7      -------------------------------NOTE------------------------------
Only required to be performed when tensioning the reactor vessel head bolting studs.
Verify reactor vessel flange and head flange                          30 minutes temperatures are t 80&deg;F.
SR 3.4.11.8      -------------------------------NOTE------------------------------
Not required to be performed until 30 minutes after RCS temperature d 90qF in MODE 4.
Verify reactor vessel flange and head flange                          30 minutes temperatures are t 80&deg;F.
SR 3.4.11.9      -------------------------------NOTE------------------------------
Not required to be performed until 12 hours after RCS temperature d 100qF in MODE 4.
Verify reactor vessel flange and head flange                          12 hours temperatures are t 80&deg;F.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.4.11-4              Amendment No. 149,169 225
 
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 d 1035 psig.
APPLICABILITY:        MODES 1 and 2.
ACTIONS CONDITION                      REQUIRED ACTION                COMPLETION TIME A. Reactor steam dome          A.1    Restore reactor steam        15 minutes pressure not within limit.          dome pressure to within limit.
B. Required Action and          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 d 1035 psig. 12 hours In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.4.12-1        Amendment No. 149,169 225
 
ECCS - Operating 3.5.1 ACTIONS CONDITION                        REQUIRED ACTION              COMPLETION TIME H. HPCS and Low                  H.1      Enter LCO 3.0.3.          Immediately Pressure Core Spray (LPCS) Systems inoperable.
OR Three or more ECCS injection/spray subsystems inoperable.
OR HPCS System and one or more required ADS valves inoperable.
OR Two or more ECCS injection/spray subsystems and one or more required ADS valves inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.5.1.1        Verify, for each ECCS injection/spray subsystem,      31 days the piping is filled with water from the pump discharge valve to the injection valve.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.5.1-3        Amendment No. 149,169 225
 
ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.5.1.2      ------------------------------NOTE-------------------------------
Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment                              In accordance and operation for decay heat removal with reactor                            with the steam dome pressure less than 48 psig in MODE 3,                          Surveillance if capable of being manually realigned and not                              Frequency otherwise inoperable.                                                    Control Program Verify each ECCS injection/spray subsystem                            31 days 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 3.5.1.3      Verify ADS accumulator backup compressed gas                          31 days system average pressure in the required bottles is t 2200 psig.
SR 3.5.1.4      Verify each ECCS pump develops the specified flow                    In accordance rate with the specified differential pressure between                with the Inservice reactor and suction source.                                          Testing Program DIFFERENTIAL PRESSURE BETWEEN REACTOR AND SYSTEM        FLOW RATE                  SUCTION SOURCE LPCS          t 6350 gpm                    t 128 psid LPCI          t 7450 gpm                    t 26 psig HPCS          t 6350 gpm                    t 200 psig SR 3.5.1.5      -------------------------------NOTE------------------------------
Vessel injection/spray may be excluded.
Verify each ECCS injection/spray subsystem                            24 months actuates on an actual or simulated automatic initiation signal.
Columbia Generating Station                      3.5.1-4              Amendment No. 169,205 225
 
ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.5.1.6      -------------------------------NOTE------------------------------
Valve actuation may be excluded.
Verify the ADS actuates on an actual or simulated                    24 months automatic initiation signal.
SR 3.5.1.7      -------------------------------NOTE------------------------------
Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test.
Verify each required ADS valve opens when                            24 months on a manually actuated.                                                    STAGGERED TEST BASIS for each valve solenoid SR 3.5.1.8      -------------------------------NOTE------------------------------
ECCS actuation instrumentation is excluded.
Verify the ECCS RESPONSE TIME for each ECCS                          24 months injection/spray subsystem is within limits.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.5.1-5              Amendment No. 150,169 225
 
ECCS - Shutdown 3.5.2 ACTIONS CONDITION                        REQUIRED ACTION                COMPLETION TIME D. Required Action C.2 and    D.1      Initiate action to restore    Immediately associated Completion                secondary containment to Time not met.                        OPERABLE status.
AND D.2      Initiate action to restore one Immediately standby gas treatment subsystem to OPERABLE status.
AND D.3      Initiate action to restore    Immediately isolation capability in each required secondary containment penetration flow path not isolated.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.5.2.1      Verify, for each required low pressure ECCS              12 hours injection/spray subsystem, the suppression pool water level is t 18 ft 6 inches.
SR 3.5.2.2      Verify, for the required High Pressure Core Spray        12 hours (HPCS) System, the:
: a. Suppression pool water level is t 18 ft 6 inches;      In accordance or                                                          with the Surveillance
: b. Condensate storage tank (CST) water level is              Frequency t 16.5 ft in a single CST or t 10.5 ft in each        Control Program CST.
Columbia Generating Station                  3.5.2-2          Amendment No. 169,210 225
 
ECCS - Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.5.2.3      Verify, for each required ECCS injection/spray                        31 days subsystem, the piping is filled with water from the pump discharge valve to the injection valve.
SR 3.5.2.4      ------------------------------NOTE-------------------------------        In accordance One low pressure coolant injection (LPCI)                                    with the subsystem may be considered OPERABLE during                                Surveillance alignment and operation for decay heat removal, if                          Frequency capable of being manually realigned and not                              Control Program otherwise inoperable.
Verify each required ECCS injection/spray                            31 days subsystem 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 3.5.2.5      Verify each required ECCS pump develops the                          In accordance specified flow rate with the specified differential                  with the Inservice pressure between reactor and suction source.                          Testing Program DIFFERENTIAL PRESSURE BETWEEN REACTOR AND SYSTEM        FLOW RATE                  SUCTION SOURCE LPCS          t 6350 gpm                    t 128 psid LPCI          t 7450 gpm                    t 26 psig HPCS          t 6350 gpm                    t 200 psig SR 3.5.2.6      -------------------------------NOTE------------------------------
Vessel injection/spray may be excluded.
Verify each required ECCS injection/spray                            24 months subsystem actuates on an actual or simulated automatic initiation signal.
Columbia Generating Station                      3.5.2-3              Amendment No. 169,205 225
 
RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.5.3.1      Verify the RCIC System piping is filled with water                      31 days from the pump discharge valve to the injection valve.
SR 3.5.3.2      Verify each RCIC System 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.
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 reactor pressure d 1035 psig and                            92 days t 935 psig, the RCIC pump can develop a flow rate t 600 gpm against a system head corresponding to reactor pressure.
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 reactor pressure d 165 psig, the RCIC                      24 months pump can develop a flow rate t 600 gpm against a system head corresponding to reactor pressure.
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.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.5.3-2              Amendment No. 150,169 225
 
Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.6.1.1.2    Verify drywell to suppression chamber bypass                          120 months leakage is  10% of the acceptable A / K design value of 0.050 ft2 at an initial differential pressure of              AND t 1.5 psid.
48 months following a test with bypass leakage greater than the bypass leakage limit AND 24 months following two consecutive tests with bypass leakage greater than the bypass leakage limit until two consecutive tests are less than or equal to the bypass leakage limit SR 3.6.1.1.3    -------------------------------NOTE------------------------------
Performance of SR 3.6.1.1.2 satisfies this surveillance.
Verify individual drywell to suppression chamber                      24 months vacuum relief valve bypass pathway leakage is 1.2% of the acceptable A / K design value of 0.050 ft2 at an initial differential pressure of 1.5 psid.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.6.1.1-2              Amendment No. 169,201 225
 
Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.6.1.1.4    -------------------------------NOTE------------------------------
Performance of SR 3.6.1.1.2 satisfies this surveillance.
Verify total drywell to suppression chamber vacuum                    24 months relief valve bypass leakage is  3.0% of the acceptable A / K design value of 0.050 ft2 at an initial differential pressure of  1.5 psid.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.6.1.1-3                    Amendment No. 201 225
 
Primary Containment Air Lock 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                        In accordance leakage rate testing in accordance with the Primary                  with the Primary Containment Leakage Rate Testing Program.                            Containment Leakage Rate Testing Program SR 3.6.1.2.2    Verify only one door in the primary containment air                  24 months lock can be opened at a time.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.6.1.2-4                Amendment No. 149,169 225
 
PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.6.1.3.1    -------------------------------NOTE------------------------------
Not required to be met when the 24 inch and 30 inch primary containment purge valves are open for inerting, de-inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open.
Verify each 24 inch and 30 inch primary                                  31 days containment purge valve is closed.
SR 3.6.1.3.2    ------------------------------NOTES-----------------------------
: 1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.
: 2. 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 and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.6.1.3-6              Amendment No. 169,208 225
 
PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.6.1.3.3    ------------------------------NOTES-----------------------------
: 1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.
: 2. Not required to be met for PCIVs that are open under administrative controls.
Verify each primary containment isolation manual                        Prior to entering valve and blind flange that is located inside primary                    MODE 2 or 3 from containment and not locked, sealed, or otherwise                        MODE 4 if secured and is required to be closed during accident                    primary conditions is closed.                                                    containment was de-inerted while in MODE 4, if not performed within the previous 92 days SR 3.6.1.3.4    Verify continuity of the traversing incore probe (TIP)                  31 days shear isolation valve explosive charge.
SR 3.6.1.3.5    Verify the isolation time of each power operated,                        In accordance automatic PCIV, except for MSIVs, is within limits.                      with the Inservice Testing Program SR 3.6.1.3.6    Verify the isolation time of each MSIV is                                In accordance t 3 seconds and d 5 seconds.                                            with the Inservice Testing Program SR 3.6.1.3.7    Verify each automatic PCIV actuates to the isolation                    24 months position on an actual or simulated isolation signal.
SR 3.6.1.3.8    Verify a representative sample of reactor instrument                    24 months line EFCVs actuate to the isolation position on an actual or simulated instrument line break signal.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.6.1.3-7              Amendment No. 199,208 225
 
PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR 3.6.1.3.9    Remove and test the explosive squib from each        24 months on a shear isolation valve of the TIP System.            STAGGERED TEST BASIS SR 3.6.1.3.10    Verify the combined leakage rate for all secondary  In accordance containment bypass leakage paths is d 0.04%          with the Primary primary containment volume/day when pressurized      Containment to t Pa.                                            Leakage Rate Testing Program SR 3.6.1.3.11    Verify leakage rate through each MSIV is            In accordance d 16.0 scfh when tested at t 25.0 psig.              with the Primary Containment Leakage Rate Testing Program SR 3.6.1.3.12    Verify combined leakage rate through hydrostatically In accordance tested lines that penetrate the primary containment  with the Primary is within limits.                                    Containment Leakage Rate Testing Program In accordance with the Surveillance Frequency Control Program Columbia Generating Station              3.6.1.3-8        Amendment No. 199,208 225
 
Drywell Air Temperature 3.6.1.4 3.6 CONTAINMENT SYSTEMS 3.6.1.4    Drywell Air Temperature LCO 3.6.1.4            Drywell average air temperature shall be d 135&deg;F.
APPLICABILITY:        MODES 1, 2, and 3.
ACTIONS CONDITION                      REQUIRED ACTION                    COMPLETION TIME A. Drywell average air          A.1    Restore drywell average air      8 hours temperature not within              temperature to within limit.
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 3.6.1.4.1        Verify drywell average air temperature is within limit. 24 hours In accordance with the Surveillance Frequency Control Program Columbia Generating Station                  3.6.1.4-1        Amendment No. 149,169 225
 
RHR Drywell Spray 3.6.1.5 3.6 CONTAINMENT SYSTEMS 3.6.1.5    Residual Heat Removal (RHR) Drywell Spray LCO 3.6.1.5          Two RHR drywell spray subsystems shall be OPERABLE.
APPLICABILITY:        MODES 1, 2, and 3.
ACTIONS CONDITION                        REQUIRED ACTION                COMPLETION TIME A. One RHR drywell spray          A.1      Restore RHR drywell spray    7 days subsystem inoperable.                  subsystem to OPERABLE status.
B. Two RHR drywell spray          B.1      Restore one RHR drywell      8 hours subsystems inoperable.                spray subsystem to OPERABLE status.
C. Required Action and            C.1      Be in MODE 3.                12 hours associated Completion Time not met.                AND C.2      Be in MODE 4.                36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.6.1.5.1      Verify each RHR drywell spray subsystem manual,        31 days power operated, and automatic valve in the flow In accordance with path that is not locked, sealed, or otherwise secured the Surveillance in position, is in the correct position or can be Frequency Control aligned to the correct position.
Program SR 3.6.1.5.2      Verify each spray nozzle is unobstructed.              10 years Columbia Generating Station                  3.6.1.5-1        Amendment No. 149,169 225
 
Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 ACTIONS CONDITION                            REQUIRED ACTION                            COMPLETION TIME E. Required Action and            E.1      Be in MODE 3.                            12 hours associated Completion Time not met.                  AND E.2        Be in MODE 4.                            36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.6.1.6.1    ------------------------------NOTES-----------------------------
: 1. Not required to be met for vacuum breakers that are open during Surveillances.
: 2. Not required to be met for vacuum breakers open when performing their intended function.
Verify each vacuum breaker is closed.                                    14 days SR 3.6.1.6.2    Perform a functional test of each vacuum breaker.                        In accordance with the Inservice Testing Program SR 3.6.1.6.3    Verify the full open setpoint of each vacuum breaker                    24 months is  0.5 psid.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.6.1.6-2              Amendment No. 149,169 225
 
Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7 ACTIONS CONDITION                            REQUIRED ACTION                            COMPLETION TIME D. Required Action and            D.1      Be in MODE 3.                            12 hours associated Completion Time not met.                  AND D.2        Be in MODE 4.                            36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.6.1.7.1    -------------------------------NOTE------------------------------
Not required to be met for vacuum breakers that are open during Surveillances.
Verify each vacuum breaker is closed.                                    14 days SR 3.6.1.7.2    Perform a functional test of each required vacuum                        31 days breaker.
AND Within 12 hours after any discharge of steam to the suppression chamber from the safety/relief valves SR 3.6.1.7.3    Verify the full open setpoint of each required                          24 months vacuum breaker is d 0.5 psid.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.6.1.7-2              Amendment No. 169,202 225
 
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 Columbia Generating Station              3.6.2.1-3      Amendment No. 149,169 225
 
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 t 30 ft 9.75 inches and d 31 ft 1.75 inches.
APPLICABILITY:          MODES 1, 2, and 3.
ACTIONS CONDITION                        REQUIRED ACTION                    COMPLETION TIME A. Suppression pool water          A.1      Restore suppression pool        2 hours level not within limits.                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.      24 hours In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.6.2.2-1          Amendment No. 149,169 225
 
RHR Suppression Pool Cooling 3.6.2.3 3.6 CONTAINMENT SYSTEMS 3.6.2.3    Residual Heat Removal (RHR) Suppression Pool Cooling LCO 3.6.2.3          Two RHR suppression pool cooling subsystems shall be OPERABLE.
APPLICABILITY:      MODES 1, 2, and 3.
ACTIONS CONDITION                      REQUIRED ACTION                  COMPLETION TIME A. One RHR suppression          A.1    Restore RHR suppression        7 days pool cooling subsystem              pool cooling subsystem to inoperable.                          OPERABLE status.
B. Required Action and          B.1    Be in MODE 3.                  12 hours associated Completion Time of Condition A not      AND met.
B.2    Be in MODE 4.                  36 hours OR Two RHR suppression pool cooling subsystems inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.6.2.3.1      Verify each RHR suppression pool cooling                  31 days subsystem 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 or can be aligned to the correct position.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.6.2.3-1          Amendment No. 149,169 225
 
Primary Containment Atmosphere Mixing System 3.6.3.2 3.6 CONTAINMENT SYSTEMS 3.6.3.2    Primary Containment Atmosphere Mixing System LCO 3.6.3.2          Two head area return fans shall be OPERABLE.
APPLICABILITY:        MODES 1 and 2.
ACTIONS CONDITION                    REQUIRED ACTION                  COMPLETION TIME A. One head area return        A.1    Restore head area return      30 days fan inoperable.                    fan to OPERABLE status.
B. Two head area return        B.1    Verify by administrative      1 hour fans inoperable.                  means that the hydrogen and oxygen control function is maintained.
AND B.2    Restore one head area          7 days return fan to OPERABLE status.
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        Operate each head area return fan for t 15 minutes. 92 days In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.6.3.2-1        Amendment No. 169,187 225
 
Primary Containment Oxygen Concentration 3.6.3.3 3.6 CONTAINMENT SYSTEMS 3.6.3.3    Primary Containment Oxygen Concentration LCO 3.6.3.3            The primary containment oxygen concentration shall be < 3.5 volume percent.
APPLICABILITY:          MODE 1 during the time period:
: a. From 24 hours after THERMAL POWER is > 15% RTP following startup, to
: b. 24 hours prior to reducing THERMAL POWER to < 15% RTP prior to the next scheduled reactor shutdown.
ACTIONS CONDITION                          REQUIRED ACTION                COMPLETION TIME A. Primary containment              A.1    Restore oxygen                24 hours oxygen concentration                    concentration to within limit.
not within limit.
B. Required Action and              B.1    Reduce THERMAL                8 hours associated Completion                  POWER to d 15% RTP.
Time not met.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.6.3.3.1          Verify primary containment oxygen concentration is      7 days within limits.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.6.3.3-1        Amendment No. 149,169 225
 
Secondary Containment 3.6.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR 3.6.4.1.1    Verify secondary containment vacuum is t 0.25 inch    24 hours of vacuum water gauge.
SR 3.6.4.1.2    Verify all secondary containment equipment hatches    31 days are closed and sealed.
SR 3.6.4.1.3    Verify each secondary containment access inner        31 days door or each secondary containment access outer door in each access opening is closed.
SR 3.6.4.1.4    Verify each standby gas treatment (SGT) subsystem    24 months on a will draw down the secondary containment to          STAGGERED t 0.25 inch of vacuum water gauge in                  TEST BASIS d 120 seconds.
SR 3.6.4.1.5    Verify each SGT subsystem can maintain                24 months on a t 0.25 inch of vacuum water gauge in the secondary    STAGGERED containment for 1 hour at a flow rate d 2240 cfm. TEST BASIS In accordance with the Surveillance Frequency Control Program Columbia Generating Station              3.6.4.1-2        Amendment No. 169,199 225
 
SCIVs 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.6.4.2.1    ------------------------------NOTES-----------------------------
: 1. Valves and blind flanges in high radiation areas may be verified by use of administrative controls.
: 2. Not required to be met for SCIVs that are open under administrative controls.
Verify each secondary containment isolation manual                      31 days valve and blind flange that is not locked, sealed, or otherwise secured, and is required to be closed during accident conditions is closed.
SR 3.6.4.2.2    Verify the isolation time of each power operated,                        In accordance automatic SCIV is within limits.                                        with the Inservice Testing Program SR 3.6.4.2.3    Verify each automatic SCIV actuates to the isolation                    24 months position on an actual or simulated automatic isolation signal.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.6.4.2-3                    Amendment No. 208 225
 
SGT System 3.6.4.3 ACTIONS CONDITION                        REQUIRED ACTION                  COMPLETION TIME E. Two SGT subsystems        E.1        Initiate action to suspend    Immediately inoperable during                    OPDRVs.
OPDRVs.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                        FREQUENCY SR 3.6.4.3.1      Operate each SGT subsystem for t 10 continuous            31 days hours with heaters operating.
SR 3.6.4.3.2      Perform required SGT filter testing in accordance        In accordance with the Ventilation Filter Testing Program (VFTP).      with the VFTP SR 3.6.4.3.3      Verify each SGT subsystem actuates on an actual          24 months or simulated initiation signal.
SR 3.6.4.3.4      Verify each SGT filter cooling recirculation valve can    24 months be opened and the fan started.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                  3.6.4.3-2        Amendment No. 169,199 225
 
SW System and UHS 3.7.1 ACTIONS 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 OR Both SW subsystems inoperable.
OR UHS inoperable for reasons other than Condition A.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.7.1.1        Verify the water level of each UHS spray pond is                        24 hours t 432 ft 9 inches mean sea level.
SR 3.7.1.2        Verify the average water temperature of each UHS                        24 hours spray pond is d 77qF.
SR 3.7.1.3        -------------------------------NOTE------------------------------
Isolation of flow to individual components does not render SW subsystem inoperable.
Verify each SW subsystem manual, power                                  31 days operated, and automatic valve in the flow path servicing safety related systems or components, that is not locked, sealed, or otherwise secured in position, is in the correct position.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                        3.7.1-2              Amendment No. 149,169 225
 
SW System and UHS 3.7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR 3.7.1.4      Verify average sediment depth in each UHS spray      92 days pond is < 0.5 ft.
SR 3.7.1.5      Verify each SW subsystem actuates on an actual or    24 months simulated initiation signal.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.7.1-3      Amendment No. 149,169 225
 
HPCS SW System 3.7.2 3.7 PLANT SYSTEMS 3.7.2      High Pressure Core Spray (HPCS) Service Water (SW) System LCO 3.7.2            The HPCS SW System shall be OPERABLE.
APPLICABILITY:        MODES 1, 2, and 3.
ACTIONS CONDITION                            REQUIRED ACTION                            COMPLETION TIME A. HPCS SW System                  A.1        Declare HPCS System                      Immediately inoperable.                              inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.7.2.1        -------------------------------NOTE------------------------------
Isolation of flow to individual components does not render HPCS SW System inoperable.
Verify each HPCS SW System manual, power                                31 days operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.
SR 3.7.2.2        Verify the HPCS SW System actuates on an actual                        24 months or simulated initiation signal.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                        3.7.2-1              Amendment No. 149,169 225
 
CREF System 3.7.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.7.3.1      Operate each CREF subsystem for t 10 continuous        31 days hours with the heaters operating.
SR 3.7.3.2      Perform required CREF filter testing in accordance      In accordance with the Ventilation Filter Testing Program (VFTP). with the VFTP SR 3.7.3.3      Verify each CREF subsystem actuates on an actual        24 months or simulated initiation signal.
SR 3.7.3.4      Perform required CRE unfiltered air inleakage          In accordance testing in accordance with the Control Room            with the Control Envelope Habitability Program.                          Room Envelope Habitability Program In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.7.3-3        Amendment No. 199,207 225
 
Control Room AC System 3.7.4 ACTIONS CONDITION                      REQUIRED ACTION                COMPLETION TIME E. Required Action and          E.1    Initiate action to suspend    Immediately associated Completion              OPDRVs.
Time of Condition B not met during OPDRVs.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.7.4.1        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 Columbia Generating Station                3.7.4-2      Amendment No. 169,199 225 227
 
Main Condenser Offgas 3.7.5 SURVEILLANCE REQUIR5EMENTS SURVEILLANCE                                                    FREQUENCY SR 3.7.5.1      -------------------------------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 gases is d 332 mCi/second after decay of                                31 days 30 minutes.
AND Once within 4 hours after a t 50% increase in the nominal steady state fission gas release after factoring out increases due to changes in THERMAL POWER level In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.7.5-2              Amendment No. 149,169 225
 
Main Turbine Bypass System 3.7.6 3.7 PLANT SYSTEMS 3.7.6      Main Turbine Bypass System LCO 3.7.6            The Main Turbine Bypass System shall be OPERABLE.
OR LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," limits for an inoperable Main Turbine Bypass System, as specified in the COLR, are made applicable.
APPLICABILITY:        THERMAL POWER t 25% RTP.
ACTIONS CONDITION                    REQUIRED ACTION                COMPLETION TIME A. Requirements of the          A.1    Satisfy the requirements of  2 hours LCO not met.                      the LCO.
B. Required Action and          B.1    Reduce THERMAL                4 hours associated Completion            POWER to < 25% RTP.
Time not met.
In accordance with the Surveillance Frequency Control Program SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR 3.7.6.1        Verify one complete cycle of each main turbine        31 days bypass valve.
SR 3.7.6.2        Perform a system functional test.                    24 months SR 3.7.6.3        Verify the TURBINE BYPASS SYSTEM                      24 months RESPONSE TIME is within limits.
Columbia Generating Station                3.7.6-1          Amendment No. 149,169 225
 
Spent Fuel Storage Pool Water Level 3.7.7 3.7 PLANT SYSTEMS 3.7.7        Spent Fuel Storage Pool Water Level LCO 3.7.7              The spent fuel storage pool water level shall be t 22 ft over the top of irradiated fuel assemblies seated in the spent fuel storage pool racks.
APPLICABILITY:        During movement of irradiated fuel assemblies in the spent fuel storage pool.
ACTIONS CONDITION                        REQUIRED ACTION                        COMPLETION TIME A. Spent fuel storage pool        A.1    ---------------NOTE--------------
water level not within                LCO 3.0.3 is not applicable.
limit.                                -------------------------------------
Suspend movement of                    Immediately irradiated fuel assemblies in the spent fuel storage pool.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                            FREQUENCY SR 3.7.7.1          Verify the spent fuel storage pool water level is              7 days t 22 ft over the top of irradiated fuel assemblies seated in the spent fuel storage pool racks.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.7.7-1              Amendment No. 149,169 225
 
AC Sources - Operating 3.8.1 ACTIONS CONDITION                              REQUIRED ACTION                            COMPLETION TIME F. Required Action and              F.1      Be in MODE 3.                            12 hours associated Completion Time of Condition A, B,          AND C, D, or E not met.
F.2      Be in MODE 4.                            36 hours G. Three or more required          G.1        Enter LCO 3.0.3.                        Immediately AC sources inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.1        Verify correct breaker alignment and indicated                          7 days power availability for each offsite circuit.
SR 3.8.1.2        ------------------------------NOTES-----------------------------
: 1. All DG starts may be preceded by an engine prelube period and followed by a warmup                                In accordance period prior to loading.                                                  with the Surveillance
: 2. A modified DG start involving idling and gradual                        Frequency acceleration to synchronous speed may be                            Control Program 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 required DG starts from standby                            31 days conditions and achieves steady state:
: a. Voltage t 3910 V and d 4400 V and frequency t 58.8 Hz and d 61.2 Hz for DG-1 and DG-2; and
: b. Voltage t 3910 V and d 4400 V and frequency t 58.8 Hz and d 61.2 Hz for DG-3.
Columbia Generating Station                        3.8.1-5              Amendment No. 169,181 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS 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.
: 5. The endurance test of SR 3.8.1.14 may be performed in lieu of the load-run test in SR 3.8.1.3 provided the requirements, except the upper load limits, of SR 3.8.1.3 are met.
Verify each required DG is synchronized and loaded                      31 days and operates for t 60 minutes at a load t 4000 kW and d 4400 kW for DG-1 and DG-2, and t 2340 kW and d 2600 kW for DG-3.
SR 3.8.1.4      Verify each required day tank contains fuel oil to                      31 days support greater than or equal to one hour of operation at full load plus 10%.
SR 3.8.1.5      Check for and remove accumulated water from each                        31 days required day tank.
SR 3.8.1.6      Verify each required fuel oil transfer subsystem                        92 days operates to automatically transfer fuel oil from the storage tank to the day tank.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.8.1-6              Amendment No. 173,215 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.8.1.7      -------------------------------NOTE------------------------------
All DG starts may be preceded by an engine prelube period.
Verify each required DG starts from standby                            184 days condition and achieves:
: a. For DG-1 and DG-2 in d 15 seconds, voltage t 3910 V and frequency t 58.8 Hz, and after steady state conditions are reached, maintains voltage t 3910 V and d 4400 V and frequency t 58.8 Hz and d 61.2 Hz; and
: b. For DG-3, in d 15 seconds, voltage t 3910 V and frequency t 58.8 Hz, and after steady state conditions are reached, maintains voltage t 3910 V and d 4400 V and frequency t 58.8 Hz and d 61.2 Hz.
SR 3.8.1.8      -------------------------------NOTE------------------------------
The automatic transfer function of this Surveillance shall not normally be performed in MODE 1 or 2.
However, this Surveillance may be performed to re-establish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify automatic and manual transfer of the power                      24 months supply to safety related buses from the startup offsite circuit to the backup offsite circuit.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.8.1-7              Amendment No. 181,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.8.1.9      ------------------------------NOTES-----------------------------
: 1. Credit may be taken for unplanned events that satisfy this SR.
: 2. If performed with the DG synchronized with offsite power, it shall be performed at a power factor as close to the power factor of the single largest post-accident load as practicable.
However, if grid conditions do not permit, the power factor limit is not required to be met.
Under this condition, the power factor shall be maintained as close to the limit as practicable.
Verify each required DG rejects a load greater than                      24 months or equal to its associated single largest post-accident load, and following load rejection, the frequency is d 66.75 Hz.
SR 3.8.1.10      ------------------------------NOTES-----------------------------
: 1. Credit may be taken for unplanned events that satisfy this SR.
: 2. If performed with the DG synchronized with offsite power, it shall be performed at a power factor of d 0.9 for DG-1 and DG-2, and d 0.91 for DG-3. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition, the power factor shall be maintained as close to the limit as practicable.
Verify each required DG does not trip and voltage is                    24 months maintained d 4784 V during and following a load rejection of a load t 4400 kW for DG-1 and DG-2 and t 2600 kW for DG-3.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.8.1-8              Amendment No. 203,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.11      ------------------------------NOTES-----------------------------
: 1. All DG starts may be preceded by an engine prelube period.
: 2. This Surveillance shall not normally be performed in MODE 1, 2, or 3 (not applicable to DG-3). However, portions of the Surveillance may be performed to re-establish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify on an actual or simulated loss of offsite power                24 months signal:
: a. De-energization of emergency buses;                              In accordance with the
: b. Load shedding from emergency buses for                            Surveillance Divisions 1 and 2; and                                              Frequency Control
: c. DG auto-starts from standby condition and:                          Program
: 1.      energizes permanently connected loads in d 15 seconds for DG-1 and DG-2, and in d 18 seconds for DG-3,
: 2.      energizes auto-connected shutdown loads,
: 3.      maintains steady state voltage t 3910 V and d 4400 V,
: 4.      maintains steady state frequency t 58.8 Hz and d 61.2 Hz, and
: 5.      supplies permanently connected and auto-connected shutdown loads for t 5 minutes.
Columbia Generating Station                      3.8.1-9              Amendment No. 203,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS 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 normally be performed in MODE 1 or 2 (not applicable to DG-3). However, portions of the Surveillance may be performed to re-establish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify on an actual or simulated Emergency Core                        24 months Cooling System (ECCS) initiation signal each required DG auto-starts from standby condition and:
In accordance
: a. For DG-1 and DG-2, in d 15 seconds achieves                          with the voltage t 3910 V, and after steady state                          Surveillance conditions are reached, maintains voltage                          Frequency t 3910 V and d 4400 V and, for DG-3, in                              Control d 15 seconds achieves voltage t 3910 V, and                          Program after steady state conditions are reached, maintains voltage t 3910 V and d 4400 V;
: b. In d 15 seconds, achieves frequency t 58.8 Hz and after steady state conditions are achieved, maintains frequency t 58.8 Hz and d 61.2 Hz;
: c. Operates for t 5 minutes;
: d. Permanently connected loads remain energized from the offsite power system; and
: e. Emergency loads are auto-connected to the offsite power system.
Columbia Generating Station                      3.8.1-10              Amendment No. 173,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.13      -------------------------------NOTE------------------------------
Credit may be taken for unplanned events that satisfy this SR.
Verify each required DG's automatic trips are                          24 months bypassed on an actual or simulated ECCS initiation signal except:
In accordance with
: a. Engine overspeed;                                                    the Surveillance Frequency Control
: b. Generator differential current; and                                      Program
: c. Incomplete starting sequence.
SR 3.8.1.14      ------------------------------NOTES-----------------------------
: 1. Momentary transients outside the load, excitation current, and power factor ranges do not invalidate this test.
: 2. Credit may be taken for unplanned events that satisfy this SR.
: 3. If performed with the DG synchronized with offsite power, it shall be performed at a power factor of d 0.9 for DG-1 and DG-2, and d 0.91 for DG-3. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition, the power factor shall be maintained as close to the limit as practicable.
Verify each required DG operates for t 24 hours:                      24 months
: a. For t 2 hours loaded t 4650 kW for DG-1 and DG-2, and t 2850 kW for DG-3; and
: b. For the remaining hours of the test loaded t 4400 kW for DG-1 and DG-2, and t 2600 kW for DG-3.
Columbia Generating Station                      3.8.1-11              Amendment No. 181,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.15      ------------------------------NOTES-----------------------------
: 1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated t 1 hour loaded t 4000 kW for DG-1 and DG-2, and t 2340 kW for DG-3.
Momentary transients outside of load range do not invalidate this test.
: 2. All DG starts may be preceded by an engine prelube period.
Verify each required DG starts and achieves:                          24 months
: a. For DG-1 and DG-2, in d 15 seconds, voltage t 3910 V and frequency t 58.8 Hz, and after                      In accordance steady state conditions are reached, maintains                        with the voltage t 3910 V and d 4400 V and frequency                        Surveillance t 58.8 Hz and d 61.2 Hz; and                                        Frequency Control
: b. For DG-3, in d 15 seconds, voltage t 3910 V                          Program and frequency t 58.8 Hz, and after steady state conditions are reached, maintains voltage t 3910 V and d 4400 V and frequency t 58.8 Hz and d 61.2 Hz.
Columbia Generating Station                      3.8.1-12              Amendment No. 203,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.16      -------------------------------NOTE------------------------------
This Surveillance shall not normally be performed in MODE 1, 2, or 3 (not applicable to DG-3). However, this Surveillance may be performed to re-establish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR.
Verify each required DG:                                              24 months
: a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;                                    In accordance with the Surveillance
: b. Transfers loads to offsite power source; and                      Frequency Control Program
: c. Returns to ready-to-load operation.
SR 3.8.1.17      -------------------------------NOTE------------------------------
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:
: a. Returning DG to ready-to-load operation; and
: b. Automatically energizing the emergency load from offsite power.
Columbia Generating Station                      3.8.1-13              Amendment No. 203,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.18      -------------------------------NOTE------------------------------
This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this Surveillance may be performed to re-establish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify interval between each sequenced load block                      24 months is within +/- 10% of design interval for each time delay relay.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.8.1-14              Amendment No. 203,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS 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 normally be performed in MODE 1, 2, or 3 (not applicable to DG-3). However, portions of the Surveillance may be performed to re-establish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify, on an actual or simulated loss of offsite                      24 months power signal in conjunction with an actual or simulated ECCS initiation signal:
: a. De-energization of emergency buses;                              In accordance with the Surveillance
: b. Load shedding from emergency buses for DG-1                      Frequency Control and DG-2; and                                                          Program
: c. DG auto-starts from standby condition and:
: 1.      energizes permanently connected loads in d 15 seconds,
: 2.      energizes auto-connected emergency loads,
: 3.      maintains steady state voltage t 3910 V and d 4400 V,
: 4.      maintains steady state frequency t 58.8 Hz and d 61.2 Hz, and
: 5.      supplies permanently connected and auto-connected emergency loads for t 5 minutes.
Columbia Generating Station                      3.8.1-15              Amendment No. 203,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.8.1.20      -------------------------------NOTE------------------------------
All DG starts may be preceded by an engine prelube period.
Verify, when started simultaneously from standby                        10 years condition, DG-1 and DG-2 achieves, in d 15 seconds, voltage t 3910 V and frequency t 58.8 Hz, and DG-3 achieves, in d 15 seconds, voltage t 3910 V and frequency t 58.8 Hz.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.8.1-16                    Amendment No. 204 225
 
Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS CONDITION                          REQUIRED ACTION                  COMPLETION TIME E. One or more DGs with          E.1      Restore required starting air    48 hours required starting air                    receiver pressure to within receiver pressure:                      limit.
: 1. For DG-1 and DG-2,
        < 230 psig and t 150 psig; and
: 2. For DG-3, < 223 psig and t 150 psig.
F. Required Action and            F.1      Declare associated DG            Immediately associated Completion                    inoperable.
Time of Condition A, B, C, D, or E not met.
OR One or more DGs with stored diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than Condition A, B, C, D, or E.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                        FREQUENCY SR 3.8.3.1            Verify each fuel oil storage subsystem contains          31 days greater than or equal to a seven day supply of fuel.
SR 3.8.3.2          Verify lube oil inventory is greater than or equal to a    31 days seven day supply.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.8.3-2        Amendment No. 169,215 225
 
Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                        FREQUENCY SR 3.8.3.3      Verify fuel oil properties of new and stored fuel oil      In accordance are tested in accordance with, and maintained within      with the Diesel the limits of, the Diesel Fuel Oil Testing Program.        Fuel Oil Testing Program SR 3.8.3.4      Verify each required DG air start receiver pressure        31 days is:
: a. t 230 psig for DG-1 and DG-2; and
: b. t 223 psig for DG-3.
SR 3.8.3.5      Check for and remove accumulated water from each          92 days fuel oil storage tank.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.8.3-3          Amendment No. 169,215 225
 
DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.8.4.1      Verify battery terminal voltage is greater than or                      7 days equal to the minimum established float voltage.
SR 3.8.4.2      Verify each required battery charger supplies the                      24 months required load for t 1.5 hours at:
: a. t 126 V for the 125 V battery chargers; and
: b. t 252 V for the 250 V battery charger.
SR 3.8.4.3      ------------------------------NOTES-----------------------------
: 1. The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.3.
: 2. This Surveillance shall not be performed in MODE 1, 2, or 3 for the Division 1 and 2 125 V DC batteries. However, credit may be taken for unplanned events that satisfy this SR.
Verify battery capacity is adequate to supply, and                      24 months maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.8.4-4                    Amendment 169,204 225
 
Battery Parameters 3.8.6 ACTIONS CONDITION                              REQUIRED ACTION                            COMPLETION TIME F. One or more batteries              F.1        Declare associated battery              Immediately with a required battery                      inoperable.
parameter not met for reasons other than Condition A, B, C, D, or E.
OR Required Action and associated Completion Time of Condition A, B, C, D, or E not met.
OR One or more batteries with one or more battery cell(s) float voltage
    < 2.07 V and float current > 2 amps.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.8.6.1          -------------------------------NOTE------------------------------
Not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1.
Verify each battery float current is d 2 amps.                          7 days SR 3.8.6.2          Verify each battery pilot cell voltage is t 2.07 V.                    31 days In accordance with the Surveillance Frequency Control Program Columbia Generating Station                          3.8.6-3                    Amendment 169,204 225
 
Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.8.6.3      Verify each battery connected cell electrolyte level is              31 days greater than or equal to minimum established design limits.
SR 3.8.6.4      Verify each battery pilot cell temperature is greater                31 days than or equal to minimum established design limits.
SR 3.8.6.5      Verify each battery connected cell voltage is                        92 days t 2.07 V.
SR 3.8.6.6      -------------------------------NOTE------------------------------        In accordance with This Surveillance shall not be performed in                                the Surveillance MODE 1, 2, or 3 for the Division 1 and 2 125 V DC                        Frequency Control batteries. However, credit may be taken for                                    Program unplanned events that satisfy this SR.
Verify battery capacity is t 80% of the                              60 months manufacturer's rating for the 125 V batteries and 83.4% of the manufacturer's rating for the 250 V                    AND battery, when subjected to a performance discharge test or a modified performance discharge test.                        12 months when battery shows degradation or has reached 85%
of expected life with capacity
                                                                                        < 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected life with capacity t 100% of manufacturer's rating Columbia Generating Station                      3.8.6-4                    Amendment 169,204 225
 
Distribution Systems - Operating 3.8.7 ACTIONS 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 D. Division 1 250 V DC          D.1      Declare associated            Immediately electrical power                      supported feature(s) distribution subsystem                inoperable.
inoperable.
E. One or more Division 3        E.1      Declare High Pressure          Immediately AC or DC electrical                    Core Spray System power distribution                    inoperable.
subsystems inoperable.
F. Two or more divisions        F.1      Enter LCO 3.0.3.              Immediately with inoperable electrical power distribution subsystems that result in a loss of function.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.8.7.1          Verify correct breaker alignments and indicated          7 days power availability to required AC and DC electrical power distribution subsystems.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                  3.8.7-2            Amendment 149,169 225
 
Distribution Systems - Shutdown 3.8.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.8.8.1      Verify correct breaker alignments and indicated          7 days power availability to required AC and DC electrical power distribution subsystems.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.8.8-2              Amendment 169,199 225
 
Refueling Equipment Interlocks 3.9.1 3.9 REFUELING OPERATIONS 3.9.1        Refueling Equipment Interlocks LCO 3.9.1              The refueling equipment interlocks associated with the refuel position shall be OPERABLE.
APPLICABILITY:          During in-vessel fuel movement with equipment associated with the interlocks when the reactor mode switch is in the refuel position.
ACTIONS CONDITION                      REQUIRED ACTION                  COMPLETION TIME A. One or more required            A.1    Suspend in-vessel fuel          Immediately refueling equipment                  movement with equipment interlocks inoperable.                associated with the inoperable interlock(s).
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:
In accordance
: a. All-rods-in,                                              with the Surveillance
: b. Refueling platform position,                            Frequency Control Program
: c. Refueling platform fuel grapple fuel-loaded,
: d. Refueling platform frame-mounted hoist fuel-loaded, and
: e. Refueling platform trolley-mounted hoist fuel-loaded.
Columbia Generating Station                    3.9.1-1              Amendment 149,169 225
 
Refuel 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.
AND A.2        Initiate action to fully insert          Immediately all 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 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 accordance with the Surveillance Frequency Control Program Columbia Generating Station                            3.9.2-1                  Amendment 149,169 225
 
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.
APPLICABILITY:          When loading fuel assemblies into the core.
ACTIONS CONDITION                          REQUIRED ACTION              COMPLETION TIME A. One or more control              A.1      Suspend loading fuel        Immediately rods 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 the Surveillance Frequency Control Program Columbia Generating Station                      3.9.3-1            Amendment 149,169 225
 
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.                    7 days SR 3.9.5.2          Verify each withdrawn control rod scram                                  7 days accumulator pressure is t 940 psig.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                          3.9.5-1                          Amendment 149,169 225
 
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 t 22 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          A.1    Suspend movement of              Immediately within limit.                      irradiated fuel assemblies within the RPV.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.9.6.1          Verify RPV water level is t 22 ft above the top of the  24 hours RPV flange.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                  3.9.6-1              Amendment 149,169 225
 
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 t 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            A.1    Suspend movement of new          Immediately within limit.                      fuel assemblies and handling of control rods within the RPV.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.9.7.1          Verify RPV water level is t 23 ft above the top of        24 hours irradiated fuel assemblies seated within the RPV.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                  3.9.7-1              Amendment 169,199 225
 
RHR - High Water Level 3.9.8 ACTIONS CONDITION                    REQUIRED ACTION                  COMPLETION TIME B. (continued)                B.3    Initiate action to restore one Immediately standby gas treatment subsystem to OPERABLE status.
AND B.4    Initiate action to restore    Immediately isolation capability in each required secondary containment penetration flow path not isolated.
C. No RHR shutdown            C.1    Verify reactor coolant        1 hour from discovery cooling subsystem in              circulation by an alternate    of no reactor coolant operation.                        method.                        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          12 hours operating.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.9.8-2              Amendment 149,169 225
 
RHR - Low Water Level 3.9.9 ACTIONS CONDITION                    REQUIRED ACTION                  COMPLETION TIME B. (continued)                B.3    Initiate action to restore    Immediately isolation capability in each required secondary containment penetration flow path not isolated.
C. No RHR shutdown            C.1    Verify reactor coolant        1 hour from discovery cooling subsystem in              circulation by an alternate    of no reactor coolant operation.                        method.                        circulation AND Once per 12 hours thereafter AND C.2    Monitor reactor coolant        Once per hour temperature.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.9.9.1        Verify one RHR shutdown cooling subsystem is          12 hours operating.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.9.9-2              Amendment 149,169 225
 
Reactor Mode Switch Interlock Testing 3.10.2 ACTIONS CONDITION                      REQUIRED ACTION                        COMPLETION TIME A. (continued)                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        12 hours containing one or more fuel assemblies.
SR 3.10.2.2      Verify no CORE ALTERATIONS are in progress.                      24 hours In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.10.2-2                    Amendment 149,169 225
 
Single Control Rod Withdrawal - Hot Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.10.3.2      -------------------------------NOTE------------------------------
Not 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                    24 hours being 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                    24 hours being withdrawn, are fully inserted.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.10.3-3                    Amendment 149,169 225
 
Single Control Rod Withdrawal - Cold Shutdown 3.10.4 ACTIONS CONDITION                            REQUIRED ACTION                            COMPLETION TIME B. (continued)                    B.2.2    Initiate action to satisfy the            Immediately requirements of this LCO.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.10.4.1      Perform the applicable SRs for the required LCOs.                      According to the applicable SRs SR 3.10.4.2      -------------------------------NOTE------------------------------
Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.c.1 requirements.
Verify all control rods, other than the control rod                    24 hours being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed.
SR 3.10.4.3      Verify all control rods, other than the control rod                    24 hours being withdrawn, are fully inserted.
SR 3.10.4.4      -------------------------------NOTE------------------------------
Not 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 hours In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.10.4-3                    Amendment 149,169 225
 
Single CRD Removal - Refueling 3.10.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.10.5.1      Verify all control 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 hours 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 other CORE ALTERATIONS are in                24 hours progress.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.10.5-2              Amendment 149,169 225
 
Multiple Control Rod Withdrawal - Refueling 3.10.6 ACTIONS CONDITION                            REQUIRED ACTION                            COMPLETION TIME A. (continued)                    A.3.1    Initiate action to fully insert          Immediately all control rods in core cells containing one or more fuel assemblies.
OR A.3.2      Initiate action to satisfy the          Immediately requirements of this LCO.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.10.6.1      Verify the four fuel assemblies are removed from                        24 hours 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 hours one or more fuel assemblies are fully inserted.
SR 3.10.6.3      -------------------------------NOTE------------------------------
Only required to be met during fuel loading.
Verify fuel assemblies being loaded are in                              24 hours compliance with an approved spiral reload sequence.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.10.6-2                    Amendment 149,169 225
 
SDM Test - Refueling (Prior to Implementation of PRNM Upgrade) 3.10.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                    FREQUENCY SR 3.10.8.3      -------------------------------NOTE------------------------------
Not required to be met if SR 3.10.8.2 satisfied.
Verify movement of control rods is in compliance                        During control rod with the approved control rod sequence for the SDM                      movement test 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.
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 AND 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                                7 days t 940 psig.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.10.8-3            Amendment No. 169 225 226
 
SDM Test - Refueling (After Implementation of PRNM Upgrade) 3.10.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.10.8.3      -------------------------------NOTE------------------------------
Not required to be met if SR 3.10.8.2 satisfied.
Verify movement of control rods is in compliance                        During control rod with the approved control rod sequence for the SDM                      movement test 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.
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 AND 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                              7 days t 940 psig.
In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.10.8-7              Amendment No. 169 225 226
 
Programs and Manuals 5.5 5.5  Programs and Manuals 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 OPERABLE Control Room Emergency Filtration (CREF) 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 (DBA) 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 Regulatory Guide 1.197, Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors, Revision 0, May 2003, and (ii) assessing CRE habitability at Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.
: 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 CREF 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 the 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 for DBA 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.
INSERT TS 5.5.15 Columbia Generating Station                    5.5-11                Amendment 207,216 225
 
INSERT TS 5.5.15 5.5.15 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.
: a.      The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program.
: 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 Control of Surveillance Frequencies," Revision 1.
: 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.
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TSTF - 425, REVISION 3  - Clean Type of Proposed Technical Specification Pages Page 1 of 1 CLEAN TYPE OF PROPOSED TECHNICAL SPECIFICATION PAGES 3.1.3-4        3.3.2.1-10  3.4.8-2        3.7.6-2 3.1.4-2        3.3.2.1-11  3.4.9-2        3.7.7-1 3.1.5-3        3.3.2.1-12  3.4.10-2      3.8.1-4 3.1.6-2        3.3.2.1-13  3.4.11-2      3.8.1-5 3.1.7-1        3.3.2.2-2    3.4.11-4      3.8.1-6 3.1.7-2        3.3.3.1-2    3.4.12-1      3.8.1-7 3.1.7-3        3.3.3.1-3    3.5.1-3        3.8.1-8 3.1.8-2        3.3.3.1-4    3.5.1-4        3.8.1-9 3.2.1-1        3.3.3.2-1    3.5.1-5        3.8.1-10 3.2.2-1        3.3.3.2-2    3.5.2-2        3.8.1-11 3.2.3-1        3.3.4.1-2    3.5.2-3        3.8.1-12 3.2.4-2        3.3.4.1-3    3.5.2-4        3.8.1-13 3.3.1.1-2      3.3.4.2-2    3.5.3-2        3.8.1-14 3.3.1.1-3      3.3.4.2-3    3.5.3-3        3.8.1-15 3.3.1.1-4      3.3.5.1-5    3.6.1.1-2      3.8.1-16 3.3.1.1-5      3.3.5.1-6    3.6.1.1-3      3.8.3-2 3.3.1.1-6      3.3.5.1-7    3.6.1.2-4      3.8.3-3 3.3.1.1-7      3.3.5.1-8    3.6.1.3-6      3.8.4-4 3.3.1.1-8      3.3.5.1-9    3.6.1.3-7      3.8.6-3 3.3.1.1-9      3.3.5.1-10  3.6.1.3-8      3.8.6-4 3.3.1.1-10    3.3.5.1-11  3.6.1.4-1      3.8.6-5 3.3.1.1-11    3.3.5.2-3    3.6.1.5-1      3.8.7-2 3.3.1.1-12    3.3.6.1-3    3.6.1.5-2      3.8.8-2 3.3.1.1-13    3.3.6.1-4    3.6.1.6-2      3.9.1-1 3.3.1.1-14    3.3.6.2-2    3.6.1.7-2      3.9.2-1 3.3.1.1-15    3.3.6.2-3    3.6.1.7-3      3.9.2-2 3.3.1.1-16    3.3.6.2-4    3.6.2.1-3      3.9.3-1 3.3.1.1-17    3.3.7.1-2    3.6.2.2-1      3.9.5-1 3.3.1.1-18    3.3.7.1-3    3.6.2.3-1      3.9.6-1 3.3.1.1-19    3.3.7.1-4    3.6.3.2-1      3.9.7-1 3.3.1.1-20    3.3.8.1-2    3.6.3.2-2      3.9.8-2 3.3.1.1-21    3.3.8.1-3    3.6.3.3-1      3.9.9-2 3.3.1.2-2      3.3.8.1-4    3.6.4.1-2      3.10.2-2 3.3.1.2-3      3.3.8.2-2    3.6.4.2-3      3.10.3-3 3.3.1.2-4      3.3.8.2-3    3.6.4.3-2      3.10.4-3 3.3.1.3-2      3.4.1-2      3.7.1-2        3.10.5-2 3.3.1.3-3      3.4.1-4      3.7.1-3        3.10.6-2 3.3.2.1-3      3.4.2-2      3.7.2-1        3.10.8-3 3.3.2.1-4      3.4.3-1      3.7.3-3        3.10.8-7 3.3.2.1-5      3.4.4-2      3.7.4-2        5.5-11 3.3.2.1-6      3.4.5-2      3.7.5-2        5.5-12 3.3.2.1-9      3.4.7-3      3.7.6-1
 
Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.1.3.1      Determine the position of each control rod.                            In accordance with the Surveillance Frequency Control Program SR 3.1.3.2      -------------------------------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 RWM.
Insert each partially withdrawn control rod at least                  In accordance one notch.                                                            with the Surveillance Frequency Control Program SR 3.1.3.3      Verify each control rod scram time from fully                          In accordance withdrawn to notch position 5 is d 7 seconds.                          with SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4 SR 3.1.3.4      Verify each control rod does not go to the withdrawn                  Each time the overtravel position.                                                  control rod is withdrawn to "full out" position AND Prior to declaring control rod OPERABLE after work on control rod or CRD System that could affect coupling Columbia Generating Station                      3.1.3-4              Amendment No. 212,216 225
 
Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS
------------------------------------------------------------NOTE-----------------------------------------------------------
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 t 800 psig.                                                              each reactor shutdown  120 days SR 3.1.4.2                Verify, for a representative sample, each tested                        In accordance control rod scram time is within the limits of                          with the Table 3.1.4-1 with reactor steam dome pressure                          Surveillance t 800 psig.                                                              Frequency Control 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 SR 3.1.4.4                Verify each affected control rod scram time is within                    Prior to exceeding the limits of Table 3.1.4-1 with reactor steam dome                      40% RTP after pressure t 800 psig.                                                    fuel movement within the affected core cell AND Prior to exceeding 40% RTP after work on control rod or CRD System that could affect scram time Columbia Generating Station                                3.1.4-2              Amendment No. 194,211 225
 
Control Rod Scram Accumulators 3.1.5 ACTION CONDITION                      REQUIRED ACTION                        COMPLETION TIME C. One or more control rod    C.1    Verify the associated                Immediately upon scram accumulators                  control rod is fully inserted.        discovery of charging inoperable with reactor                                                  water header steam dome pressure                                                      pressure < 940 psig
    < 900 psig.
AND C.2    Declare the associated                1 hour control rod inoperable.
D. Required Action B.1 or      D.1    ---------------NOTE--------------
C.1 and associated                  Not applicable if all Completion Time not                inoperable control rod met.                                scram accumulators are associated 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            In accordance is t 940 psig.                                                with the Surveillance Frequency Control Program Columbia Generating Station                3.1.5-3              Amendment No. 169,216 225
 
Rod Pattern Control 3.1.6 ACTIONS CONDITION                  REQUIRED ACTION              COMPLETION TIME B (continued)                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 BPWS.                                            with the Surveillance Frequency Control Program Columbia Generating Station            3.1.6-2          Amendment No. 149,169 225
 
SLC System 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7      Standby Liquid Control (SLC) System LCO 3.1.7            Two SLC subsystems shall be OPERABLE.
APPLICABILITY:        MODES 1, 2, and 3.
ACTIONS CONDITION                      REQUIRED ACTION            COMPLETION TIME A. One SLC subsystem            A.1    Restore SLC subsystem to  7 days inoperable.                        OPERABLE status.
B. Two SLC subsystems            B.1    Restore one SLC          8 hours inoperable.                        subsystem to OPERABLE status.
C. Required Action and          C.1    Be in MODE 3.            12 hours associated Completion Time not met.              AND C.2    Be in MODE 4.            36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE                                FREQUENCY SR 3.1.7.1        Verify available volume of sodium pentaborate      In accordance solution is t 4587 gallons.                        with the Surveillance Frequency Control Program Columbia Generating Station                  3.1.7-1      Amendment No. 169,199 225
 
SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.1.7.2      Verify temperature of sodium pentaborate solution is    In accordance within the limits of Figure 3.1.7-1.                    with the Surveillance Frequency Control Program SR 3.1.7.3      Verify continuity of explosive charge.                  In accordance with the Surveillance Frequency Control Program SR 3.1.7.4      Verify the concentration of boron in solution is within In accordance the limits of Figure 3.1.7-1.                          with the Surveillance Frequency Control Program AND Once within 24 hours after water or boron is added to solution AND Once within 24 hours after solution temperature is restored within the limits of Figure 3.1.7-1 SR 3.1.7.5      Verify each SLC subsystem manual and power              In accordance operated valve in the flow path that is not locked,    with the sealed, or otherwise secured in position, is in the    Surveillance correct position or can be aligned to the correct      Frequency position.                                              Control Program Columbia Generating Station                3.1.7-2        Amendment No. 169,199 225
 
SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR 3.1.7.6      Verify each pump develops a flow rate t 41.2 gpm    In accordance at a discharge pressure t 1220 psig.                with the Inservice Testing Program SR 3.1.7.7      Verify flow through one SLC subsystem from pump      In accordance into reactor pressure vessel.                        with the Surveillance Frequency Control Program SR 3.1.7.8      Verify all heat traced piping between storage tank  In accordance and pump suction valve is unblocked.                with the Surveillance Frequency Control Program AND Once within 24 hours after solution temperature is restored within the limits of Figure 3.1.7-1 SR 3.1.7.9      Verify sodium pentaborate enrichment is t 44.0      Prior to addition to atom percent B-10.                                  SLC Tank Columbia Generating Station                3.1.7-3        Amendment No. 199,221 225
 
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 closed and fully open position.                                      with the Surveillance Frequency Control Program SR 3.1.8.3      Verify each SDV vent and drain valve:                                In accordance with the
: a. Closes in d 30 seconds after receipt of an                      Surveillance actual or simulated scram signal; and                          Frequency Control Program
: b. Opens when the actual or simulated scram signal is reset.
Columbia Generating Station                      3.1.8-2              Amendment No. 149,169 225
 
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 t 25% RTP.
ACTIONS CONDITION                      REQUIRED ACTION                COMPLETION TIME A. Any APLHGR not within        A.1      Restore APLHGR(s) to        2 hours limits.                              within limits.
B. Required Action and          B.1      Reduce THERMAL              4 hours associated Completion                POWER to < 25% 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 t 25% RTP AND In accordance with the Surveillance Frequency Control Program Columbia Generating Station                  3.2.1-1      Amendment No. 149,169 225
 
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 t 25% 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              4 hours associated Completion                POWER to < 25% 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 t 25% RTP AND In accordance with the Surveillance Frequency Control Program Columbia Generating Station                  3.2.2-1      Amendment No. 169,211 225
 
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 t 25% 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                    4 hours associated Completion              POWER to < 25% 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 t 25% RTP AND In accordance with the Surveillance Frequency Control Program Columbia Generating Station                  3.2.3-1          Amendment No. 149,169 225
 
APRM Gain and Setpoint (Prior to Implementation of PRNM Upgrade) 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.2.4.1      -------------------------------NOTE------------------------------
Not required to be met if SR 3.2.4.2 is satisfied for LCO 3.2.4.b or LCO 3.2.4.c requirements.
Verify MFLPD is within limits.                                        Once within 12 hours after t 25% RTP AND In accordance with the Surveillance Frequency Control Program SR 3.2.4.2      -------------------------------NOTE------------------------------
Not required to be met if SR 3.2.4.1 is satisfied for LCO 3.2.4.a requirements.
Verify each required:                                                In accordance with the
: a. APRM Flow Biased Simulated Thermal Power -                      Surveillance High Function Allowable Value is modified by                    Frequency greater than or equal to the ratio of FRTP and                  Control Program the MFLPD; or
: b. APRM gain is adjusted such that the APRM reading is t 100% times MFLPD.
Columbia Generating Station                      3.2.4-2              Amendment No. 169 225 226
 
RPS Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME E. As required by Required                E.1        Reduce THERMAL                          4 hours Action D.1 and                                  POWER to < 30% RTP.
referenced in Table 3.3.1.1-1.
F. As required by Required                F.1        Be in MODE 2.                            6 hours Action D.1 and referenced in Table 3.3.1.1-1.
G. As required by Required                G.1        Be in MODE 3.                            12 hours Action D.1 and referenced in Table 3.3.1.1-1.
H. As required by Required                H.1        Initiate action to fully insert          Immediately Action D.1 and                                  all insertable control rods in referenced in                                  core cells containing one or Table 3.3.1.1-1.                                more fuel assemblies.
SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTES----------------------------------------------------------
: 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.                                                  In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.1.1-2              Amendment No. 169 225 226
 
RPS Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.3.1.1.2    -------------------------------NOTE------------------------------
Not required to be performed until 12 hours after THERMAL POWER t 25% RTP.
Verify the absolute difference between the average                    In accordance power range monitor (APRM) channels and the                          with the calculated power d 2% RTP plus any gain                              Surveillance adjustment required by LCO 3.2.4, "Average Power                      Frequency Range Monitor (APRM) Gain and Setpoint," while                        Control Program operating at t 25% RTP.
SR 3.3.1.1.3    -------------------------------NOTE------------------------------
Not 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 3.3.1.1.4    Perform CHANNEL FUNCTIONAL TEST.                                      In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.5    Verify the source range monitor (SRM) and                            Prior to intermediate range monitor (IRM) channels overlap.                    withdrawing SRMs from the fully inserted position Columbia Generating Station                    3.3.1.1-3              Amendment No. 169 225 226
 
RPS Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.3.1.1.6    -------------------------------NOTE------------------------------
Only 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 3.3.1.1.7    Calibrate the local power range monitors.                            In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.8    Perform CHANNEL FUNCTIONAL TEST.                                      In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.9    ------------------------------NOTES-----------------------------
: 1. Neutron detectors 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.
Perform CHANNEL CALIBRATION.                                          In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.3.1.1-4              Amendment No. 169 225 226
 
RPS Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.3.1.1.10    ------------------------------NOTES-----------------------------
: 1. Neutron detectors are excluded.
: 2. For Function 1, 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 Frequency Control Program SR 3.3.1.1.11    Verify the APRM Flow Biased Simulated Thermal                        In accordance Power - High Function time constant is d 7 seconds.                  with the Surveillance Frequency Control Program SR 3.3.1.1.12    Verify Turbine Throttle Valve - Closure, and Turbine                  In accordance Governor Valve Fast Closure Trip Oil Pressure -                      with the Low Functions are not bypassed when THERMAL                          Surveillance POWER is t 30% RTP.                                                  Frequency Control Program SR 3.3.1.1.13    Perform CHANNEL FUNCTIONAL TEST.                                      In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.14    Perform LOGIC SYSTEM FUNCTIONAL TEST.                                In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.3.1.1-5              Amendment No. 169 225 226
 
RPS Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.3.1.1.15    ------------------------------NOTES-----------------------------
1 Neutron detectors are excluded.
: 2. Channel sensors for Functions 3 and 4 are excluded.
: 3. For Function 5, "n" equals 4 channels for the purpose of determining the STAGGERED TEST BASIS Frequency.
Verify the RPS RESPONSE TIME is within limits.                        In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.3.1.1-6              Amendment No. 169 225 226
 
RPS Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.1 Table 3.3.1.1-1 (page 1 of 3)
Reactor Protection System Instrumentation APPLICABLE                    CONDITIONS MODES OR      REQUIRED      REFERENCED OTHER      CHANNELS          FROM SPECIFIED      PER TRIP      REQUIRED        SURVEILLANCE      ALLOWABLE FUNCTION              CONDITIONS        SYSTEM        ACTION D.1    REQUIREMENTS          VALUE
: 1. Intermediate Range Monitors
: a. Neutron Flux - High          2            3              G        SR 3.3.1.1.1  d 122/125 SR 3.3.1.1.3  divisions of full SR 3.3.1.1.5  scale SR 3.3.1.1.6 SR 3.3.1.1.10 SR 3.3.1.1.14 (a) 5              3              H        SR 3.3.1.1.1  d 122/125 SR 3.3.1.1.4  divisions of full SR 3.3.1.1.10 scale SR 3.3.1.1.14
: b. Inop                          2            3              G        SR 3.3.1.1.3  NA SR 3.3.1.1.14 (a) 5              3              H        SR 3.3.1.1.4  NA SR 3.3.1.1.14
: 2. Average Power Range Monitors
: a. Neutron Flux - High,          2            2              G        SR 3.3.1.1.1  d 20% RTP Setdown                                                              SR 3.3.1.1.3 SR 3.3.1.1.6 SR 3.3.1.1.7 SR 3.3.1.1.9 SR 3.3.1.1.14
: b. Flow Biased Simulated        1            2              F        SR 3.3.1.1.1  d 0.58 W + 62% RTP Thermal Power - High                                                  SR 3.3.1.1.2  and d 114.9% RTP SR 3.3.1.1.7 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.11 SR 3.3.1.1.14
: c. Fixed Neutron Flux -          1            2              F        SR 3.3.1.1.1  d 120% RTP High                                                                  SR 3.3.1.1.2 SR 3.3.1.1.7 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.14 SR 3.3.1.1.15
: d. Inop                        1,2            2              G        SR 3.3.1.1.7  NA SR 3.3.1.1.8 SR 3.3.1.1.14 (a)    With any control rod withdrawn from a core cell containing one or more fuel assemblies.
Columbia Generating Station                            3.3.1.1-7          Amendment No. 169 225 226
 
RPS Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.1 Table 3.3.1.1-1 (page 2 of 3)
Reactor Protection System Instrumentation APPLICABLE                    CONDITIONS MODES OR      REQUIRED      REFERENCED OTHER      CHANNELS          FROM SPECIFIED      PER TRIP      REQUIRED        SURVEILLANCE      ALLOWABLE FUNCTION                CONDITIONS      SYSTEM        ACTION D.1    REQUIREMENTS          VALUE
: 3. Reactor Vessel Steam              1,2            2              G        SR 3.3.1.1.8  d 1079 psig Dome Pressure - High                                                      SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15
: 4. Reactor Vessel Water Level        1,2            2              G        SR 3.3.1.1.1  t 9.5 inches
        - Low, Level 3                                                            SR 3.3.1.1.8 SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15
: 5. Main Steam Isolation Valve        1            8              F        SR 3.3.1.1.8  d 12.5% closed
        - Closure                                                                  SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15
: 6. Primary Containment              1,2            2              G        SR 3.3.1.1.8  d 1.88 psig Pressure - High                                                            SR 3.3.1.1.10 SR 3.3.1.1.14
: 7. Scram Discharge Volume Water Level - High
: a. Transmitter/Trip Unit        1,2            2              G        SR 3.3.1.1.8  d 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14 (a) 5              2              H        SR 3.3.1.1.8  d 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14
: b. Float Switch                1,2            2              G        SR 3.3.1.1.8  d 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14 (a) 5              2              H        SR 3.3.1.1.8  d 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14
: 8. Turbine Throttle Valve -      t 30% RTP          4              E        SR 3.3.1.1.8  d 7% closed Closure                                                                    SR 3.3.1.1.10 SR 3.3.1.1.12 SR 3.3.1.1.14 SR 3.3.1.1.15 (a)    With any control rod withdrawn from a core cell containing one or more fuel assemblies.
Columbia Generating Station                            3.3.1.1-8          Amendment No. 169 225 226
 
RPS Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.1 Table 3.3.1.1-1 (page 3 of 3)
Reactor Protection System Instrumentation APPLICABLE                    CONDITIONS MODES OR      REQUIRED      REFERENCED OTHER      CHANNELS          FROM SPECIFIED      PER TRIP      REQUIRED        SURVEILLANCE    ALLOWABLE FUNCTION              CONDITIONS        SYSTEM        ACTION D.1    REQUIREMENTS        VALUE
: 9. Turbine Governor Valve      t 30% RTP          2              E        SR 3.3.1.1.8  t 1000 psig Fast Closure, Trip Oil                                                    SR 3.3.1.1.10 Pressure - Low                                                            SR 3.3.1.1.12 SR 3.3.1.1.14 SR 3.3.1.1.15
: 10. Reactor Mode Switch -            1,2            2              G        SR 3.3.1.1.13 NA Shutdown Position                                                          SR 3.3.1.1.14 (a) 5              2              H        SR 3.3.1.1.13 SR 3.3.1.1.14 NA
: 11. Manual Scram                    1,2            2              G        SR 3.3.1.1.4  NA SR 3.3.1.1.14 5(a)          2              H        SR 3.3.1.1.4  NA SR 3.3.1.1.14 (a)    With any control rod withdrawn from a core cell containing one or more fuel assemblies.
Columbia Generating Station                            3.3.1.1-9          Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 3.3 INSTRUMENTATION 3.3.1.1        Reactor Protection System (RPS) Instrumentation LCO 3.3.1.1                  The RPS instrumentation for each Function in Table 3.3.1.1-1 shall be OPERABLE.
APPLICABILITY:                According to Table 3.3.1.1-1 after implementation of Power Range Neutron Monitor (PRNM) upgrade.
ACTIONS
------------------------------------------------------------NOTE-----------------------------------------------------------
Separate Condition entry is allowed for each channel.
CONDITION                                REQUIRED ACTION                            COMPLETION TIME A. One or more required                  A.1        Place channel in trip.                  12 hours channels inoperable.
OR
                                                      -------------NOTE---------------
Not applicable for Functions 2.a, 2.b, 2.c, 2.d, or 2.f.
A.2        Place associated trip                    12 hours system in trip.
  ---------------NOTE--------------        B.1        Place channel in one trip                6 hours Not applicable for                              system in trip.
Functions 2.a, 2.b, 2.c, 2.d, or 2.f.                        OR B.2        Place one trip system in                6 hours B. One or more Functions                            trip.
with one or more required channels inoperable in both trip systems.
Columbia Generating Station                              3.3.1.1-10                        Amendment No. 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 ACTIONS CONDITION                  REQUIRED ACTION                  COMPLETION TIME C. One or more Functions    C.1    Restore RPS trip capability. 1 hour with RPS trip capability not maintained.
D. Required Action and      D.1    Enter the Condition            Immediately associated Completion          referenced in Time of Condition A, B,        Table 3.3.1.1-1 for the or C not met.                  channel.
E. As required by Required  E.1    Reduce THERMAL                  4 hours Action D.1 and                  POWER to < 30% RTP.
referenced in Table 3.3.1.1-1.
F. As required by Required  F.1    Be in MODE 2.                  6 hours Action D.1 and referenced in Table 3.3.1.1-1.
G. As required by Required  G.1    Be in MODE 3.                  12 hours Action D.1 and referenced in Table 3.3.1.1-1.
H. As required by Required  H.1    Initiate action to fully insert Immediately Action D.1 and                  all insertable control rods in referenced in                  core cells containing one or Table 3.3.1.1-1.                more fuel assemblies.
Columbia Generating Station          3.3.1.1-11          Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME I. As required by Required              I.1        Initiate alternate method to            12 hours Action D.1 and                                  detect and suppress referenced in                                  thermal hydraulic instability Table 3.3.1.1-1.                                oscillations.
AND
                                                      ---------------NOTE-------------
LCO 3.0.4 is not applicable.
I.2        Restore required channels                120 days to OPERABLE J. Required Action and                    J.1        Reduce THERMAL                          4 hours associated Completion                          POWER to less than the Time of Condition I not                        value specified in the met.                                            COLR.
SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTES----------------------------------------------------------
: 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.                                                  In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.1.1-12              Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.3.1.1.2    -------------------------------NOTE------------------------------
Not required to be performed until 12 hours after THERMAL POWER t 25% RTP.
Verify the absolute difference between the average                    In accordance power range monitor (APRM) channels and the                          with the calculated power d 2% RTP while operating at                          Surveillance t 25% RTP.                                                            Frequency Control Program SR 3.3.1.1.3    -------------------------------NOTE------------------------------
Not 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 3.3.1.1.4    Perform CHANNEL FUNCTIONAL TEST.                                      In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.5    Verify the source range monitor (SRM) and                            Prior to intermediate range monitor (IRM) channels overlap.                    withdrawing SRMs from the fully inserted position Columbia Generating Station                    3.3.1.1-13            Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.3.1.1.6    -------------------------------NOTE------------------------------
Only 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 3.3.1.1.7    Calibrate the local power range monitors.                            In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.8    Perform CHANNEL FUNCTIONAL TEST.                                      In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.9    Deleted.
SR 3.3.1.1.10    ------------------------------NOTES-----------------------------
: 1. Neutron detectors are excluded.
: 2. For Function 1, not required to be performed when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2.
: 3. For Functions 2.b and 2.f, the recirculation flow transmitters that feed the APRMs are included.
Perform CHANNEL CALIBRATION.                                          In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.3.1.1-14            Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR 3.3.1.1.11    Deleted.
SR 3.3.1.1.12    Verify Turbine Throttle Valve - Closure, and Turbine  In accordance Governor Valve Fast Closure Trip Oil Pressure -      with the Low Functions are not bypassed when THERMAL          Surveillance POWER is t 30% RTP.                                  Frequency Control Program SR 3.3.1.1.13    Perform CHANNEL FUNCTIONAL TEST.                      In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.14    Perform LOGIC SYSTEM FUNCTIONAL TEST.                In accordance with the Surveillance Frequency Control Program Columbia Generating Station              3.3.1.1-15        Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.3.1.1.15    ------------------------------NOTES-----------------------------
: 1. Neutron detectors are excluded.
: 2. Channel sensors for Functions 3 and 4 are excluded.
: 3. For Function 5, "n" equals 4 channels for the purpose of determining the STAGGERED TEST BASIS Frequency.
: 4. For Function 2.e, "n" equals 8 channels for the purpose of determining the STAGGERED TEST BASIS Frequency. Testing of APRM and oscillation power range monitor (OPRM) outputs shall alternate.
Verify the RPS RESPONSE TIME is within limits.                        In accordance with the Surveillance Frequency Control Program SR 3.3.1.1.16    ------------------------------NOTES-----------------------------
: 1. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours after entering MODE 2.
: 2. For Functions 2.b and 2.f, the CHANNEL FUNCTIONAL TEST includes the recirculation flow input processing, excluding the flow transmitters.
Perform CHANNEL FUNCTIONAL TEST.                                      In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.3.1.1-16            Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.3.1.1.17    Verify the OPRM is not bypassed when APRM              In accordance Simulated Thermal Power is greater than or equal to    with the the value specified in the COLR and recirculation      Surveillance drive flow is less than the value specified in the    Frequency COLR.                                                  Control Program Columbia Generating Station              3.3.1.1-17        Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 Table 3.3.1.1-1 (page 1 of 4)
Reactor Protection System Instrumentation APPLICABLE                    CONDITIONS MODES OR      REQUIRED    REFERENCED OTHER      CHANNELS          FROM SPECIFIED      PER TRIP      REQUIRED      SURVEILLANCE                ALLOWABLE FUNCTION                CONDITIONS      SYSTEM        ACTION D.1    REQUIREMENTS                  VALUE
: 1. Intermediate Range Monitors
: a. Neutron Flux - High          2              3              G        SR  3.3.1.1.1          d 122/125 SR  3.3.1.1.3          divisions of full SR  3.3.1.1.5          scale SR  3.3.1.1.6 SR  3.3.1.1.10 SR  3.3.1.1.14 (a) 5              3              H        SR  3.3.1.1.1          d 122/125 SR  3.3.1.1.4          divisions of full SR  3.3.1.1.10          scale SR  3.3.1.1.14
: b. Inop                          2              3              G        SR 3.3.1.1.3            NA SR 3.3.1.1.14 (a) 5              3              H        SR 3.3.1.1.4            NA SR 3.3.1.1.14
: 2. Average Power Range Monitors (b)
: a. Neutron Flux - High          2            3              G        SR  3.3.1.1.1          d 20% RTP (Setdown)                                                            SR  3.3.1.1.6 SR  3.3.1.1.7 (d),(e)
SR  3.3.1.1.10 SR  3.3.1.1.16 (b)
: b. Simulated Thermal            1            3              F        SR  3.3.1.1.1          d 0.63W + 64.0% RTP (c)
Power - High                                                        SR  3.3.1.1.2          and d 114.9% RTP SR  3.3.1.1.7 (d),(e)
SR  3.3.1.1.10 SR  3.3.1.1.16 (a)    With any control rod withdrawn from a core cell containing one or more fuel assemblies.
(b)    Each APRM/OPRM channel provides inputs to both trip systems.
(c)     0.63W + 60.8% RTP and  114.9% RTP when reset for single loop operation per LCO 3.4.1, Recirculation Loops Operating.
(d)    If the as-found channel setpoint is outside its predefined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.
(e)    The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.
Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the surveillance procedures (Nominal Trip Setpoint) to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in the Licensee Controlled Specifications.
Columbia Generating Station                              3.3.1.1-18            Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 Table 3.3.1.1-1 (page 2 of 4)
Reactor Protection System Instrumentation APPLICABLE                  CONDITIONS MODES OR      REQUIRED    REFERENCED OTHER        CHANNELS          FROM SPECIFIED      PER TRIP      REQUIRED        SURVEILLANCE          ALLOWABLE FUNCTION                  CONDITIONS      SYSTEM        ACTION D.1    REQUIREMENTS                VALUE
: 2. Average Power Range Monitors (b)
: c. Neutron Flux - High            1            3              F        SR 3.3.1.1.1          d 120% RTP SR 3.3.1.1.2 SR 3.3.1.1.7 (d),(e)
SR 3.3.1.1.10 SR 3.3.1.1.16 (b)
: d. Inop                          1,2          3              G        SR 3.3.1.1.16        NA
: e. 2-Out-of-4 Voter              1,2            2              G        SR 3.3.1.1.1          NA SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.16 (b)                                              (g)
: f. OPRM Upscale                  (f)          3              I        SR 3.3.1.1.1          NA SR 3.3.1.1.7 (d),(e)
SR 3.3.1.1.10 SR 3.3.1.1.16 SR 3.3.1.1.17 (b)    Each APRM/OPRM channel provides inputs to both trip systems.
(d)    If the as-found channel setpoint is outside its predefined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.
(e)    The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.
Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the surveillance procedures (Nominal Trip Setpoint) to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in the Licensee Controlled Specifications.
(f)    THERMAL POWER greater than or equal to the value specified in the COLR.
(g)    The OPRM Upscale does not have an Allowable Value. The Period Based Detection Algorithm (PBDA) trip setpoints are specified in the COLR.
Columbia Generating Station                              3.3.1.1-19            Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 Table 3.3.1.1-1 (page 3 of 4)
Reactor Protection System Instrumentation APPLICABLE                  CONDITIONS MODES OR      REQUIRED    REFERENCED OTHER      CHANNELS        FROM SPECIFIED      PER TRIP      REQUIRED      SURVEILLANCE      ALLOWABLE FUNCTION                CONDITIONS      SYSTEM        ACTION D.1    REQUIREMENTS          VALUE
: 3. Reactor Vessel Steam            1,2            2            G        SR  3.3.1.1.8    d 1079 psig Dome Pressure - High                                                    SR  3.3.1.1.10 SR  3.3.1.1.14 SR  3.3.1.1.15
: 4. Reactor Vessel Water            1,2            2            G        SR  3.3.1.1.1    t 9.5 inches Level - Low, Level 3                                                    SR  3.3.1.1.8 SR  3.3.1.1.10 SR  3.3.1.1.14 SR  3.3.1.1.15
: 5. Main Steam Isolation Valve        1            8            F        SR  3.3.1.1.8    d 12.5% closed
        - Closure                                                              SR  3.3.1.1.10 SR  3.3.1.1.14 SR  3.3.1.1.15
: 6. Primary Containment              1,2            2            G        SR 3.3.1.1.8      d 1.88 psig Pressure - High                                                        SR 3.3.1.1.10 SR 3.3.1.1.14
: 7. Scram Discharge Volume Water Level - High
: a. Transmitter/Trip Unit      1,2            2            G        SR 3.3.1.1.8  d 529 ft 9 inches SR 3.3.1.1.10  elevation SR 3.3.1.1.14 5(a)          2            H        SR 3.3.1.1.8  d 529 ft 9 inches SR 3.3.1.1.10  elevation SR 3.3.1.1.14
: b. Float Switch                1,2            2            G        SR 3.3.1.1.8  d 529 ft 9 inches SR 3.3.1.1.10  elevation SR 3.3.1.1.14 (a) 5              2            H        SR 3.3.1.1.8  d 529 ft 9 inches SR 3.3.1.1.10  elevation SR 3.3.1.1.14
: 8. Turbine Throttle Valve -    t 30% RTP          4            E        SR  3.3.1.1.8  d 7% closed Closure                                                                SR  3.3.1.1.10 SR  3.3.1.1.12 SR  3.3.1.1.14 SR  3.3.1.1.15 (a)    With any control rod withdrawn from a core cell containing one or more fuel assemblies.
Columbia Generating Station                          3.3.1.1-20          Amendment No. 169 225 226
 
RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 Table 3.3.1.1-1 (page 4 of 4)
Reactor Protection System Instrumentation APPLICABLE                  CONDITIONS MODES OR      REQUIRED      REFERENCED OTHER      CHANNELS        FROM SPECIFIED      PER TRIP      REQUIRED      SURVEILLANCE      ALLOWABLE FUNCTION                CONDITIONS      SYSTEM        ACTION D.1    REQUIREMENTS          VALUE
: 9. Turbine Governor Valve      t 30% RTP          2              E        SR  3.3.1.1.8  t 1000 psig Fast Closure, Trip Oil                                                  SR  3.3.1.1.10 Pressure - Low                                                          SR  3.3.1.1.12 SR  3.3.1.1.14 SR  3.3.1.1.15
: 10. Reactor Mode Switch -            1,2            2              G        SR 3.3.1.1.13  NA Shutdown Position                                                      SR 3.3.1.1.14 (a) 5              2              H        SR 3.3.1.1.13 SR 3.3.1.1.14  NA
: 11. Manual Scram                    1,2            2              G        SR 3.3.1.1.4    NA SR 3.3.1.1.14 (a) 5              2              H        SR 3.3.1.1.4    NA SR 3.3.1.1.14 (a)    With any control rod withdrawn from a core cell containing one or more fuel assemblies.
Columbia Generating Station                          3.3.1.1-21          Amendment No. 169 225 226
 
SRM Instrumentation 3.3.1.2 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME E. One or more required                  E.1        Suspend CORE                            Immediately SRMs inoperable in                              ALTERATIONS except for MODE 5.                                        control rod insertion.
AND E.2        Initiate action to fully insert          Immediately all insertable control rods in core cells containing one or more fuel assemblies.
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 Columbia Generating Station                              3.3.1.2-2              Amendment No. 149,169 225
 
SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY 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:                        In accordance with the
: a. The fueled region;                                              Surveillance Frequency
: b. The core quadrant where CORE                                    Control Program 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.                                                In accordance with the Surveillance Frequency Control Program SR 3.3.1.2.4    -------------------------------NOTE------------------------------
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:                                                  In accordance with the
: a. t 3.0 cps with a signal to noise ratio t 2:1 or                  Surveillance Frequency
: b. t 0.7 cps with a signal to noise ratio t 20:1.                  Control Program Columbia Generating Station                    3.3.1.2-3              Amendment No. 149,169 225
 
SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.3.1.2.5    -------------------------------NOTE------------------------------
The determination of signal to noise ratio is 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.
Perform CHANNEL FUNCTIONAL TEST and                                    In accordance determination of signal to noise ratio.                                with the Surveillance Frequency Control Program SR 3.3.1.2.6    -------------------------------NOTE------------------------------
Not required to be performed until 12 hours after IRMs on Range 2 or below.
Perform CHANNEL FUNCTIONAL TEST and                                    In accordance determination of signal to noise ratio.                                with the Surveillance Frequency Control Program SR 3.3.1.2.7    ------------------------------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 Columbia Generating Station                    3.3.1.2-4              Amendment No. 149,169 225
 
OPRM Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.3 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 OPRM System maintains trip capability.
SURVEILLANCE                                                    FREQUENCY SR 3.3.1.3.1              Perform CHANNEL FUNCTIONAL TEST.                                        In accordance with the Surveillance Frequency Control Program SR 3.3.1.3.2              Calibrate the local power range monitors.                                In accordance with the Surveillance Frequency Control Program SR 3.3.1.3.3              -------------------------------NOTE------------------------------
Neutron detectors are excluded.
Perform CHANNEL CALIBRATION.                                            In accordance with the Surveillance Frequency Control Program SR 3.3.1.3.4              Perform LOGIC SYSTEM FUNCTIONAL TEST.                                    In accordance with the Surveillance Frequency Control Program SR 3.3.1.3.5              Verify OPRM is not bypassed when THERMAL                                In accordance POWER is t 30% RTP and core flow d 60% rated                            with the core flow.                                                              Surveillance Frequency Control Program Columbia Generating Station                              3.3.1.3-2              Amendment No. 171 225 226
 
OPRM Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.3.1.3.6    -----------------------------NOTE--------------------------------
Neutron detectors are excluded.
Verify the RPS RESPONSE TIME is within limits.                        In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.3.1.3-3              Amendment No. 171 225 226
 
Control Rod Block Instrumentation (Prior to Implementation of PRNM Upgrade) 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 an RBM 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              Perform CHANNEL FUNCTIONAL TEST.                                        In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.2              -------------------------------NOTE------------------------------
Not required to be performed until 1 hour after any control rod is withdrawn at d 10% RTP in MODE 2.
Perform CHANNEL FUNCTIONAL TEST.                                        In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.3              -------------------------------NOTE------------------------------
Not required to be performed until 1 hour after THERMAL POWER is d 10% RTP in MODE 1.
Perform CHANNEL FUNCTIONAL TEST.                                        In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.2.1-3              Amendment No. 169 225 226
 
Control Rod Block Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.3.2.1.4    -------------------------------NOTE------------------------------
Neutron detectors are excluded.
Verify the RBM is not bypassed:                                      In accordance with the
: a. When THERMAL POWER is t 30% RTP; and                            Surveillance Frequency
: b. When a peripheral control rod is not selected.                  Control Program SR 3.3.2.1.5    -------------------------------NOTE------------------------------
Neutron detectors are excluded.
Perform CHANNEL CALIBRATION.                                          In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.6    Verify the RWM is not bypassed when THERMAL                          In accordance POWER is d 10% RTP.                                                  with the Surveillance Frequency Control Program SR 3.3.2.1.7    -------------------------------NOTE------------------------------
Not 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 Columbia Generating Station                    3.3.2.1-4              Amendment No. 169 225 226
 
Control Rod Block Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.3.2.1.8    Verify control rod sequences input to the RWM are      Prior to declaring in conformance with BPWS.                              RWM OPERABLE following loading of sequence into RWM Columbia Generating Station              3.3.2.1-5        Amendment No. 169 225 226
 
Control Rod Block Instrumentation (Prior to Implementation of PRNM Upgrade) 3.3.2.1 Table 3.3.2.1-1 (page 1 of 1)
Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED      REQUIRED  SURVEILLANCE    ALLOWABLE FUNCTION                    CONDITIONS      CHANNELS    REQUIREMENTS        VALUE
: 1. Rod Block Monitor
: a. Upscale                                (a)          2        SR 3.3.2.1.1 d 0.58W + 51 %
SR 3.3.2.1.4 RTP SR 3.3.2.1.5
: b. Inop                                  (a)          2        SR 3.3.2.1.1 NA SR 3.3.2.1.4
: c. Downscale                              (a)          2        SR 3.3.2.1.1 t 3% RTP SR 3.3.2.1.4 SR 3.3.2.1.5
: 2. Rod Worth Minimizer                      1(b), 2(b)      1        SR 3.3.2.1.2 NA SR 3.3.2.1.3 SR 3.3.2.1.6 SR 3.3.2.1.8
: 3. Reactor Mode Switch - Shutdown              (c)          2        SR 3.3.2.1.7 NA Position (a)    THERMAL POWER t 30% RTP and no peripheral control rod selected.
(b)    With THERMAL POWER d 10% RTP.
(c)    Reactor mode switch in the shutdown position.
Columbia Generating Station                          3.3.2.1-6        Amendment No. 169 225 226
 
Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) 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 an RBM 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              Perform CHANNEL FUNCTIONAL TEST.                                        In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.2              -------------------------------NOTE------------------------------
Not required to be performed until 1 hour after any control rod is withdrawn at d 10% RTP in MODE 2.
Perform CHANNEL FUNCTIONAL TEST.                                        In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.3              -------------------------------NOTE------------------------------
Not required to be performed until 1 hour after THERMAL POWER is d 10% RTP in MODE 1.
Perform CHANNEL FUNCTIONAL TEST.                                        In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.2.1-9              Amendment No. 169 225 226
 
Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.3.2.1.4      -------------------------------NOTE------------------------------
Neutron detectors are excluded.
Verify the RBM is not bypassed:                                      In accordance with the
: a. Low Power Range - Upscale Function is not                      Surveillance bypassed when APRM Simulated Thermal                            Frequency Power is  28% and < 63% RTP and peripheral                    Control Program control rod is not selected.
: b. Intermediate Power Range - Upscale Function is not bypassed when APRM Simulated Thermal Power is  63% and < 83% RTP and peripheral control rod is not selected.
: c. High Power Range - Upscale Function is not bypassed when APRM Simulated Thermal Power is  83% and peripheral control rod is not selected.
SR 3.3.2.1.5      -------------------------------NOTE------------------------------
Neutron detectors are excluded.
Perform CHANNEL CALIBRATION.                                          In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.6      Verify the RWM is not bypassed when THERMAL                          In accordance POWER is d 10% RTP.                                                  with the Surveillance Frequency Control Program Columbia Generating Station                      3.3.2.1-10            Amendment No. 169 225 226
 
Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.3.2.1.7      -------------------------------NOTE------------------------------
Not 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 3.3.2.1.8      Verify control rod sequences input to the RWM are                    Prior to declaring in conformance with BPWS.                                            RWM OPERABLE following loading of sequence into RWM Columbia Generating Station                      3.3.2.1-11            Amendment No. 169 225 226
 
Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) 3.3.2.1 Table 3.3.2.1-1 (page 1 of 2)
Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED      REQUIRED          SURVEILLANCE          ALLOWABLE FUNCTION                        CONDITIONS      CHANNELS        REQUIREMENTS              VALUE
: 1. Rod Block Monitor
: a. Low Power Range - Upscale                  (a)            2            SR 3.3.2.1.1        (f)
SR 3.3.2.1.4 SR 3.3.2.1.5(d),(e)
: b. Intermediate Power Range -                (b)            2            SR 3.3.2.1.1        (f)
Upscale                                                                  SR 3.3.2.1.4 SR 3.3.2.1.5(d),(e)
: c. High Power Range - Upscale                (c)            2            SR 3.3.2.1.1        (f)
SR 3.3.2.1.4 SR 3.3.2.1.5(d),(e)
: d. Inop                                  (a),(b),(c)        2            SR 3.3.2.1.1        NA (a)    APRM Simulated Thermal Power is  28% and < 63% RTP and MCPR is less than the limit specified in the COLR and no peripheral control rod selected.
(b)    APRM Simulated Thermal Power is  63% and < 83% RTP and MCPR is less than the limit specified in the COLR and no peripheral control rod selected.
(c)    APRM Simulated Thermal Power is  83% and MCPR is less than the limit specified in the COLR and no peripheral control rod selected.
(d)    If the as-found channel setpoint is outside its predefined as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service.
(e)    The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.
Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the surveillance procedures (Nominal Trip Setpoint) to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in the Licensee Controlled Specifications.
(f)    Allowable Value Specified in the COLR.
Columbia Generating Station                                3.3.2.1-12          Amendment No. 169 225 226
 
Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) 3.3.2.1 Table 3.3.2.1-1 (page 2 of 2)
Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED      REQUIRED SURVEILLANCE  ALLOWABLE FUNCTION                    CONDITIONS      CHANNELS REQUIREMENTS    VALUE (g)  (g)
: 2. Rod Worth Minimizer                      1 ,2            1      SR 3.3.2.1.2 NA SR 3.3.2.1.3 SR 3.3.2.1.6 SR 3.3.2.1.8
: 3. Reactor Mode Switch - Shutdown              (h)          2      SR 3.3.2.1.7 NA Position (g)    With THERMAL POWER d 10% RTP.
(h)    Reactor mode switch in the shutdown position.
Columbia Generating Station                          3.3.2.1-13          Amendment No. 226
 
Feedwater and Main Turbine High Water Level Trip Instrumentation 3.3.2.2 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 feedwater and main turbine high water level trip capability is maintained.
SURVEILLANCE                                                      FREQUENCY SR 3.3.2.2.1              Perform CHANNEL CHECK.                                                  In accordance with the Surveillance Frequency Control Program SR 3.3.2.2.2              Perform CHANNEL FUNCTIONAL TEST.                                        In accordance with the Surveillance Frequency Control Program SR 3.3.2.2.3              Perform CHANNEL CALIBRATION. The Allowable                              In accordance Value shall be d 56.0 inches.                                            with the Surveillance Frequency Control Program SR 3.3.2.2.4              Perform LOGIC SYSTEM FUNCTIONAL TEST,                                    In accordance including valve actuation.                                              with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.2.2-2              Amendment No. 149,169 225
 
PAM Instrumentation 3.3.3.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME E. As required by Required                E.1        Be in MODE 3.                            12 hours Action D.1 and referenced in Table 3.3.3.1-1.
F. As required by Required                F.1        Initiate action in accordance            Immediately Action D.1 and                                  with Specification 5.6.4.
referenced in Table 3.3.3.1-1.
SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTES----------------------------------------------------------
: 1.        These SRs apply to each Function in Table 3.3.3.1-1.
: 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 other required channel(s) in the associated Function is OPERABLE.
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 for Functions 1,                            In accordance 2, 4, 5, and 10.                                                        with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.3.1-2              Amendment No.189,190 225
 
PAM Instrumentation 3.3.3.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                          FREQUENCY SR 3.3.3.1.4    Perform CHANNEL CALIBRATION for              In accordance Functions 3, 6, and 7.                      with the Surveillance Frequency Control Program Columbia Generating Station              3.3.3.1-3 Amendment No.189,190 225
 
PAM Instrumentation 3.3.3.1 Table 3.3.3.1-1 (page 1 of 1)
Post Accident Monitoring Instrumentation CONDITIONS REFERENCED REQUIRED                FROM REQUIRED FUNCTION                                      CHANNELS                    ACTION D.1
: 1. Reactor Vessel Pressure                                                2                          E
: 2. Reactor Vessel Water Level
: a.  -150 inches to +60 inches                                        2                          E
: b.  -310 inches to -110 inches                                        2                          E
: 3. Suppression Pool Water Level
: a.  -25 inches to +25 inches                                          2                          E
: b. 2 ft to 52 ft                                                    2                          E
: 4. Suppression Chamber Pressure                                          2                          E
: 5. Drywell Pressure
: a.  -5 psig to +3 psig                                                2                          E
: b. 0 psig to 25 psig                                                2                          E
: c. 0 psig to 180 psig                                                2                          E
: 6. Primary Containment Area Radiation                                    2                          F
: 7. Penetration Flow Path PCIV Position                          2 per penetration flow                E (a) (b) path
: 8. Deleted
: 9. Deleted
: 10. ECCS Pump Room Flood Level                                            5                          E (a)  Not required for isolation valves whose associated penetration flow path is isolated by at least one closed and de-activated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.
(b)  Only one position indication channel is required for penetration flow paths with only one installed control room indication channel.
Columbia Generating Station                            3.3.3.1-4            Amendment No. 189,208 225
 
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
-----------------------------------------------------------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.
SURVEILLANCE                                                      FREQUENCY SR 3.3.3.2.1              Perform CHANNEL CHECK for each required                                  In accordance instrumentation channel that is normally energized.                      with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.3.2-1              Amendment No. 169,187 225
 
Remote Shutdown System 3.3.3.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.3.3.2.2    Perform CHANNEL CALIBRATION for each                  In accordance required instrumentation channel, except the          with the suppression pool water level instrumentation          Surveillance channel.                                              Frequency Control Program SR 3.3.3.2.3    Perform CHANNEL CALIBRATION for the                    In accordance suppression pool water level instrumentation          with the channel.                                              Surveillance Frequency Control Program SR 3.3.3.2.4    Verify each required control circuit and transfer      In accordance switch is capable of performing the intended          with the functions.                                            Surveillance Frequency Control Program Columbia Generating Station              3.3.3.2-2          Amendment No. 149,169 225
 
EOC-RPT Instrumentation 3.3.4.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME B. One or more Functions                  B.1        Restore EOC-RPT trip                    2 hours with EOC-RPT trip                              capability.
capability not maintained.                          OR AND                                  B.2        Apply the MCPR limit for                2 hours inoperable EOC-RPT as MCPR limit for                                  specified in the COLR.
inoperable EOC-RPT not made applicable.
C. Required Action and                    C.1        Remove the associated                    4 hours associated Completion                          recirculation pump from Time not met.                                  service.
OR C.2        Reduce THERMAL                          4 hours POWER to < 30% RTP.
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 Columbia Generating Station                              3.3.4.1-2              Amendment No. 149,169 225
 
EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.3.4.1.2.a  Perform CHANNEL CALIBRATION. The Allowable                            In accordance Value shall be:                                                      with the Surveillance TTV - Closure: d 7% closed.                                          Frequency Control Program SR 3.3.4.1.2.b  Perform CHANNEL CALIBRATION. The Allowable                            In accordance Value shall be:                                                      with the Surveillance TGV Fast Closure, Trip Oil Pressure - Low:                            Frequency t 1000 psig.                                                          Control Program SR 3.3.4.1.3    Verify TTV - Closure and TGV Fast Closure, Trip                      In accordance Oil Pressure - Low Functions are not bypassed                        with the when THERMAL POWER is t 30% RTP.                                      Surveillance Frequency Control Program SR 3.3.4.1.4    Perform LOGIC SYSTEM FUNCTIONAL TEST,                                In accordance including breaker actuation.                                          with the Surveillance Frequency Control Program SR 3.3.4.1.5    -------------------------------NOTE------------------------------
Breaker arc suppression time may be assumed from the most recent performance of SR 3.3.4.1.6.
Verify the EOC-RPT SYSTEM RESPONSE TIME is                            In accordance within limits.                                                        with the Surveillance Frequency Control Program SR 3.3.4.1.6    Determine RPT breaker arc suppression time.                          In accordance with the Surveillance Frequency Control Program Columbia Generating Station                    3.3.4.1-3              Amendment No. 149,169 225
 
ATWS-RPT Instrumentation 3.3.4.2 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME C. Both Functions with                    C.1        Restore ATWS-RPT trip                    1 hour ATWS-RPT trip                                  capability for one Function.
capability 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 for Reactor Vessel                                In accordance Water Level - Low Low, Level 2 Function.                                with the Surveillance Frequency Control Program SR 3.3.4.2.2              Perform CHANNEL FUNCTIONAL TEST.                                        In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.4.2-2              Amendment No. 149,169 225
 
ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                FREQUENCY SR 3.3.4.2.3    Perform CHANNEL CALIBRATION. The Allowable          In accordance Values shall be:                                    with the Surveillance
: a. Reactor Vessel Water Level - Low Low, Level 2: Frequency t -58 inches; and                              Control Program
: b. Reactor Vessel Steam Dome Pressure - High:
d 1143 psig.
SR 3.3.4.2.4    Perform LOGIC SYSTEM FUNCTIONAL TEST,              In accordance including breaker actuation.                        with the Surveillance Frequency Control Program Columbia Generating Station              3.3.4.2-3      Amendment No. 149,169 225
 
ECCS Instrumentation 3.3.5.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME H. Required Action and                    H.1        Declare associated                      Immediately associated Completion                          supported feature(s)
Time of Condition B, C,                        inoperable.
D, E, F, or G not met.
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, and 3.g; and (b) for up to 6 hours for Functions other than 3.c, 3.f, and 3.g 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              Perform CHANNEL CALIBRATION.                                            In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.5.1-5                Amendment No. 150,169 225
 
ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                      FREQUENCY 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 Frequency Control Program SR 3.3.5.1.6    Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program Columbia Generating Station          3.3.5.1-6    Amendment No. 150,169 225
 
ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 1 of 5)
Emergency Core Cooling System Instrumentation APPLICABLE                  CONDITIONS MODES OR      REQUIRED    REFERENCED OTHER        CHANNELS        FROM SPECIFIED        PER        REQUIRED  SURVEILLANCE      ALLOWABLE FUNCTION                  CONDITIONS      FUNCTION      ACTION A.1  REQUIREMENTS          VALUE
: 1. Low Pressure Coolant Injection-A (LPCI) and Low Pressure Core Spray (LPCS)
Subsystems (b)
: a. Reactor Vessel              1, 2, 3,        2              B    SR  3.3.5.1.1    t -142.3 inches Water Level - Low          4(a), 5(a)                            SR  3.3.5.1.2 Low Low, Level 1                                                  SR  3.3.5.1.4 SR  3.3.5.1.6
: b. Drywell Pressure -          1, 2, 3        2(b)          B    SR 3.3.5.1.2    d 1.88 psig High                                                              SR 3.3.5.1.4 SR 3.3.5.1.6
: c. LPCS Pump Start -          1, 2, 3,        1(e)          C    SR 3.3.5.1.5    t 8.53 seconds (a)  (a)
LOCA Time Delay            4 ,5                                  SR 3.3.5.1.6    and Relay                                                                              d 10.64 seconds (e)
: d. LPCI Pump A Start -        1, 2, 3,        1              C    SR 3.3.5.1.5    t 17.24 seconds (a)  (a)
LOCA Time Delay            4 ,5                                  SR 3.3.5.1.6    and d 21.53 Relay                                                                              seconds
: e. LPCI Pump A Start -        1, 2, 3,          1            C    SR 3.3.5.1.2    t 3.04 seconds (a)  (a)
LOCA/LOOP Time              4 ,5                                  SR 3.3.5.1.3    and Delay Relay                                                      SR 3.3.5.1.6    d 6.00 seconds
: f. Reactor Vessel              1, 2, 3    1 per valve        C    SR 3.3.5.1.2    t 448 psig and Pressure - Low                                                    SR 3.3.5.1.4    d 492 psig (Injection                                                        SR 3.3.5.1.6 Permissive)
(a)  (a) 4 ,5        1 per valve        B    SR 3.3.5.1.2    t 448 psig and SR 3.3.5.1.4    d 492 psig SR 3.3.5.1.6 (a)  When associated subsystem(s) are required to be OPERABLE.
(b)  Also required to initiate the associated diesel generator (DG).
(e)  Also supports OPERABILITY of 230 kV offsite power circuit pursuant to LCO 3.8.1 and LCO 3.8.2.
Columbia Generating Station                            3.3.5.1-7          Amendment No. 169,172 225
 
ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 2 of 5)
Emergency Core Cooling System Instrumentation APPLICABLE                  CONDITIONS MODES OR      REQUIRED    REFERENCED OTHER        CHANNELS        FROM SPECIFIED        PER        REQUIRED    SURVEILLANCE      ALLOWABLE FUNCTION                  CONDITIONS      FUNCTION    ACTION A.1  REQUIREMENTS          VALUE
: 1. LPCI and LPCS Subsystems
: g. LPCS Pump                  1, 2, 3,          1            E      SR 3.3.5.1.2    t 668 gpm and Discharge Flow -            4(a), 5(a)                            SR 3.3.5.1.4    d 1067 gpm Low (Minimum Flow)                                                SR 3.3.5.1.6
: h. LPCI Pump A                1, 2, 3,          1            E      SR 3.3.5.1.2    t 605 gpm and (a)  (a)
Discharge Flow -            4 ,5                                  SR 3.3.5.1.4    d 984 gpm Low (Minimum Flow)                                                SR 3.3.5.1.6
: i. Manual Initiation          1, 2, 3,          2            C      SR 3.3.5.1.6    NA (a)  (a) 4 ,5
: 2. LPCI B and LPCI C Subsystems (b)
: a. Reactor Vessel              1, 2, 3,        2            B      SR  3.3.5.1.1    t -142.3 inches Water Level - Low          4(a), 5(a)                            SR  3.3.5.1.2 Low Low, Level 1                                                  SR  3.3.5.1.4 SR  3.3.5.1.6
: b. Drywell Pressure -          1, 2, 3        2(b)          B      SR 3.3.5.1.2    d 1.88 psig High                                                              SR 3.3.5.1.4 SR 3.3.5.1.6
: c. LPCI Pump B Start -        1, 2, 3,        1(e)          C      SR 3.3.5.1.5    t 17.24 seconds (a)  (a)
LOCA Time Delay            4 ,5                                  SR 3.3.5.1.6    and Relay                                                                              d 21.53 seconds (e)
: d. LPCI Pump C Start -        1, 2, 3,        1            C      SR 3.3.5.1.5    t 8.53 seconds (a)  (a)
LOCA Time Delay            4 ,5                                  SR 3.3.5.1.6    and Relay                                                                              d 10.64 seconds
: e. LPCI Pump B Start -        1, 2, 3,          1            C      SR 3.3.5.1.2    t 3.04 seconds LOCA/LOOP Time              4(a), 5(a)                            SR 3.3.5.1.3    and Delay Relay                                                      SR 3.3.5.1.6    d 6.00 seconds (a)  When associated subsystem(s) are required to be OPERABLE.
(b)  Also required to initiate the associated DG.
(e)  Also supports OPERABILITY of 230 kV offsite power circuit pursuant to LCO 3.8.1 and LCO 3.8.2.
Columbia Generating Station                            3.3.5.1-8        Amendment No. 169,172 225
 
ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 3 of 5)
Emergency Core Cooling System Instrumentation APPLICABLE                    CONDITIONS MODES OR      REQUIRED        REFERENCED OTHER        CHANNELS          FROM SPECIFIED        PER          REQUIRED    SURVEILLANCE    ALLOWABLE FUNCTION                  CONDITIONS      FUNCTION        ACTION A.1  REQUIREMENTS        VALUE
: 2. LPCI B and LPCI C Subsystems
: f. Reactor Vessel              1, 2, 3,    1 per valve          C      SR 3.3.5.1.2    t 448 psig Pressure - Low                                                        SR 3.3.5.1.4    and (Injection                                                            SR 3.3.5.1.6    d 492 psig Permissive)
(a)  (a) 4 ,5        1 per valve          B      SR 3.3.5.1.2    t 448 psig SR 3.3.5.1.4    and SR 3.3.5.1.6    d 492 psig
: g. LPCI Pumps B & C            1, 2, 3,    1 per pump            E      SR 3.3.5.1.2    t 605 gpm Discharge Flow -            (a) (a)                                  SR 3.3.5.1.4 4 ,5                                                      and Low (Minimum flow)                                                    SR 3.3.5.1.6    d 984 gpm
: h. Manual Initiation          1, 2, 3,          2              C      SR 3.3.5.1.6    NA (a) (a) 4 ,5
: 3. High Pressure Core Spray (HPCS) System (b)
: a. Reactor Vessel              1, 2, 3,        4                B      SR  3.3.5.1.1  t -58 inches Water Level - Low            (a) (a)                                  SR  3.3.5.1.2 4 ,5 Low, Level 2                                                          SR  3.3.5.1.4 SR  3.3.5.1.6 (b)
: b. Drywell Pressure -          1, 2, 3        4                B      SR 3.3.5.1.2    d 1.88 psig High                                                                  SR 3.3.5.1.4 SR 3.3.5.1.6
: c. Reactor Vessel              1, 2, 3,          2              C      SR  3.3.5.1.1  d 56.0 inches Water Level - High,          (a) (a)                                  SR  3.3.5.1.2 4 ,5 Level 8                                                              SR  3.3.5.1.4 SR  3.3.5.1.6
: d. Condensate Storage          1, 2, 3,          2              D      SR 3.3.5.1.2    t 448 ft 1 inch Tank Level - Low            (c) (c)                                  SR 3.3.5.1.4 4 ,5                                                      elevation SR 3.3.5.1.6 (a)    When associated subsystem(s) are required to be OPERABLE.
(b)    Also required to initiate the associated DG.
(c)    When HPCS is OPERABLE for compliance with LCO 3.5.2, "ECCS - Shutdown," and aligned to the condensate storage tank while tank water level is not within the limit of SR 3.5.2.2.
Columbia Generating Station                              3.3.5.1-9              Amendment No. 166,169 226
 
ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 4 of 5)
Emergency Core Cooling System Instrumentation APPLICABLE                  CONDITIONS MODES OR      REQUIRED  REFERENCED OTHER        CHANNELS      FROM SPECIFIED        PER      REQUIRED    SURVEILLANCE      ALLOWABLE FUNCTION              CONDITIONS      FUNCTION    ACTION A.1  REQUIREMENTS        VALUE
: 3. HPCS System
: e. Suppression Pool        1, 2, 3          2            D      SR 3.3.5.1.2    d 466 ft Water Level - High                                            SR 3.3.5.1.4    11 inches SR 3.3.5.1.6    elevation
: f. HPCS System Flow        1, 2, 3,          1            E      SR 3.3.5.1.2    t 1200 gpm and Rate - Low              4(a), 5(a)                            SR 3.3.5.1.4    d 1512 gpm (Minimum Flow)                                                SR 3.3.5.1.6
: g. Manual Initiation      1, 2, 3,          2            C      SR 3.3.5.1.6    NA (a)  (a) 4 ,5
: 4. Automatic Depressurization System (ADS) Trip System A
: a. Reactor Vessel        1, 2(d), 3(d)      2            F      SR  3.3.5.1.1  t -142.3 inches Water Level - Low                                            SR  3.3.5.1.2 Low Low, Level 1                                              SR  3.3.5.1.4 SR  3.3.5.1.6 (d)  (d)
: b. ADS Initiation Timer  1, 2 , 3          1            G      SR 3.3.5.1.2    d 115.0 seconds SR 3.3.5.1.3 SR 3.3.5.1.6
: c. Reactor Vessel        1, 2(d), 3(d)      1            F      SR  3.3.5.1.1  t 9.5 inches Water Level - Low,                                            SR  3.3.5.1.2 Level 3 (Permissive)                                          SR  3.3.5.1.4 SR  3.3.5.1.6 (d)  (d)
: d. LPCS Pump              1, 2 , 3          2            G      SR 3.3.5.1.2    t 119 psig and Discharge Pressure                                            SR 3.3.5.1.4    d 171 psig
            - High                                                        SR 3.3.5.1.6
: e. LPCI Pump A            1, 2(d), 3(d)      2            G      SR 3.3.5.1.2    t 116 psig and Discharge Pressure                                            SR 3.3.5.1.4    d 134 psig
            - High                                                        SR 3.3.5.1.6 (a)  When associated subsystem(s) are required to be OPERABLE.
(d)  With reactor steam dome pressure > 150 psig.
Columbia Generating Station                        3.3.5.1-10        Amendment No. 166,169 225
 
ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 5 of 5)
Emergency Core Cooling System Instrumentation APPLICABLE                CONDITIONS MODES OR      REQUIRED  REFERENCED OTHER        CHANNELS      FROM SPECIFIED        PER      REQUIRED      SURVEILLANCE    ALLOWABLE FUNCTION              CONDITIONS    FUNCTION    ACTION A.1  REQUIREMENTS        VALUE
: 4. ADS Trip System A (d)  (d)
: f. Accumulator Backup    1, 2 , 3          3          F        SR 3.3.5.1.2  t 151.4 psig Compressed Gas                                                SR 3.3.5.1.4 System Pressure -                                              SR 3.3.5.1.6 Low
: g. Manual Initiation      1, 2(d), 3(d)      4          G        SR 3.3.5.1.6  NA
: 5. ADS Trip System B
: a. Reactor Vessel        1, 2(d), 3(d)      2          F        SR 3.3.5.1.1  t -142.3 inches Water Level - Low                                              SR 3.3.5.1.2 Low Low, Level 1                                              SR 3.3.5.1.4 SR 3.3.5.1.6 (d)  (d)
: b. ADS Initiation Timer  1, 2 , 3          1          G        SR 3.3.5.1.2  d 115.0 seconds SR 3.3.5.1.3 SR 3.3.5.1.6
: c. Reactor Vessel        1, 2(d), 3(d)      1          F        SR 3.3.5.1.1  t 9.5 inches Water Level -                                                  SR 3.3.5.1.2 Low, Level 3                                                  SR 3.3.5.1.4 (Permissive)                                                  SR 3.3.5.1.6
: d. LPCI Pumps B & C      1, 2(d), 3(d) 2 per pump      G        SR 3.3.5.1.2  t 116 psig and Discharge Pressure                                            SR 3.3.5.1.4  d 134 psig
            - High                                                        SR 3.3.5.1.6
: e. Accumulator Backup    1, 2(d), 3(d)      3          F        SR 3.3.5.1.2  t 151.4 psig Compressed Gas                                                SR 3.3.5.1.4 System Pressure -                                              SR 3.3.5.1.6 Low (d)  (d)
: f. Manual Initiation      1, 2 , 3          4          G        SR 3.3.5.1.6  NA (d)  With reactor steam dome pressure > 150 psig.
Columbia Generating Station                        3.3.5.1-11            Amendment No. 166,169 225
 
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 4; and (b) for up to 6 hours for Functions 1 and 3 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              Perform CHANNEL CALIBRATION.                                            In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.4              Perform LOGIC SYSTEM FUNCTIONAL TEST.                                    In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.5.2-3              Amendment No. 149,169 225
 
Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME I. As required by Required              I.1        Declare associated standby              1 hour Action C.1 and                                  liquid control (SLC) referenced in                                  subsystem inoperable.
Table 3.3.6.1-1.
OR I.2        Isolate the Reactor Water                1 hour Cleanup (RWCU) System.
J. As required by Required                J.1        Initiate action to restore              Immediately Action C.1 and                                  channel to OPERABLE referenced in                                  status.
Table 3.3.6.1-1.
OR J.2        Initiate action to isolate the          Immediately Residual Heat Removal (RHR) Shutdown Cooling (SDC) System.
SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTES----------------------------------------------------------
: 1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Primary Containment 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 isolation capability.
SURVEILLANCE                                                      FREQUENCY SR 3.3.6.1.1              Perform CHANNEL CHECK.                                                  In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.6.1-3              Amendment No. 149,169 225
 
Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.3.6.1.2    Perform CHANNEL FUNCTIONAL TEST.                                      In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.3    Perform CHANNEL FUNCTIONAL TEST.                                      In accordance with the Surveillance Frequency Control 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 SR 3.3.6.1.7    -------------------------------NOTE------------------------------
Channel sensors for Functions 1.a, 1.b, and 1.c are excluded.
Verify the ISOLATION SYSTEM RESPONSE TIME                            In accordance is within limits.                                                    with the Surveillance Frequency Control Program Columbia Generating Station                    3.3.6.1-4              Amendment No. 214,219 225
 
Secondary Containment Isolation Instrumentation 3.3.6.2 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME C. (continued)                            C.2.1      Place the associated                    1 hour standby gas treatment (SGT) subsystem in operation.
OR C.2.2      Declare associated SGT                  1 hour subsystem inoperable.
SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTES----------------------------------------------------------
: 1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment 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 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 Columbia Generating Station                              3.3.6.2-2              Amendment No. 149,169 225
 
Secondary Containment Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                              FREQUENCY SR 3.3.6.2.3    Perform CHANNEL CALIBRATION.                    In accordance with the Surveillance Frequency Control Program SR 3.3.6.2.4    Perform LOGIC SYSTEM FUNCTIONAL TEST.            In accordance with the Surveillance Frequency Control Program Columbia Generating Station          3.3.6.2-3      Amendment No. 149,169 225
 
Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1)
Secondary Containment Isolation Instrumentation APPLICABLE      REQUIRED MODES OR      CHANNELS OTHER          PER SPECIFIED        TRIP    SURVEILLANCE        ALLOWABLE FUNCTION                      CONDITIONS      SYSTEM    REQUIREMENTS            VALUE (c)
: 1. Reactor Vessel Water Level - Low          1, 2, 3, (a)      2        SR 3.3.6.2.2        t -58 inches Low, Level 2                                                          SR 3.3.6.2.3 SR 3.3.6.2.4 (c)
: 2. Drywell Pressure - High                      1, 2, 3          2        SR 3.3.6.2.2        d 1.88 psig SR 3.3.6.2.3 SR 3.3.6.2.4
: 3. Reactor Building Vent Exhaust              1, 2, 3, (a)        2      SR  3.3.6.2.1      d 16.0 mR/hr Plenum Radiation - High                                                SR  3.3.6.2.2 SR  3.3.6.2.3 SR  3.3.6.2.4
: 4. Manual Initiation                          1, 2, 3, (a)        4      SR 3.3.6.2.4            NA (a)    During operations with a potential for draining the reactor vessel.
(b)    Deleted (c)    Also required to initiate the associated LOCA Time Delay Relay Function pursuant to LCO 3.3.5.1.
Columbia Generating Station                              3.3.6.2-4          Amendment No. 172,199 225
 
CREF System Instrumentation 3.3.7.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME D. Required Action and                    D.1        Place associated CREF                    1 hour associated Completion                          subsystem in the Time of Condition B or C                        pressurization mode of not met.                                        operation.
OR D.2        Declare associated CREF                  1 hour subsystem inoperable.
SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTES----------------------------------------------------------
: 1. Refer to Table 3.3.7.1-1 to determine which SRs apply for each CREF 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 CREF initiation capability.
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              Perform CHANNEL CALIBRATION.                                            In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.7.1-2              Amendment No. 187,199 225
 
CREF System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                      FREQUENCY SR 3.3.7.1.4    Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program Columbia Generating Station          3.3.7.1-3  Amendment No. 187,199 225
 
CREF System Instrumentation 3.3.7.1 Table 3.3.7.1-1 (page 1 of 1)
Control Room Emergency Filtration System Instrumentation APPLICABLE                      CONDITIONS MODES OR        REQUIRED      REFERENCED OTHER        CHANNELS          FROM SPECIFIED        PER TRIP      REQUIRED    SURVEILLANCE  ALLOWABLE FUNCTION                CONDITIONS        SYSTEM        ACTION A.1  REQUIREMENTS      VALUE
: 1. Reactor Vessel Water        1, 2, 3, (a)        2                B    SR  3.3.7.1.1 t -58 inches Level - Low Low, Level 2                                                SR  3.3.7.1.2 SR  3.3.7.1.3 SR  3.3.7.1.4
: 2. Drywell Pressure - High        1, 2, 3            2                C    SR  3.3.7.1.1 d 1.88 psig SR  3.3.7.1.2 SR  3.3.7.1.3 SR  3.3.7.1.4
: 3. Reactor Building Vent        1, 2, 3, (a)        2                B    SR  3.3.7.1.1 d 16.0 mR/hr Exhaust Plenum                                                          SR  3.3.7.1.2 Radiation - High                                                        SR  3.3.7.1.3 SR  3.3.7.1.4 (a)  During operations with a potential for draining the reactor vessel.
Columbia Generating Station                            3.3.7.1-4          Amendment No. 169,199 225
 
LOP Instrumentation 3.3.8.1 ACTIONS CONDITION                                REQUIRED ACTION                            COMPLETION TIME D. Required Action and                    D.1        Declare associated DG                    Immediately associated Completion                          inoperable.
Time of Condition B or C not met.                            OR
                                            --------------------NOTE-------------------
Only applicable for Functions 1.c and 1.d.
D.2.1      Open offsite circuit supply              Immediately breaker to associated 4.16 kV ESF bus.
AND D.2.2      Declare associated offsite              Immediately circuit inoperable.
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 initiation capability.
SURVEILLANCE                                                      FREQUENCY SR 3.3.8.1.1              Perform CHANNEL FUNCTIONAL TEST.                                        In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.8.1-2              Amendment No. 149,169 225
 
LOP Instrumentation 3.3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                      FREQUENCY SR 3.3.8.1.2    Perform CHANNEL CALIBRATION.              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 Columbia Generating Station          3.3.8.1-3  Amendment No. 149,169 225
 
LOP Instrumentation 3.3.8.1 Table 3.3.8.1-1 (page 1 of 1)
Loss of Power Instrumentation CONDITIONS REQUIRED      REFERENCED CHANNELS          FROM PER          REQUIRED      SURVEILLANCE            ALLOWABLE FUNCTION                  DIVISION      ACTION A.1  REQUIREMENTS                VALUE
: 1. Divisions 1 and 2 - 4.16 kV Emergency Bus Undervoltage
: a. TR-S Loss of Voltage -          2              B          SR 3.3.8.1.2    t 2450 V and d 3135 V 4.16 kV Basis                                              SR 3.3.8.1.4
: b. TR-S Loss of Voltage -          2              B          SR 3.3.8.1.3    t 2.95 seconds and Time Delay                                                SR 3.3.8.1.4    d 7.1 seconds
: c. TR-B Loss of Voltage -          1              C          SR 3.3.8.1.3    t 2450 V and d 3135 V 4.16 kV Basis                                              SR 3.3.8.1.4
: d. TR-B Loss of Voltage -          1              C          SR 3.3.8.1.3    t 3.06 seconds and Time Delay                                                SR 3.3.8.1.4    d 9.28 seconds (a)
: e. Degraded Voltage -              2              C          SR 3.3.8.1.1  t 3685 V and d 3755 V 4.16 kV Basis                                              SR 3.3.8.1.2 SR 3.3.8.1.4
: f. Degraded Voltage -              2(a)            C          SR 3.3.8.1.1  t 5.0 seconds and Primary Time Delay                                        SR 3.3.8.1.2  d 5.3 seconds SR 3.3.8.1.4
: g. Degraded Voltage -              1              C          SR 3.3.8.1.2  t 2.63 seconds and Secondary Time Delay                                      SR 3.3.8.1.4  d 3.39 seconds
: 2. Division 3 - 4.16 kV Emergency Bus Undervoltage
: a. Los of Voltage -                2              B          SR 3.3.8.1.2    t 2450 V and d 3135 V 4.16 kV Basis                                              SR 3.3.8.1.4
: b. Loss of voltage -                2              B          SR 3.3.8.1.3    t 1.87 seconds and Time Delay                                                SR 3.3.8.1.4    d 3.73 seconds
: c. Degraded Voltage -              2              C          SR 3.3.8.1.2    t 3685 V and d 3755 V 4.16 kV Basis                                              SR 3.3.8.1.4
: d. Degraded Voltage -              2              C          SR 3.3.8.1.2    t 7.36 seconds and Time Delay                                                SR 3.3.8.1.4    d 8.34 seconds (a)      The Degraded Voltage - 4.16 kV Basis and - Primary Time Delay Functions must be associated with one another.
Columbia Generating Station                        3.3.8.1-4          Amendment No.149,169 225
 
RPS Electric Power Monitoring 3.3.8.2 ACTIONS CONDITION              REQUIRED ACTION                    COMPLETION TIME D. Required Action and      D.1 Initiate action to restore one    Immediately associated Completion        electric power monitoring Time of Condition A or B    assembly to OPERABLE not met in MODE 4 or 5      status for inservice power with both RHR SDC            supply(s) supplying suction isolation valves    required instrumentation.
open.
OR D.2 Initiate action to isolate the    Immediately RHR SDC System.
E. Required Action and      E.1 Initiate action to fully insert  Immediately associated Completion        all insertable control rods in Time of Condition A or B    core cells containing one or not met in MODE 5 with      more fuel assemblies.
any control rod withdrawn from a core cell containing one or more fuel assemblies.
Columbia Generating Station        3.3.8.2-2          Amendment No. 149,169 225
 
RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTE------------------------------------------------------------
When an RPS electric power monitoring assembly is placed in an inoperable status solely for performance of required Surveillances, entry into the associated Conditions and Required Actions may be delayed for up to 6 hours provided the other RPS electric power monitoring assembly for the associated power supply maintains trip capability.
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 t 24 hours.
Perform CHANNEL FUNCTIONAL TEST.                                        In accordance with the Surveillance Frequency Control Program SR 3.3.8.2.2              Perform CHANNEL CALIBRATION. The Allowable                              In accordance Values shall be:                                                        with the Surveillance
: a. Overvoltage d 133.8 V, with time delay                            Frequency
                                   3.46 seconds;                                                    Control Program
: b. Undervoltage t 110.8 V, with time delay
                                   3.46 seconds; and
: c. Underfrequency t 57 Hz, with time delay
                                   3.46 seconds.
SR 3.3.8.2.3              Perform a system functional test.                                        In accordance with the Surveillance Frequency Control Program Columbia Generating Station                              3.3.8.2-3              Amendment No. 169,179 225
 
Recirculation Loops Operating (Prior to Implementation of PRNM Upgrade) 3.4.1 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 drive flow mismatch with                    In accordance both recirculation loops in operation is:                            with the Surveillance
: a. d 10% of rated recirculation loop drive flow                    Frequency when operating at < 70% of rated core flow; and                Control Program
: b. d 5% of rated recirculation loop drive flow when operating at t 70% of rated core flow.
Columbia Generating Station                      3.4.1-2              Amendment No. 205 225 226
 
Recirculation Loops Operating (After Implementation of PRNM Upgrade) 3.4.1 ACTIONS 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 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 drive flow mismatch with                      In accordance both recirculation loops in operation is:                              with the Surveillance
: a. d 10% of rated recirculation loop drive flow                      Frequency when operating at < 70% of rated core flow; and                  Control Program
: b. d 5% of rated recirculation loop drive flow when operating at t 70% of rated core flow.
Columbia Generating Station                        3.4.1-4              Amendment No. 205 225 226
 
Jet Pumps 3.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.4.2.1      ------------------------------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 > 25% RTP.
Verify at least two of the following criteria (a, b,                  In accordance and c) are satisfied for each operating recirculation                with the loop:                                                                Surveillance Frequency
: a. Recirculation loop drive flow versus                            Control Program recirculation pump speed differs by d 10% from established patterns.
: b. Recirculation loop drive flow versus total core flow differs by d 10% from established patterns.
: c. Each jet pump diffuser to lower plenum differential pressure differs by d 20% from established patterns, or each jet pump flow differs by d 10% from established patterns.
Columbia Generating Station                      3.4.2-2              Amendment No. 149,169 225
 
SRVs -  25% RTP 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3      Safety/Relief Valves (SRVs) -  25% RTP LCO 3.4.3            The safety function of 12 SRVs shall be OPERABLE, with two SRVs in the lowest two lift setpoint groups OPERABLE.
APPLICABILITY:      THERMAL POWER t 25% RTP.
ACTIONS CONDITION                        REQUIRED ACTION                  COMPLETION TIME A. One or more required        A.1      Reduce THERMAL                  4 hours SRVs inoperable.                    POWER to < 25% RTP.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                        FREQUENCY SR 3.4.3.1        Verify the safety function lift setpoints of the required  In accordance SRVs are as follows:                                      with the Inservice Testing Program Number of                  Setpoint SRVs                      (psig) 2                  1165 +/- 34.9 4                  1175 +/- 35.2 4                  1185 +/- 35.5 4                  1195 +/- 35.8 4                  1205 +/- 36.1 SR 3.4.3.2        Verify each required SRV opens when manually              In accordance actuated.                                                  with the Surveillance Frequency Control Program Columbia Generating Station                  3.4.3-1          Amendment No. 149,169 225
 
SRVs - < 25% RTP 3.4.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.4.4.2      -------------------------------NOTE------------------------------
Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test.
Verify each required SRV opens when manually                          In accordance actuated.                                                            with the Surveillance Frequency Control Program Columbia Generating Station                      3.4.4-2              Amendment No. 149,169 225
 
RCS Operational LEAKAGE 3.4.5 ACTIONS 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 OR Pressure boundary LEAKAGE exists.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR 3.4.5.1        Verify RCS unidentified and total LEAKAGE and      In accordance unidentified LEAKAGE increase are within limits. with the Surveillance Frequency Control Program Columbia Generating Station                3.4.5-2        Amendment No. 149,169 225
 
RCS Leakage Detection Instrumentation 3.4.7 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 other required leakage detection instrumentation is OPERABLE.
SURVEILLANCE                                                      FREQUENCY SR 3.4.7.1                Perform CHANNEL CHECK of required drywell                                In accordance atmospheric monitoring system.                                          with the Surveillance Frequency Control Program SR 3.4.7.2                Perform CHANNEL FUNCTIONAL TEST of required                              In accordance leakage detection instrumentation.                                      with the Surveillance Frequency Control Program SR 3.4.7.3                Perform CHANNEL CALIBRATION of required                                  In accordance leakage detection instrumentation.                                      with the Surveillance Frequency Control Program Columbia Generating Station                                3.4.7-3              Amendment No. 149,169 225
 
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 I-131                          In accordance specific activity is d 0.2 PCi/gm.                                    with the Surveillance Frequency Control Program Columbia Generating Station                      3.4.8-2              Amendment No. 149,169 225
 
RHR Shutdown Cooling System - Hot Shutdown 3.4.9 ACTIONS CONDITION                              REQUIRED ACTION                            COMPLETION TIME B. No RHR shutdown                  B.1        Initiate action to restore one          Immediately cooling subsystem in                        RHR shutdown cooling operation.                                  subsystem or one recirculation pump to AND                                        operation.
No recirculation pump in        AND operation.
B.2        Verify reactor coolant                  1 hour from discovery circulation by an alternate              of no reactor coolant method.                                  circulation AND Once per 12 hours thereafter AND B.3        Monitor reactor coolant                  Once per hour temperature and pressure.
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 than 48 psig.
Verify one RHR shutdown cooling subsystem or                            In accordance recirculation pump is operating.                                        with the Surveillance Frequency Control Program Columbia Generating Station                        3.4.9-2              Amendment No. 164,169 225
 
RHR Shutdown Cooling System - Cold Shutdown 3.4.10 ACTIONS CONDITION                      REQUIRED ACTION                COMPLETION TIME B. No RHR shutdown              B.1    Verify reactor coolant      1 hour from discovery cooling subsystem in                circulating by an alternate  of no reactor coolant operation.                          method.                      circulation AND                                                              AND No recirculation pump in                                          Once per 12 hours operation.                                                        thereafter AND 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 recirculation pump is operating.                      with the Surveillance Frequency Control Program Columbia Generating Station                3.4.10-2          Amendment No. 149,169 225
 
RCS P/T Limits 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.4.11.1      -------------------------------NOTE------------------------------
Only required to be performed during RCS heatup and cooldown operations, and RCS inservice leak and hydrostatic testing.
Verify:                                                              In accordance with the
: a. RCS pressure and RCS temperature are within                    Surveillance the applicable limits specified in                              Frequency Figures 3.4.11-1, 3.4.11-2, and 3.4.11-3;                      Control Program
: b. RCS heatup and cooldown rates are  100&deg;F in any 1 hour period; and
: c. RCS temperature change during inservice leak and hydrostatic testing is  20&deg;F in any 1 hour period when the RCS pressure and RCS temperature are not within the limits of Figure 3.4.11-2.
SR 3.4.11.2      Verify RCS pressure and RCS temperature are                          Once within within the criticality limits specified in                            15 minutes prior Figure 3.4.11-3.                                                      to control rod withdrawal for the purpose of achieving criticality SR 3.4.11.3      -------------------------------NOTE------------------------------
Only required to be met in MODES 1, 2, 3, and 4 during recirculation pump startup.
Verify the difference between the bottom head                        Once within coolant temperature and the reactor pressure vessel                  15 minutes prior (RPV) coolant temperature is d 145&deg;F.                                to each startup of a recirculation pump Columbia Generating Station                      3.4.11-2              Amendment No. 149,169 225
 
RCS P/T Limits 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.4.11.7      -------------------------------NOTE------------------------------
Only required to be performed when tensioning the reactor vessel head bolting studs.
Verify reactor vessel flange and head flange                          In accordance temperatures are t 80&deg;F.                                              with the Surveillance Frequency Control Program SR 3.4.11.8      -------------------------------NOTE------------------------------
Not required to be performed until 30 minutes after RCS temperature d 90qF in MODE 4.
Verify reactor vessel flange and head flange                          In accordance temperatures are t 80&deg;F.                                              with the Surveillance Frequency Control Program SR 3.4.11.9      -------------------------------NOTE------------------------------
Not required to be performed until 12 hours after RCS temperature d 100qF in MODE 4.
Verify reactor vessel flange and head flange                          In accordance temperatures are t 80&deg;F.                                              with the Surveillance Frequency Control Program Columbia Generating Station                      3.4.11-4              Amendment No. 149,169 225
 
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 d 1035 psig.
APPLICABILITY:        MODES 1 and 2.
ACTIONS CONDITION                      REQUIRED ACTION                COMPLETION TIME A. Reactor steam dome          A.1    Restore reactor steam        15 minutes pressure not within limit.          dome pressure to within limit.
B. Required Action and          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 d 1035 psig. In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.4.12-1        Amendment No. 149,169 225
 
ECCS - Operating 3.5.1 ACTIONS CONDITION                        REQUIRED ACTION              COMPLETION TIME H. HPCS and Low                  H.1      Enter LCO 3.0.3.          Immediately Pressure Core Spray (LPCS) Systems inoperable.
OR Three or more ECCS injection/spray subsystems inoperable.
OR HPCS System and one or more required ADS valves inoperable.
OR Two or more ECCS injection/spray subsystems and one or more required ADS valves inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.5.1.1        Verify, for each ECCS injection/spray subsystem,      In accordance the piping is filled with water from the pump          with the discharge valve to the injection valve.                Surveillance Frequency Control Program Columbia Generating Station                    3.5.1-3        Amendment No. 149,169 225
 
ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.5.1.2      ------------------------------NOTE-------------------------------
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 48 psig in MODE 3, if capable of being manually realigned and not otherwise inoperable.
Verify each ECCS injection/spray subsystem                            In accordance manual, power operated, and automatic valve in the                    with the flow path, that is not locked, sealed, or otherwise                  Surveillance secured in position, is in the correct position.                      Frequency Control Program SR 3.5.1.3      Verify ADS accumulator backup compressed gas                          In accordance system average pressure in the required bottles is                    with the t 2200 psig.                                                          Surveillance Frequency Control Program SR 3.5.1.4      Verify each ECCS pump develops the specified flow                    In accordance rate with the specified differential pressure between                with the Inservice reactor and suction source.                                          Testing Program DIFFERENTIAL PRESSURE BETWEEN REACTOR AND SYSTEM        FLOW RATE                  SUCTION SOURCE LPCS          t 6350 gpm                    t 128 psid LPCI          t 7450 gpm                    t 26 psig HPCS          t 6350 gpm                    t 200 psig Columbia Generating Station                      3.5.1-4              Amendment No. 169,205 225
 
ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.5.1.5      -------------------------------NOTE------------------------------
Vessel injection/spray may be excluded.
Verify each ECCS injection/spray subsystem                            In accordance actuates on an actual or simulated automatic                          with the initiation signal.                                                    Surveillance Frequency Control Program SR 3.5.1.6      -------------------------------NOTE------------------------------
Valve actuation may be excluded.
Verify the ADS actuates on an actual or simulated                    In accordance automatic initiation signal.                                          with the Surveillance Frequency Control Program SR 3.5.1.7      -------------------------------NOTE------------------------------
Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test.
Verify each required ADS valve opens when                            In accordance manually actuated.                                                    with the Surveillance Frequency Control Program SR 3.5.1.8      -------------------------------NOTE------------------------------
ECCS actuation instrumentation is excluded.
Verify the ECCS RESPONSE TIME for each ECCS                          In accordance injection/spray subsystem is within limits.                          with the Surveillance Frequency Control Program Columbia Generating Station                      3.5.1-5              Amendment No. 150,169 225
 
ECCS - Shutdown 3.5.2 ACTIONS CONDITION                        REQUIRED ACTION                COMPLETION TIME D. Required Action C.2 and    D.1      Initiate action to restore    Immediately associated Completion                secondary containment to Time not met.                        OPERABLE status.
AND D.2      Initiate action to restore one Immediately standby gas treatment subsystem to OPERABLE status.
AND D.3      Initiate action to restore    Immediately isolation capability in each required secondary containment penetration flow path not isolated.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.5.2.1      Verify, for each required low pressure ECCS              In accordance injection/spray subsystem, the suppression pool          with the water level is t 18 ft 6 inches.                        Surveillance Frequency Control Program SR 3.5.2.2      Verify, for the required High Pressure Core Spray        In accordance (HPCS) System, the:                                      with the Surveillance
: a. Suppression pool water level is t 18 ft 6 inches;  Frequency or                                                  Control Program
: b. Condensate storage tank (CST) water level is t 16.5 ft in a single CST or t 10.5 ft in each CST.
Columbia Generating Station                  3.5.2-2          Amendment No. 169,210 225
 
ECCS - Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.5.2.3      Verify, for each required ECCS injection/spray                        In accordance subsystem, the piping is filled with water from the                  with the pump discharge valve to the injection valve.                          Surveillance Frequency Control Program SR 3.5.2.4      ------------------------------NOTE-------------------------------
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.
Verify each required ECCS injection/spray                            In accordance subsystem manual, power operated, and automatic                      with the valve in the flow path, that is not locked, sealed, or                Surveillance otherwise secured in position, is in the correct                      Frequency position.                                                            Control Program SR 3.5.2.5      Verify each required ECCS pump develops the                          In accordance specified flow rate with the specified differential                  with the Inservice pressure between reactor and suction source.                          Testing Program DIFFERENTIAL PRESSURE BETWEEN REACTOR AND SYSTEM        FLOW RATE                  SUCTION SOURCE LPCS          t 6350 gpm                    t 128 psid LPCI          t 7450 gpm                    t 26 psig HPCS          t 6350 gpm                    t 200 psig Columbia Generating Station                      3.5.2-3              Amendment No. 169,205 225
 
ECCS - Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.5.2.6      -------------------------------NOTE------------------------------
Vessel injection/spray may be excluded.
Verify each required ECCS injection/spray                            In accordance subsystem actuates on an actual or simulated                          with the automatic initiation signal.                                          Surveillance Frequency Control Program Columbia Generating Station                      3.5.2-4              Amendment No. 169,205 225
 
RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.5.3.1      Verify the RCIC System piping is filled with water                    In accordance from the pump discharge valve to the injection                        with the valve.                                                                Surveillance Frequency Control Program SR 3.5.3.2      Verify each RCIC System manual, power operated,                      In accordance and automatic valve in the flow path, that is not                    with the locked, sealed, or otherwise secured in position, is                  Surveillance in the correct position.                                              Frequency Control 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 reactor pressure d 1035 psig and                        In accordance t 935 psig, the RCIC pump can develop a flow rate                    with the t 600 gpm against a system head corresponding to                      Surveillance reactor pressure.                                                    Frequency Control 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 reactor pressure d 165 psig, the RCIC                    In accordance pump can develop a flow rate t 600 gpm against a                      with the system head corresponding to reactor pressure.                        Surveillance Frequency Control Program Columbia Generating Station                      3.5.3-2              Amendment No. 150,169 225
 
RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.5.3.5      -------------------------------NOTE------------------------------
Vessel injection may be excluded.
Verify the RCIC System actuates on an actual or                      In accordance simulated automatic initiation signal.                                with the Surveillance Frequency Control Program Columbia Generating Station                      3.5.3-3              Amendment No. 150,169 225
 
Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.6.1.1.2    Verify drywell to suppression chamber bypass                          In accordance leakage is  10% of the acceptable A / K design                        with the value of 0.050 ft2 at an initial differential pressure of              Surveillance t 1.5 psid.                                                            Frequency Control Program AND 48 months following a test with bypass leakage greater than the bypass leakage limit AND 24 months following two consecutive tests with bypass leakage greater than the bypass leakage limit until two consecutive tests are less than or equal to the bypass leakage limit SR 3.6.1.1.3    -------------------------------NOTE------------------------------
Performance of SR 3.6.1.1.2 satisfies this surveillance.
Verify individual drywell to suppression chamber                      In accordance vacuum relief valve bypass pathway leakage is                          with the
                   1.2% of the acceptable A / K design value of                        Surveillance 0.050 ft2 at an initial differential pressure of                      Frequency
                   1.5 psid.                                                            Control Program Columbia Generating Station                    3.6.1.1-2              Amendment No. 169,201 225
 
Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.6.1.1.4    -------------------------------NOTE------------------------------
Performance of SR 3.6.1.1.2 satisfies this surveillance.
Verify total drywell to suppression chamber vacuum                    In accordance relief valve bypass leakage is  3.0% of the                          with the acceptable A / K design value of 0.050 ft2 at an                      Surveillance initial differential pressure of  1.5 psid.                          Frequency Control Program Columbia Generating Station                    3.6.1.1-3                    Amendment No. 201 225
 
Primary Containment Air Lock 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                        In accordance leakage rate testing in accordance with the Primary                  with the Primary Containment Leakage Rate Testing Program.                            Containment Leakage Rate Testing Program SR 3.6.1.2.2    Verify only one door in the primary containment air                  In accordance lock can be opened at a time.                                        with the Surveillance Frequency Control Program Columbia Generating Station                    3.6.1.2-4                Amendment No. 149,169 225
 
PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.6.1.3.1    -------------------------------NOTE------------------------------
Not required to be met when the 24 inch and 30 inch primary containment purge valves are open for inerting, de-inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open.
Verify each 24 inch and 30 inch primary                              In accordance containment purge valve is closed.                                    with the Surveillance Frequency Control Program SR 3.6.1.3.2    ------------------------------NOTES-----------------------------
: 1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.
: 2. Not required to be met for PCIVs that are open under administrative controls.
Verify each primary containment isolation manual                      In accordance valve and blind flange that is located outside primary                with the containment and not locked, sealed, or otherwise                      Surveillance secured and is required to be closed during accident                  Frequency conditions is closed.                                                Control Program Columbia Generating Station                    3.6.1.3-6              Amendment No. 169,208 225
 
PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.6.1.3.3    ------------------------------NOTES-----------------------------
: 1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.
: 2. Not required to be met for PCIVs that are open under administrative controls.
Verify each primary containment isolation manual                      Prior to entering valve and blind flange that is located inside primary                MODE 2 or 3 from containment and not locked, sealed, or otherwise                      MODE 4 if secured and is required to be closed during accident                  primary conditions is closed.                                                containment was de-inerted while in MODE 4, if not performed within the previous 92 days SR 3.6.1.3.4    Verify continuity of the traversing incore probe (TIP)                In accordance shear isolation valve explosive charge.                              with the Surveillance Frequency Control Program SR 3.6.1.3.5    Verify the isolation time of each power operated,                    In accordance automatic PCIV, except for MSIVs, is within limits.                  with the Inservice Testing Program SR 3.6.1.3.6    Verify the isolation time of each MSIV is                            In accordance t 3 seconds and d 5 seconds.                                          with the Inservice Testing Program SR 3.6.1.3.7    Verify each automatic PCIV actuates to the isolation                  In accordance position on an actual or simulated isolation signal.                  with the Surveillance Frequency Control Program Columbia Generating Station                    3.6.1.3-7              Amendment No. 199,208 225
 
PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR 3.6.1.3.8    Verify a representative sample of reactor instrument In accordance line EFCVs actuate to the isolation position on an  with the actual or simulated instrument line break signal. Surveillance Frequency Control Program SR 3.6.1.3.9    Remove and test the explosive squib from each        In accordance shear isolation valve of the TIP System.            with the Surveillance Frequency Control Program SR 3.6.1.3.10    Verify the combined leakage rate for all secondary  In accordance containment bypass leakage paths is d 0.04%          with the Primary primary containment volume/day when pressurized      Containment to t Pa.                                            Leakage Rate Testing Program SR 3.6.1.3.11    Verify leakage rate through each MSIV is            In accordance d 16.0 scfh when tested at t 25.0 psig.              with the Primary Containment Leakage Rate Testing Program SR 3.6.1.3.12    Verify combined leakage rate through hydrostatically In accordance tested lines that penetrate the primary containment  with the Primary is within limits.                                    Containment Leakage Rate Testing Program Columbia Generating Station              3.6.1.3-8        Amendment No. 199,208 225
 
Drywell Air Temperature 3.6.1.4 3.6 CONTAINMENT SYSTEMS 3.6.1.4    Drywell Air Temperature LCO 3.6.1.4            Drywell average air temperature shall be d 135&deg;F.
APPLICABILITY:        MODES 1, 2, and 3.
ACTIONS CONDITION                      REQUIRED ACTION                    COMPLETION TIME A. Drywell average air          A.1    Restore drywell average air      8 hours temperature not within              temperature to within limit.
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 3.6.1.4.1        Verify drywell average air temperature is within limit. In accordance with the Surveillance Frequency Control Program Columbia Generating Station                  3.6.1.4-1        Amendment No. 149,169 225
 
RHR Drywell Spray 3.6.1.5 3.6 CONTAINMENT SYSTEMS 3.6.1.5    Residual Heat Removal (RHR) Drywell Spray LCO 3.6.1.5          Two RHR drywell spray subsystems shall be OPERABLE.
APPLICABILITY:        MODES 1, 2, and 3.
ACTIONS CONDITION                        REQUIRED ACTION                COMPLETION TIME A. One RHR drywell spray          A.1      Restore RHR drywell spray    7 days subsystem inoperable.                  subsystem to OPERABLE status.
B. Two RHR drywell spray          B.1      Restore one RHR drywell      8 hours subsystems inoperable.                spray subsystem to OPERABLE status.
C. Required Action and            C.1      Be in MODE 3.                12 hours associated Completion Time not met.                AND C.2      Be in MODE 4.                36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.6.1.5.1      Verify each RHR drywell spray subsystem manual,        In accordance power operated, and automatic valve in the flow        with the path that is not locked, sealed, or otherwise secured  Surveillance in position, is in the correct position or can be      Frequency aligned to the correct position.                        Control Program Columbia Generating Station                  3.6.1.5-1        Amendment No. 149,169 225
 
RHR Drywell Spray 3.6.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                FREQUENCY SR 3.6.1.5.2    Verify each spray nozzle is unobstructed.          In accordance with the Surveillance Frequency Control Program Columbia Generating Station            3.6.1.5-2        Amendment No. 149,169 225
 
Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 ACTIONS CONDITION                            REQUIRED ACTION                            COMPLETION TIME E. Required Action and            E.1      Be in MODE 3.                            12 hours associated Completion Time not met.                  AND E.2        Be in MODE 4.                            36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.6.1.6.1    ------------------------------NOTES-----------------------------
: 1. Not required to be met for vacuum breakers that are open during Surveillances.
: 2. Not required to be met for vacuum breakers open when performing their intended function.
Verify each vacuum breaker is closed.                                  In accordance with the Surveillance Frequency Control Program SR 3.6.1.6.2    Perform a functional test of each vacuum breaker.                      In accordance with the Inservice Testing Program SR 3.6.1.6.3    Verify the full open setpoint of each vacuum breaker                    In accordance is  0.5 psid.                                                          with the Surveillance Frequency Control Program Columbia Generating Station                    3.6.1.6-2              Amendment No. 149,169 225
 
Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7 ACTIONS CONDITION                            REQUIRED ACTION                            COMPLETION TIME D. Required Action and            D.1      Be in MODE 3.                            12 hours associated Completion Time not met.                  AND D.2        Be in MODE 4.                            36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.6.1.7.1    -------------------------------NOTE------------------------------
Not required to be met for vacuum breakers that are open during Surveillances.
Verify each vacuum breaker is closed.                                  In accordance with the Surveillance Frequency Control Program SR 3.6.1.7.2    Perform a functional test of each required vacuum                      In accordance breaker.                                                                with the Surveillance Frequency Control Program AND Within 12 hours after any discharge of steam to the suppression chamber from the safety/relief valves Columbia Generating Station                    3.6.1.7-2              Amendment No. 169,202 225
 
Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR 3.6.1.7.3    Verify the full open setpoint of each required        In accordance vacuum breaker is d 0.5 psid.                        with the Surveillance Frequency Control Program Columbia Generating Station              3.6.1.7-3        Amendment No. 169,202 225
 
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 within the applicable limits.                      with the Surveillance Frequency Control Program AND 5 minutes when performing testing that adds heat to the suppression pool Columbia Generating Station              3.6.2.1-3      Amendment No. 149,169 225
 
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 t 30 ft 9.75 inches and d 31 ft 1.75 inches.
APPLICABILITY:          MODES 1, 2, and 3.
ACTIONS CONDITION                        REQUIRED ACTION                    COMPLETION TIME A. Suppression pool water          A.1      Restore suppression pool        2 hours level not within limits.                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 Columbia Generating Station                    3.6.2.2-1          Amendment No. 149,169 225
 
RHR Suppression Pool Cooling 3.6.2.3 3.6 CONTAINMENT SYSTEMS 3.6.2.3    Residual Heat Removal (RHR) Suppression Pool Cooling LCO 3.6.2.3          Two RHR suppression pool cooling subsystems shall be OPERABLE.
APPLICABILITY:      MODES 1, 2, and 3.
ACTIONS CONDITION                      REQUIRED ACTION                  COMPLETION TIME A. One RHR suppression          A.1    Restore RHR suppression        7 days pool cooling subsystem              pool cooling subsystem to inoperable.                          OPERABLE status.
B. Required Action and          B.1    Be in MODE 3.                  12 hours associated Completion Time of Condition A not      AND met.
B.2    Be in MODE 4.                  36 hours OR Two RHR suppression pool cooling subsystems inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.6.2.3.1      Verify each RHR suppression pool cooling                In accordance subsystem manual, power operated, and automatic          with the valve in the flow path that is not locked, sealed, or    Surveillance otherwise secured in position, is in the correct        Frequency position or can be aligned to the correct position.      Control Program Columbia Generating Station                3.6.2.3-1          Amendment No. 149,169 225
 
Primary Containment Atmosphere Mixing System 3.6.3.2 3.6 CONTAINMENT SYSTEMS 3.6.3.2    Primary Containment Atmosphere Mixing System LCO 3.6.3.2          Two head area return fans shall be OPERABLE.
APPLICABILITY:        MODES 1 and 2.
ACTIONS CONDITION                    REQUIRED ACTION              COMPLETION TIME A. One head area return        A.1    Restore head area return    30 days fan inoperable.                    fan to OPERABLE status.
B. Two head area return        B.1    Verify by administrative    1 hour fans inoperable.                  means that the hydrogen and oxygen control function is maintained.
AND B.2    Restore one head area        7 days return fan to OPERABLE status.
C. Required Action and        C.1    Be in MODE 3.                12 hours associated Completion Time not met.
Columbia Generating Station                3.6.3.2-1        Amendment No. 169,187 225
 
Primary Containment Atmosphere Mixing System 3.6.3.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                FREQUENCY SR 3.6.3.2.1    Operate each head area return fan for t 15 minutes. In accordance with the Surveillance Frequency Control Program Columbia Generating Station            3.6.3.2-2        Amendment No. 169,187 225
 
Primary Containment Oxygen Concentration 3.6.3.3 3.6 CONTAINMENT SYSTEMS 3.6.3.3    Primary Containment Oxygen Concentration LCO 3.6.3.3            The primary containment oxygen concentration shall be < 3.5 volume percent.
APPLICABILITY:          MODE 1 during the time period:
: a. From 24 hours after THERMAL POWER is > 15% RTP following startup, to
: b. 24 hours prior to reducing THERMAL POWER to < 15% RTP prior to the next scheduled reactor shutdown.
ACTIONS CONDITION                          REQUIRED ACTION                COMPLETION TIME A. Primary containment              A.1    Restore oxygen                24 hours oxygen concentration                    concentration to within limit.
not within limit.
B. Required Action and              B.1    Reduce THERMAL                8 hours associated Completion                  POWER to d 15% RTP.
Time not met.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.6.3.3.1          Verify primary containment oxygen concentration is      In accordance within limits.                                          with the Surveillance Frequency Control Program Columbia Generating Station                    3.6.3.3-1        Amendment No. 149,169 225
 
Secondary Containment 3.6.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR 3.6.4.1.1    Verify secondary containment vacuum is t 0.25 inch  In accordance of vacuum water gauge.                              with the Surveillance Frequency Control Program SR 3.6.4.1.2    Verify all secondary containment equipment hatches  In accordance are closed and sealed.                              with the Surveillance Frequency Control Program SR 3.6.4.1.3    Verify each secondary containment access inner      In accordance door or each secondary containment access outer      with the door in each access opening is closed.              Surveillance Frequency Control Program SR 3.6.4.1.4    Verify each standby gas treatment (SGT) subsystem    In accordance will draw down the secondary containment to          with the t 0.25 inch of vacuum water gauge in                Surveillance d 120 seconds.                                      Frequency Control Program SR 3.6.4.1.5    Verify each SGT subsystem can maintain              In accordance t 0.25 inch of vacuum water gauge in the secondary  with the containment for 1 hour at a flow rate d 2240 cfm. Surveillance Frequency Control Program Columbia Generating Station              3.6.4.1-2        Amendment No. 169,199 225
 
SCIVs 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.6.4.2.1    ------------------------------NOTES-----------------------------
: 1. Valves and blind flanges in high radiation areas may be verified by use of administrative controls.
: 2. Not required to be met for SCIVs that are open under administrative controls.
Verify each secondary containment isolation manual                    In accordance valve and blind flange that is not locked, sealed, or                with the otherwise secured, and is required to be closed                      Surveillance during accident conditions is closed.                                Frequency Control Program SR 3.6.4.2.2    Verify the isolation time of each power operated,                    In accordance automatic SCIV is within limits.                                      with the Inservice Testing Program SR 3.6.4.2.3    Verify each automatic SCIV actuates to the isolation                  In accordance position on an actual or simulated automatic                          with the isolation signal.                                                    Surveillance Frequency Control Program Columbia Generating Station                    3.6.4.2-3                    Amendment No. 208 225
 
SGT System 3.6.4.3 ACTIONS CONDITION                        REQUIRED ACTION                  COMPLETION TIME E. Two SGT subsystems        E.1        Initiate action to suspend    Immediately inoperable during                    OPDRVs.
OPDRVs.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.6.4.3.1      Operate each SGT subsystem for t 10 continuous          In accordance hours with heaters operating.                            with the Surveillance Frequency Control Program SR 3.6.4.3.2      Perform required SGT filter testing in accordance        In accordance with the Ventilation Filter Testing Program (VFTP).      with the VFTP SR 3.6.4.3.3      Verify each SGT subsystem actuates on an actual          In accordance or simulated initiation signal.                          with the Surveillance Frequency Control Program SR 3.6.4.3.4      Verify each SGT filter cooling recirculation valve can  In accordance be opened and the fan started.                          with the Surveillance Frequency Control Program Columbia Generating Station                  3.6.4.3-2        Amendment No. 169,199 225
 
SW System and UHS 3.7.1 ACTIONS 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 OR Both SW subsystems inoperable.
OR UHS inoperable for reasons other than Condition A.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                FREQUENCY SR 3.7.1.1        Verify the water level of each UHS spray pond is    In accordance t 432 ft 9 inches mean sea level.                  with the Surveillance Frequency Control Program SR 3.7.1.2        Verify the average water temperature of each UHS    In accordance spray pond is d 77qF.                              with the Surveillance Frequency Control Program Columbia Generating Station                  3.7.1-2      Amendment No. 149,169 225
 
SW System and UHS 3.7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.7.1.3      -------------------------------NOTE------------------------------
Isolation of flow to individual components does not render SW subsystem inoperable.
Verify each SW subsystem manual, power                                In accordance operated, and automatic valve in the flow path                        with the servicing safety related systems or components,                        Surveillance that is not locked, sealed, or otherwise secured in                    Frequency position, is in the correct position.                                  Control Program SR 3.7.1.4      Verify average sediment depth in each UHS spray                        In accordance pond is < 0.5 ft.                                                      with the Surveillance Frequency Control Program SR 3.7.1.5      Verify each SW subsystem actuates on an actual or                      In accordance simulated initiation signal.                                          with the Surveillance Frequency Control Program Columbia Generating Station                      3.7.1-3              Amendment No. 149,169 225
 
HPCS SW System 3.7.2 3.7 PLANT SYSTEMS 3.7.2      High Pressure Core Spray (HPCS) Service Water (SW) System LCO 3.7.2            The HPCS SW System shall be OPERABLE.
APPLICABILITY:        MODES 1, 2, and 3.
ACTIONS CONDITION                            REQUIRED ACTION                            COMPLETION TIME A. HPCS SW System                  A.1        Declare HPCS System                      Immediately inoperable.                              inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.7.2.1        -------------------------------NOTE------------------------------
Isolation of flow to individual components does not render HPCS SW System inoperable.
Verify each HPCS SW System manual, power                                In accordance operated, and automatic valve in the flow path, that                    with the is not locked, sealed, or otherwise secured in                          Surveillance position, is in the correct position.                                  Frequency Control Program SR 3.7.2.2        Verify the HPCS SW System actuates on an actual                        In accordance or simulated initiation signal.                                        with the Surveillance Frequency Control Program Columbia Generating Station                        3.7.2-1              Amendment No. 149,169 225
 
CREF System 3.7.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR 3.7.3.1      Operate each CREF subsystem for t 10 continuous      In accordance hours with the heaters operating.                    with the Surveillance Frequency Control Program SR 3.7.3.2      Perform required CREF filter testing in accordance    In accordance with the Ventilation Filter Testing Program (VFTP). with the VFTP SR 3.7.3.3      Verify each CREF subsystem actuates on an actual      In accordance or simulated initiation signal.                      with the Surveillance Frequency Control Program SR 3.7.3.4      Perform required CRE unfiltered air inleakage        In accordance testing in accordance with the Control Room          with the Control Envelope Habitability Program.                        Room Envelope Habitability Program Columbia Generating Station                3.7.3-3        Amendment No. 199,207 225
 
Control Room AC System 3.7.4 ACTIONS CONDITION                      REQUIRED ACTION                COMPLETION TIME E. Required Action and          E.1    Initiate action to suspend    Immediately associated Completion              OPDRVs.
Time of Condition B not met during OPDRVs.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.7.4.1        Verify each control room AC subsystem has the        In accordance capability to remove the assumed heat load.          with the Surveillance Frequency Control Program Columbia Generating Station                3.7.4-2      Amendment No. 169,199 225 227
 
Main Condenser Offgas 3.7.5 SURVEILLANCE REQUIR5EMENTS SURVEILLANCE                                                    FREQUENCY SR 3.7.5.1      -------------------------------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 gases is d 332 mCi/second after decay of                                with the 30 minutes.                                                            Surveillance Frequency Control Program AND Once within 4 hours after a t 50% increase in the nominal steady state fission gas release after factoring out increases due to changes in THERMAL POWER level Columbia Generating Station                      3.7.5-2              Amendment No. 149,169 225
 
Main Turbine Bypass System 3.7.6 3.7 PLANT SYSTEMS 3.7.6      Main Turbine Bypass System LCO 3.7.6            The Main Turbine Bypass System shall be OPERABLE.
OR LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," limits for an inoperable Main Turbine Bypass System, as specified in the COLR, are made applicable.
APPLICABILITY:        THERMAL POWER t 25% RTP.
ACTIONS CONDITION                    REQUIRED ACTION                COMPLETION TIME A. Requirements of the          A.1    Satisfy the requirements of  2 hours LCO not met.                      the LCO.
B. Required Action and          B.1    Reduce THERMAL                4 hours associated Completion            POWER to < 25% RTP.
Time not met.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.7.6.1        Verify one complete cycle of each main turbine      In accordance bypass valve.                                        with the Surveillance Frequency Control Program Columbia Generating Station                3.7.6-1          Amendment No. 149,169 225
 
Main Turbine Bypass System 3.7.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE                            FREQUENCY SR 3.7.6.2      Perform a system functional test.            In accordance with the Surveillance Frequency Control Program SR 3.7.6.3      Verify the TURBINE BYPASS SYSTEM              In accordance RESPONSE TIME is within limits.              with the Surveillance Frequency Control Program Columbia Generating Station              3.7.6-2    Amendment No. 149,169 225
 
Spent Fuel Storage Pool Water Level 3.7.7 3.7 PLANT SYSTEMS 3.7.7        Spent Fuel Storage Pool Water Level LCO 3.7.7              The spent fuel storage pool water level shall be t 22 ft over the top of irradiated fuel assemblies seated in the spent fuel storage pool racks.
APPLICABILITY:        During movement of irradiated fuel assemblies in the spent fuel storage pool.
ACTIONS CONDITION                        REQUIRED ACTION                        COMPLETION TIME A. Spent fuel storage pool        A.1    ---------------NOTE--------------
water level not within                LCO 3.0.3 is not applicable.
limit.                                -------------------------------------
Suspend movement of                  Immediately irradiated fuel assemblies in the spent fuel storage pool.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                            FREQUENCY SR 3.7.7.1          Verify the spent fuel storage pool water level is              In accordance t 22 ft over the top of irradiated fuel assemblies            with the seated in the spent fuel storage pool racks.                  Surveillance Frequency Control Program Columbia Generating Station                      3.7.7-1              Amendment No. 149,169 225
 
AC Sources - Operating 3.8.1 ACTIONS CONDITION                    REQUIRED ACTION                        COMPLETION TIME C. Two offsite circuits    C.1        Declare required feature(s)          12 hours from inoperable.                        inoperable when the                  discovery of redundant required                    Condition C feature(s) are inoperable.            concurrent with inoperability of redundant required feature(s)
AND C.2        Restore one offsite circuit to        24 hours OPERABLE status.
D. One offsite circuit    --------------------NOTE-------------------
inoperable.            Enter applicable Conditions and Required Actions of LCO 3.8.7, AND                    "Distribution Systems - Operating,"
when Condition D is entered with no One required DG        AC power source to any division.
inoperable.            ------------------------------------------------
D.1        Restore offsite circuit to            12 hours OPERABLE status.
OR D.2        Restore required DG to                12 hours OPERABLE status.
E. Two required DGs        E.1        Restore one required DG to            2 hours inoperable.                        OPERABLE status.
OR 24 hours if Division 3 DG is inoperable F. Required Action and    F.1        Be in MODE 3.                        12 hours associated Completion Time of Condition A, B, AND C, D, or E not met.
F.2        Be in MODE 4.                        36 hours Columbia Generating Station                3.8.1-4              Amendment No. 169,197 225
 
AC Sources - Operating 3.8.1 ACTIONS CONDITION                            REQUIRED ACTION                            COMPLETION TIME G. Three or more required          G.1        Enter LCO 3.0.3.                        Immediately AC sources inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.1        Verify correct breaker alignment and indicated                          In accordance power availability for each offsite circuit.                            with the Surveillance Frequency Control Program SR 3.8.1.2        ------------------------------NOTES-----------------------------
: 1. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.
: 2. A modified DG start involving idling and 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 required DG starts from standby                            In accordance conditions and achieves steady state:                                  with the Surveillance
: a. Voltage t 3910 V and d 4400 V and frequency                      Frequency t 58.8 Hz and d 61.2 Hz for DG-1 and DG-2;                        Control Program and
: b. Voltage t 3910 V and d 4400 V and frequency t 58.8 Hz and d 61.2 Hz for DG-3.
Columbia Generating Station                        3.8.1-5              Amendment No. 169,181 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS 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.
: 5. The endurance test of SR 3.8.1.14 may be performed in lieu of the load-run test in SR 3.8.1.3 provided the requirements, except the upper load limits, of SR 3.8.1.3 are met.
Verify each required DG is synchronized and loaded                    In accordance and operates for t 60 minutes at a load t 4000 kW                      with the and d 4400 kW for DG-1 and DG-2, and t 2340 kW                        Surveillance and d 2600 kW for DG-3.                                                Frequency Control Program SR 3.8.1.4      Verify each required day tank contains fuel oil to                    In accordance support greater than or equal to one hour of                          with the operation at full load plus 10%.                                      Surveillance Frequency Control Program SR 3.8.1.5      Check for and remove accumulated water from each                      In accordance required day tank.                                                    with the Surveillance Frequency Control Program Columbia Generating Station                      3.8.1-6              Amendment No. 173,215 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.6      Verify each required fuel oil transfer subsystem                      In accordance operates to automatically transfer fuel oil from the                  with the storage tank to the day tank.                                          Surveillance Frequency Control Program SR 3.8.1.7      -------------------------------NOTE------------------------------
All DG starts may be preceded by an engine prelube period.
Verify each required DG starts from standby                            In accordance condition and achieves:                                                with the Surveillance
: a. For DG-1 and DG-2 in d 15 seconds, voltage                      Frequency t 3910 V and frequency t 58.8 Hz, and after                      Control Program steady state conditions are reached, maintains voltage t 3910 V and d 4400 V and frequency t 58.8 Hz and d 61.2 Hz; and
: b. For DG-3, in d 15 seconds, voltage t 3910 V and frequency t 58.8 Hz, and after steady state conditions are reached, maintains voltage t 3910 V and d 4400 V and frequency t 58.8 Hz and d 61.2 Hz.
SR 3.8.1.8      -------------------------------NOTE------------------------------
The automatic transfer function of this Surveillance shall not normally be performed in MODE 1 or 2.
However, this Surveillance may be performed to re-establish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify automatic and manual transfer of the power                      In accordance supply to safety related buses from the startup                        with the offsite circuit to the backup offsite circuit.                        Surveillance Frequency Control Program Columbia Generating Station                      3.8.1-7              Amendment No. 181,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.9      ------------------------------NOTES-----------------------------
: 1. Credit may be taken for unplanned events that satisfy this SR.
: 2. If performed with the DG synchronized with offsite power, it shall be performed at a power factor as close to the power factor of the single largest post-accident load as practicable.
However, if grid conditions do not permit, the power factor limit is not required to be met.
Under this condition, the power factor shall be maintained as close to the limit as practicable.
Verify each required DG rejects a load greater than                    In accordance or equal to its associated single largest post-                        with the accident load, and following load rejection, the                      Surveillance frequency is d 66.75 Hz.                                              Frequency Control Program SR 3.8.1.10      ------------------------------NOTES-----------------------------
: 1. Credit may be taken for unplanned events that satisfy this SR.
: 2. If performed with the DG synchronized with offsite power, it shall be performed at a power factor of d 0.9 for DG-1 and DG-2, and d 0.91 for DG-3. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition, the power factor shall be maintained as close to the limit as practicable.
Verify each required DG does not trip and voltage is                  In accordance maintained d 4784 V during and following a load                        with the rejection of a load t 4400 kW for DG-1 and DG-2                        Surveillance and t 2600 kW for DG-3.                                                Frequency Control Program Columbia Generating Station                      3.8.1-8              Amendment No. 203,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.11      ------------------------------NOTES-----------------------------
: 1. All DG starts may be preceded by an engine prelube period.
: 2. This Surveillance shall not normally be performed in MODE 1, 2, or 3 (not applicable to DG-3). However, portions of the Surveillance may be performed to re-establish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify on an actual or simulated loss of offsite power                In accordance signal:                                                                with the Surveillance
: a. De-energization of emergency buses;                              Frequency Control Program
: b. Load shedding from emergency buses for Divisions 1 and 2; and
: c. DG auto-starts from standby condition and:
: 1.      energizes permanently connected loads in d 15 seconds for DG-1 and DG-2, and in d 18 seconds for DG-3,
: 2.      energizes auto-connected shutdown loads,
: 3.      maintains steady state voltage t 3910 V and d 4400 V,
: 4.      maintains steady state frequency t 58.8 Hz and d 61.2 Hz, and
: 5.      supplies permanently connected and auto-connected shutdown loads for t 5 minutes.
Columbia Generating Station                      3.8.1-9              Amendment No. 203,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS 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 normally be performed in MODE 1 or 2 (not applicable to DG-3). However, portions of the Surveillance may be performed to re-establish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify on an actual or simulated Emergency Core                        In accordance Cooling System (ECCS) initiation signal each                          with the required DG auto-starts from standby condition and:                    Surveillance Frequency
: a. For DG-1 and DG-2, in d 15 seconds achieves                      Control Program voltage t 3910 V, and after steady state conditions are reached, maintains voltage t 3910 V and d 4400 V and, for DG-3, in d 15 seconds achieves voltage t 3910 V, and after steady state conditions are reached, maintains voltage t 3910 V and d 4400 V;
: b. In d 15 seconds, achieves frequency t 58.8 Hz and after steady state conditions are achieved, maintains frequency t 58.8 Hz and d 61.2 Hz;
: c. Operates for t 5 minutes;
: d. Permanently connected loads remain energized from the offsite power system; and
: e. Emergency loads are auto-connected to the offsite power system.
Columbia Generating Station                      3.8.1-10              Amendment No. 173,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.13      -------------------------------NOTE------------------------------
Credit may be taken for unplanned events that satisfy this SR.
Verify each required DG's automatic trips are                          In accordance bypassed on an actual or simulated ECCS initiation                    with the signal except:                                                        Surveillance Frequency
: a. Engine overspeed;                                                Control Program
: b. Generator differential current; and
: c. Incomplete starting sequence.
SR 3.8.1.14      ------------------------------NOTES-----------------------------
: 1. Momentary transients outside the load, excitation current, and power factor ranges do not invalidate this test.
: 2. Credit may be taken for unplanned events that satisfy this SR.
: 3. If performed with the DG synchronized with offsite power, it shall be performed at a power factor of d 0.9 for DG-1 and DG-2, and d 0.91 for DG-3. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition, the power factor shall be maintained as close to the limit as practicable.
Verify each required DG operates for t 24 hours:                      In accordance with the
: a. For t 2 hours loaded t 4650 kW for DG-1 and                      Surveillance DG-2, and t 2850 kW for DG-3; and                                Frequency Control Program
: b. For the remaining hours of the test loaded t 4400 kW for DG-1 and DG-2, and t 2600 kW for DG-3.
Columbia Generating Station                      3.8.1-11              Amendment No. 181,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.15      ------------------------------NOTES-----------------------------
: 1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated t 1 hour loaded t 4000 kW for DG-1 and DG-2, and t 2340 kW for DG-3.
Momentary transients outside of load range do not invalidate this test.
: 2. All DG starts may be preceded by an engine prelube period.
Verify each required DG starts and achieves:                          In accordance with the
: a. For DG-1 and DG-2, in d 15 seconds, voltage                      Surveillance t 3910 V and frequency t 58.8 Hz, and after                      Frequency steady state conditions are reached, maintains                  Control Program voltage t 3910 V and d 4400 V and frequency t 58.8 Hz and d 61.2 Hz; and
: b. For DG-3, in d 15 seconds, voltage t 3910 V and frequency t 58.8 Hz, and after steady state conditions are reached, maintains voltage t 3910 V and d 4400 V and frequency t 58.8 Hz and d 61.2 Hz.
Columbia Generating Station                      3.8.1-12              Amendment No. 203,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.16      -------------------------------NOTE------------------------------
This Surveillance shall not normally be performed in MODE 1, 2, or 3 (not applicable to DG-3). However, this Surveillance may be performed to re-establish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR.
Verify each required DG:                                              In accordance with the
: a. Synchronizes with offsite power source while                    Surveillance loaded with emergency loads upon a simulated                    Frequency restoration of offsite power;                                    Control Program
: b. Transfers loads to offsite power source; and
: c. Returns to ready-to-load operation.
SR 3.8.1.17      -------------------------------NOTE------------------------------
Credit may be taken for unplanned events that satisfy this SR.
Verify, with a DG operating in test mode and                          In accordance connected to its bus, an actual or simulated ECCS                      with the initiation signal overrides the test mode by:                          Surveillance Frequency
: a. Returning DG to ready-to-load operation; and                    Control Program
: b. Automatically energizing the emergency load from offsite power.
Columbia Generating Station                      3.8.1-13              Amendment No. 203,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.18      -------------------------------NOTE------------------------------
This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this Surveillance may be performed to re-establish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify interval between each sequenced load block                      In accordance is within +/- 10% of design interval for each time delay                with the relay.                                                                Surveillance Frequency Control Program Columbia Generating Station                      3.8.1-14              Amendment No. 203,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS 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 normally be performed in MODE 1, 2, or 3 (not applicable to DG-3). However, portions of the Surveillance may be performed to re-establish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify, on an actual or simulated loss of offsite                      In accordance power signal in conjunction with an actual or                          with the simulated ECCS initiation signal:                                      Surveillance Frequency
: a. De-energization of emergency buses;                              Control Program
: b. Load shedding from emergency buses for DG-1 and DG-2; and
: c. DG auto-starts from standby condition and:
: 1.      energizes permanently connected loads in d 15 seconds,
: 2.      energizes auto-connected emergency loads,
: 3.      maintains steady state voltage t 3910 V and d 4400 V,
: 4.      maintains steady state frequency t 58.8 Hz and d 61.2 Hz, and
: 5.      supplies permanently connected and auto-connected emergency loads for t 5 minutes.
Columbia Generating Station                      3.8.1-15              Amendment No. 203,204 225
 
AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.1.20      -------------------------------NOTE------------------------------
All DG starts may be preceded by an engine prelube period.
Verify, when started simultaneously from standby                      In accordance condition, DG-1 and DG-2 achieves, in                                  with the d 15 seconds, voltage t 3910 V and frequency                          Surveillance t 58.8 Hz, and DG-3 achieves, in d 15 seconds,                        Frequency voltage t 3910 V and frequency t 58.8 Hz.                              Control Program Columbia Generating Station                      3.8.1-16                    Amendment No. 204 225
 
Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS CONDITION                          REQUIRED ACTION                COMPLETION TIME E. One or more DGs with          E.1      Restore required starting air  48 hours required starting air                    receiver pressure to within receiver pressure:                      limit.
: 1. For DG-1 and DG-2,
        < 230 psig and t 150 psig; and
: 2. For DG-3, < 223 psig and t 150 psig.
F. Required Action and            F.1      Declare associated DG          Immediately associated Completion                    inoperable.
Time of Condition A, B, C, D, or E not met.
OR One or more DGs with stored diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than Condition A, B, C, D, or E.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.8.3.1            Verify each fuel oil storage subsystem contains        In accordance greater than or equal to a seven day supply of fuel. with the Surveillance Frequency Control Program Columbia Generating Station                    3.8.3-2        Amendment No. 169,215 225
 
Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.8.3.2      Verify lube oil inventory is greater than or equal to a  In accordance seven day supply.                                        with the Surveillance Frequency Control Program SR 3.8.3.3      Verify fuel oil properties of new and stored fuel oil    In accordance are tested in accordance with, and maintained within      with the Diesel the limits of, the Diesel Fuel Oil Testing Program.      Fuel Oil Testing Program SR 3.8.3.4      Verify each required DG air start receiver pressure      In accordance is:                                                      with the Surveillance
: a. t 230 psig for DG-1 and DG-2; and                    Frequency Control Program
: b. t 223 psig for DG-3.
SR 3.8.3.5      Check for and remove accumulated water from each          In accordance fuel oil storage tank.                                    with the Surveillance Frequency Control Program Columbia Generating Station                3.8.3-3          Amendment No. 169,215 225
 
DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.4.1      Verify battery terminal voltage is greater than or                    In accordance equal to the minimum established float voltage.                        with the Surveillance Frequency Control Program SR 3.8.4.2      Verify each required battery charger supplies the                      In accordance required load for t 1.5 hours at:                                      with the Surveillance
: a. t 126 V for the 125 V battery chargers; and                      Frequency Control Program
: b. t 252 V for the 250 V battery charger.
SR 3.8.4.3      ------------------------------NOTES-----------------------------
: 1. The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.3.
: 2. This Surveillance shall not be performed in MODE 1, 2, or 3 for the Division 1 and 2 125 V DC batteries. However, credit may be taken for unplanned events that satisfy this SR.
Verify battery capacity is adequate to supply, and                    In accordance maintain in OPERABLE status, the required                              with the emergency loads for the design duty cycle when                        Surveillance subjected to a battery service test.                                  Frequency Control Program Columbia Generating Station                      3.8.4-4                    Amendment 169,204 225
 
Battery Parameters 3.8.6 ACTIONS CONDITION                              REQUIRED ACTION                            COMPLETION TIME F. One or more batteries              F.1        Declare associated battery              Immediately with a required battery                      inoperable.
parameter not met for reasons other than Condition A, B, C, D, or E.
OR Required Action and associated Completion Time of Condition A, B, C, D, or E not met.
OR One or more batteries with one or more battery cell(s) float voltage
    < 2.07 V and float current > 2 amps.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.8.6.1          -------------------------------NOTE------------------------------
Not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1.
Verify each battery float current is d 2 amps.                          In accordance with the Surveillance Frequency Control Program Columbia Generating Station                          3.8.6-3                    Amendment 169,204 225
 
Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.8.6.2      Verify each battery pilot cell voltage is t 2.07 V. In accordance with the Surveillance Frequency Control Program SR 3.8.6.3      Verify each battery connected cell electrolyte level is In accordance greater than or equal to minimum established            with the design limits.                                          Surveillance Frequency Control Program SR 3.8.6.4      Verify each battery pilot cell temperature is greater  In accordance than or equal to minimum established design limits. with the Surveillance Frequency Control Program SR 3.8.6.5      Verify each battery connected cell voltage is          In accordance t 2.07 V.                                              with the Surveillance Frequency Control Program Columbia Generating Station                3.8.6-4                Amendment 169,204 225
 
Battery Parameters 3.8.6 SURVEILLANCE                                                FREQUENCY SR 3.8.6.6      -------------------------------NOTE------------------------------
This Surveillance shall not be performed in MODE 1, 2, or 3 for the Division 1 and 2 125 V DC batteries. However, credit may be taken for unplanned events that satisfy this SR.
Verify battery capacity is t 80% of the                              In accordance manufacturer's rating for the 125 V batteries and                    with the
                   83.4% of the manufacturer's rating for the 250 V                    Surveillance battery, when subjected to a performance discharge                    Frequency test or a modified performance discharge test.                        Control Program AND 12 months when battery shows degradation or has reached 85%
of expected life with capacity
                                                                                        < 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected life with capacity t 100% of manufacturer's rating Columbia Generating Station                      3.8.6-5                    Amendment 169,204 225
 
Distribution Systems - Operating 3.8.7 ACTIONS 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 D. Division 1 250 V DC          D.1      Declare associated            Immediately electrical power                      supported feature(s) distribution subsystem                inoperable.
inoperable.
E. One or more Division 3        E.1      Declare High Pressure          Immediately AC or DC electrical                    Core Spray System power distribution                    inoperable.
subsystems inoperable.
F. Two or more divisions        F.1      Enter LCO 3.0.3.              Immediately with inoperable electrical power distribution subsystems that result in a loss of function.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.8.7.1          Verify correct breaker alignments and indicated        In accordance power availability to required AC and DC electrical    with the power distribution subsystems.                          Surveillance Frequency Control Program Columbia Generating Station                  3.8.7-2            Amendment 149,169 225
 
Distribution Systems - Shutdown 3.8.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.8.8.1      Verify correct breaker alignments and indicated          In accordance power availability to required AC and DC electrical      with the power distribution subsystems.                          Surveillance Frequency Control Program Columbia Generating Station                3.8.8-2              Amendment 169,199 225
 
Refueling Equipment Interlocks 3.9.1 3.9 REFUELING OPERATIONS 3.9.1        Refueling Equipment Interlocks LCO 3.9.1              The refueling equipment interlocks associated with the refuel position shall be OPERABLE.
APPLICABILITY:          During in-vessel fuel movement with equipment associated with the interlocks when the reactor mode switch is in the refuel position.
ACTIONS CONDITION                      REQUIRED ACTION                  COMPLETION TIME A. One or more required            A.1    Suspend in-vessel fuel          Immediately refueling equipment                  movement with equipment interlocks inoperable.                associated with the inoperable interlock(s).
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.9.1.1          Perform CHANNEL FUNCTIONAL TEST on each of                In accordance the following required refueling equipment interlock      with the inputs:                                                  Surveillance Frequency
: a. All-rods-in,                                        Control Program
: b. Refueling platform position,
: c. Refueling platform fuel grapple fuel-loaded,
: d. Refueling platform frame-mounted hoist fuel-loaded, and
: e. Refueling platform trolley-mounted hoist fuel-loaded.
Columbia Generating Station                    3.9.1-1              Amendment 149,169 225
 
Refuel 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.
AND A.2      Initiate action to fully insert  Immediately all 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.      In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.9.2-1                Amendment 149,169 225
 
Refuel Position One-Rod-Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS 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.                                      In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.9.2-2                    Amendment 149,169 225
 
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.
APPLICABILITY:          When loading fuel assemblies into the core.
ACTIONS CONDITION                          REQUIRED ACTION              COMPLETION TIME A. One or more control              A.1      Suspend loading fuel        Immediately rods not fully inserted.                assemblies into the core.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                  FREQUENCY SR 3.9.3.1            Verify all control rods are fully inserted.          In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.9.3-1            Amendment 149,169 225
 
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.                  In accordance with the Surveillance Frequency Control Program SR 3.9.5.2          Verify each withdrawn control rod scram                                In accordance accumulator pressure is t 940 psig.                                    with the Surveillance Frequency Control Program Columbia Generating Station                          3.9.5-1                          Amendment 149,169 225
 
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 t 22 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          A.1    Suspend movement of              Immediately within limit.                      irradiated fuel assemblies within the RPV.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.9.6.1          Verify RPV water level is t 22 ft above the top of the  In accordance RPV flange.                                              with the Surveillance Frequency Control Program Columbia Generating Station                  3.9.6-1              Amendment 149,169 225
 
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 t 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            A.1    Suspend movement of new          Immediately within limit.                      fuel assemblies and handling of control rods within the RPV.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                      FREQUENCY SR 3.9.7.1          Verify RPV water level is t 23 ft above the top of        In accordance irradiated fuel assemblies seated within the RPV.        with the Surveillance Frequency Control Program Columbia Generating Station                  3.9.7-1              Amendment 169,199 225
 
RHR - High Water Level 3.9.8 ACTIONS CONDITION                    REQUIRED ACTION                  COMPLETION TIME B. (continued)                B.3    Initiate action to restore one Immediately standby gas treatment subsystem to OPERABLE status.
AND B.4    Initiate action to restore    Immediately isolation capability in each required secondary containment penetration flow path not isolated.
C. No RHR shutdown            C.1    Verify reactor coolant        1 hour from discovery cooling subsystem in              circulation by an alternate    of no reactor coolant operation.                        method.                        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          In accordance operating.                                            with the Surveillance Frequency Control Program Columbia Generating Station                3.9.8-2              Amendment 149,169 225
 
RHR - Low Water Level 3.9.9 ACTIONS CONDITION                    REQUIRED ACTION                  COMPLETION TIME B. (continued)                B.3    Initiate action to restore    Immediately isolation capability in each required secondary containment penetration flow path not isolated.
C. No RHR shutdown            C.1    Verify reactor coolant        1 hour from discovery cooling subsystem in              circulation by an alternate    of no reactor coolant operation.                        method.                        circulation AND Once per 12 hours thereafter AND C.2    Monitor reactor coolant        Once per hour temperature.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.9.9.1        Verify one RHR shutdown cooling subsystem is          In accordance operating.                                            with the Surveillance Frequency Control Program Columbia Generating Station                3.9.9-2              Amendment 149,169 225
 
Reactor Mode Switch Interlock Testing 3.10.2 ACTIONS CONDITION                      REQUIRED ACTION                        COMPLETION TIME A. (continued)                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        In accordance containing one or more fuel assemblies.                        with the Surveillance Frequency Control Program SR 3.10.2.2      Verify no CORE ALTERATIONS are in progress.                    In accordance with the Surveillance Frequency Control Program Columbia Generating Station                3.10.2-2                    Amendment 149,169 225
 
Single Control Rod Withdrawal - Hot Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.10.3.2      -------------------------------NOTE------------------------------
Not 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                  In accordance being withdrawn, in a five by five array centered on                  with the the control rod being withdrawn, are disarmed.                        Surveillance Frequency Control Program SR 3.10.3.3      Verify all control rods, other than the control rod                  In accordance being withdrawn, are fully inserted.                                  with the Surveillance Frequency Control Program Columbia Generating Station                      3.10.3-3                    Amendment 149,169 225
 
Single Control Rod Withdrawal - Cold Shutdown 3.10.4 ACTIONS CONDITION                            REQUIRED ACTION                            COMPLETION TIME B. (continued)                    B.2.2      Initiate action to satisfy the          Immediately requirements of this LCO.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.10.4.1      Perform the applicable SRs for the required LCOs.                      According to the applicable SRs SR 3.10.4.2      -------------------------------NOTE------------------------------
Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.c.1 requirements.
Verify all control rods, other than the control rod                    In accordance being withdrawn, in a five by five array centered on                    with the the control rod being withdrawn, are disarmed.                          Surveillance Frequency Control Program SR 3.10.4.3      Verify all control rods, other than the control rod                    In accordance being withdrawn, are fully inserted.                                    with the Surveillance Frequency Control Program SR 3.10.4.4      -------------------------------NOTE------------------------------
Not 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.                      In accordance with the Surveillance Frequency Control Program Columbia Generating Station                      3.10.4-3                    Amendment 149,169 225
 
Single CRD Removal - Refueling 3.10.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                    FREQUENCY SR 3.10.5.1      Verify all control rods, other than the control rod    In accordance withdrawn for the removal of the associated CRD,        with the are fully inserted.                                    Surveillance Frequency Control Program SR 3.10.5.2      Verify all control rods, other than the control rod    In accordance withdrawn for the removal of the associated CRD, in    with the a five by five array centered on the control rod        Surveillance withdrawn for the removal of the associated CRD,        Frequency are disarmed.                                          Control Program SR 3.10.5.3      Verify a control rod withdrawal block is inserted.      In accordance with the Surveillance Frequency Control Program 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 other CORE ALTERATIONS are in                In accordance progress.                                              with the Surveillance Frequency Control Program Columbia Generating Station                3.10.5-2              Amendment 149,169 225
 
Multiple Control Rod Withdrawal - Refueling 3.10.6 ACTIONS CONDITION                            REQUIRED ACTION                            COMPLETION TIME A. (continued)                    A.3.1      Initiate action to fully insert          Immediately all control rods in core cells containing one or more fuel assemblies.
OR A.3.2      Initiate action to satisfy the          Immediately requirements of this LCO.
SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                  FREQUENCY SR 3.10.6.1      Verify the four fuel assemblies are removed from                        In accordance core cells associated with each control rod or CRD                      with the removed.                                                                Surveillance Frequency Control Program SR 3.10.6.2      Verify all other control rods in core cells containing                  In accordance one or more fuel assemblies are fully inserted.                        with the Surveillance Frequency Control Program SR 3.10.6.3      -------------------------------NOTE------------------------------
Only required to be met during fuel loading.
Verify fuel assemblies being loaded are in                              In accordance compliance with an approved spiral reload                              with the sequence.                                                              Surveillance Frequency Control Program Columbia Generating Station                      3.10.6-2                    Amendment 149,169 225
 
SDM Test - Refueling (Prior to Implementation of PRNM Upgrade) 3.10.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.10.8.3      -------------------------------NOTE------------------------------
Not required to be met if SR 3.10.8.2 satisfied.
Verify movement of control rods is in compliance                      During control rod with the approved control rod sequence for the SDM                    movement test 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                              In accordance progress.                                                            with the Surveillance Frequency Control Program 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 AND 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                            In accordance t 940 psig.                                                          with the Surveillance Frequency Control Program Columbia Generating Station                      3.10.8-3            Amendment No. 169 225 226
 
SDM Test - Refueling (After Implementation of PRNM Upgrade) 3.10.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE                                                FREQUENCY SR 3.10.8.3      -------------------------------NOTE------------------------------
Not required to be met if SR 3.10.8.2 satisfied.
Verify movement of control rods is in compliance                      During control rod with the approved control rod sequence for the SDM                    movement test 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                              In accordance progress.                                                            with the Surveillance Frequency Control Program 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 AND 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                            In accordance t 940 psig.                                                          with the Surveillance Frequency Control Program Columbia Generating Station                      3.10.8-7              Amendment No. 169 225 226
 
Programs and Manuals 5.5 5.5  Programs and Manuals 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 OPERABLE Control Room Emergency Filtration (CREF) 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 (DBA) 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 Regulatory Guide 1.197, Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors, Revision 0, May 2003, and (ii) assessing CRE habitability at Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.
: 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 CREF 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 the 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 for DBA 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.
Columbia Generating Station                    5.5-11                Amendment 191,204 225
 
Programs and Manuals 5.5 5.5  Programs and Manuals 5.5.15 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.
: a.      The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program.
: 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 Control of Surveillance Frequencies," Revision 1.
: 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.
Columbia Generating Station                    5.5-12              Amendment 207,216 225
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TSTF - 425, REVISION 3  - Markup of Proposed Technical Specification Bases Pages Page 1 of 1 MARKUP OF PROPOSED TECHNICAL SPECIFICATIONS BASES PAGES (Note: TS Bases pages are provided for information only. In addition, for TS Bases 3.2.4, 3.3.1.1, 3.3.1.3, 3.3.2.1, 3.4.1, and 3.10.8, only the Bases pages for the "Prior to Implementation of PRNM Upgrade" Specifications are included. The "After Implementation of PRNM Upgrade" Specifications are not effective at this time, and the associated Bases for these Specifications have not been issued. The Bases wording for the SRs effective after PRNM implementation will be consistent with the changes shown in the "Prior to Implementation of PRNM Upgrade" Bases changes.)
B 3.1.3-7      B 3.3.2.1-8      B 3.3.7.1-7    B 3.6.1.1-5    B 3.7.3-6      B 3.8.6-8 B 3.1.4-4      B 3.3.2.1-9      B 3.3.7.1-8    B 3.6.1.2-6    B 3.7.4-4      B 3.8.6-9 B 3.1.5-4      B 3.3.2.1-10    B 3.3.8.1-8    B 3.6.1.2-7    B 3.7.5-2      B 3.8.7-7 B 3.1.6-4      B 3.3.2.1-11    B 3.3.8.1-9    B 3.6.1.3-8    B 3.7.6-2      B 3.8.8-3 B 3.1.7-3      B 3.3.2.2-4      B 3.3.8.2-6    B 3.6.1.3-9    B 3.7.6-3      B 3.9.1-3 B 3.1.7-4      B 3.3.2.2-5      B 3.3.8.2-7    B 3.6.1.3-10  B 3.7.7-2      B 3.9.2-3 B 3.1.7-5      B 3.3.2.2-6      B 3.3.8.2-8    B 3.6.1.3-11  B 3.8.1-16    B 3.9.3-2 B 3.1.7-6      B 3.3.3.1-8      B 3.4.1-5      B 3.6.1.3-12  B 3.8.1-17    B 3.9.5-2 B 3.1.8-3      B 3.3.3.1-9      B 3.4.2-3      B 3.6.1.3-13  B 3.8.1-18    B 3.9.6-2 B 3.1.8-4      B 3.3.3.2-4      B 3.4.3-4      B 3.6.1.3-14  B 3.8.1-19    B 3.9.7-2 B 3.2.1-2      B 3.3.3.2-5      B 3.4.4-3      B 3.6.1.3-15  B 3.8.1-20    B 3.9.8-3 B 3.2.2-3      B 3.3.3.2-6      B 3.4.4-4      B 3.6.1.3-16  B 3.8.1-21    B 3.9.9-3 B 3.2.3-2      B 3.3.4.1-7      B 3.4.5-4      B 3.6.1.4-2    B 3.8.1-24    B 3.10.2-4 B 3.2.4-5      B 3.3.4.1-8      B 3.4.5-5      B 3.6.1.5-3    B 3.8.1-25    B 3.10.3-4 B 3.3.1.1-21    B 3.3.4.1-9      B 3.4.7-6      B 3.6.1.6-4    B 3.8.1-27    B 3.10.4-5 B 3.3.1.1-22    B 3.3.4.1-10    B 3.4.7-7      B 3.6.1.6-5    B 3.8.1-28    B 3.10.5-4 B 3.3.1.1-23    B 3.3.4.2-6      B 3.4.7-8      B 3.6.1.7-4    B 3.8.1-29    B 3.10.6-3 B 3.3.1.1-24    B 3.3.4.2-7      B 3.4.8-3      B 3.6.1.7-5    B 3.8.1-31    B 3.10.8-4 B 3.3.1.1-25    B 3.3.4.2-8      B 3.4.9-4      B 3.6.2.1-4    B 3.8.1-32    B 3.10.8-5 B 3.3.1.1-26    B 3.3.4.2-9      B 3.4.10-4    B 3.6.2.2-3    B 3.8.1-33 B 3.3.1.1-27    B 3.3.5.1-31    B 3.4.11-6    B 3.6.2.3-3    B 3.8.1-34 B 3.3.1.1-28    B 3.3.5.1-32    B 3.4.11-8    B 3.6.3.2-4    B 3.8.1-35 B 3.3.1.1-29    B 3.3.5.1-33    B 3.4.12-2    B 3.6.3.3-2    B 3.8.1-36 B 3.3.1.1-30    B 3.3.5.2-8      B 3.5.1-8      B 3.6.4.1-3    B 3.8.1-37 B 3.3.1.1-31    B 3.3.5.2-9      B 3.5.1-9      B 3.6.4.1-4    B 3.8.1-38 B 3.3.1.2-5    B 3.3.5.2-10    B 3.5.1-10    B 3.6.4.1-5    B 3.8.1-39 B 3.3.1.2-6    B 3.3.6.1-32    B 3.5.1-11    B 3.6.4.1-6    B 3.8.1-40 B 3.3.1.2-7    B 3.3.6.1-33    B 3.5.1-12    B 3.6.4.2-5    B 3.8.3-6 B 3.3.1.2-8    B 3.3.6.1-34    B 3.5.1-13    B 3.6.4.2-6    B 3.8.3-7 B 3.3.1.2-9    B 3.3.6.1-35    B 3.5.2-4      B 3.6.4.3-4    B 3.8.3-9 B 3.3.1.2-10    B 3.3.6.1-36    B 3.5.2-5      B 3.6.4.3-5    B 3.8.3-10 B 3.3.1.3-5    B 3.3.6.2-8      B 3.5.3-3      B 3.7.1-5      B 3.8.4-8 B 3.3.1.3-6    B 3.3.6.2-9      B 3.5.3-4      B 3.7.1-6      B 3.8.4-9 B 3.3.1.3-7    B 3.3.6.2-10    B 3.5.3-5      B 3.7.2-2      B 3.8.6-6 B 3.3.2.1-7    B 3.3.6.2-11    B 3.6.1.1-4    B 3.7.2-3      B 3.8.6-7
 
Control Rod OPERABILITY B 3.1.3 BASES 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 Frequency of this SR is based on operating experience related to expected changes in control rod position and the availability of control rod position indications in the control room.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.1.3.2 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 not required when THERMAL POWER is less than or equal to the actual LPSP of the RWM since the notch insertions may not be compatible with the requirements of the Banked Position Withdrawal Sequence (BPWS) (LCO 3.1.6) and the RWM (LCO 3.3.2.1). 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 determination of that control rod's trippability (OPERABILITY) must be made and appropriate action taken. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
This SR is modified by a Note that allows 31 days, after withdrawal of the control rod and increasing power to above the LPSP, to perform the Surveillance. This acknowledges that the control rod must be first withdrawn and THERMAL POWER must be increased to above the LPSP before performance of the Surveillance, and therefore the Note avoids potential conflicts with SR 3.0.3 and SR 3.0.4.
Columbia Generating Station            B 3.1.3-7                                    Revision 73
 
Control Rod Scram Times B 3.1.4 BASES SURVEILLANCE REQUIREMENTS (continued) required to be tested before exceeding 40% RTP. This Frequency is acceptable, considering the additional surveillances performed for control rod OPERABILITY, the frequent verification of adequate accumulator pressure, and the required testing of control rods affected by fuel movement within the associated core cell and by work on control rods or the CRD System.
SR 3.1.4.2 Additional testing of a sample of control rods is required to verify the continued performance of the scram function during the cycle. A representative sample contains at least 10% of the control rods. The sample remains representative if no more than 7.5% of the control rods in the sample tested are determined to be "slow." If more than 7.5% of the sample is declared to be "slow" per the criteria in Table 3.1.4-1, additional control rods are tested until this 7.5% criterion (i.e., 7.5% 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 200 day Frequency is based on operating experience that has shown control rod scram times do not significantly change over an operating cycle. This Frequency is also reasonable, based on the additional Surveillances done on the CRDs at more frequent intervals in accordance with LCO 3.1.3 and LCO 3.1.5, "Control Rod Scram Accumulators."The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
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 < 800 psig are found in the Licensee Controlled Specifications Manual (Ref. 8), and are established based on a high probability of meeting the acceptance criteria at reactor pressures t 800 psig. Limits for t 800 psig are found in Table 3.1.4-1. If testing demonstrates the affected control rod does not meet these limits, Columbia Generating Station            B 3.1.4-4                                      Revision 73
 
Control Rod Scram Accumulators B 3.1.5 BASES ACTIONS (continued) more important since the scram function could become severely degraded during a depressurization event or at low reactor pressures.
Therefore, immediately upon discovery of charging water header pressure < 940 psig, concurrent with Condition C, all control rods associated with inoperable accumulators must be verified to be fully inserted. Withdrawn control rods with inoperable scram accumulators may fail to scram under these low pressure conditions. The associated control rods must also be declared inoperable within 1 hour. The allowed Completion Time of 1 hour is reasonable for Required Action C.2, considering the low probability of a DBA or transient occurring during the time the accumulator is inoperable.
D.1 The reactor mode switch must be immediately placed in the shutdown position if either Required Action and associated Completion Time associated with loss of the CRD charging pump (Required Actions B.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 days periodically 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 considered inoperable. The minimum accumulator pressure of 940 psig is well below the expected pressure of 1050 psig to 1100 psig (Ref. 2).
Declaring the accumulator inoperable when the minimum pressure is not maintained ensures that significant degradation in scram times does not occur. The 7 day Frequency has been shown to be acceptable through operating experience and takes into account indications available in the control room.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.1.5-4                                    Revision 73
 
Rod Pattern Control B 3.1.6 BASES SURVEILLANCE        SR 3.1.6.1 REQUIREMENTS The control rod pattern is periodically verified to be in compliance with the BPWS at a 24 hour Frequency, ensuring the assumptions of the CRDA analyses are met. The 24 hour Frequency of this Surveillance was developed considering that the primary check of the control rod pattern compliance with the BPWS is performed by the RWM (LCO 3.3.2.1). The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The RWM provides control rod blocks to enforce the required control rod sequence and is required to be OPERABLE when operating at d 10% RTP.
REFERENCES        1. Letter from T.A. Pickens (BWROG) to G.C. Laines (NRC),
                        "Amendment 17 to General Electric Licensing Topical Report NEDE-24011-P-A," BWROG-8644, August 15, 1988.
: 2. FSAR, Section 15.4.9.
: 3. NUREG-0979, "NRC Safety Evaluation Report for 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.
: 5. 10 CFR 50.67, "Accident Source Term."
: 6. NEDO-10527, "Rod Drop Accident Analysis for Large Boiling Water Reactors," (March 1972); Supplement 1, (July 1972); Supplement 2, (January 1973).
: 7. NEDO-21778-A, "Transient Pressure Rises Affected Fracture Toughness Requirements for Boiling Water Reactors,"
December 1978.
: 8. ASME, Boiler and Pressure Vessel Code, Section III.
: 9. NEDO-21231, "Banked Position Withdrawal Sequence,"
January 1977.
: 10. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station          B 3.1.6-4                                      Revision 77
 
SLC System B 3.1.7 BASES ACTIONS (continued) requirements of Reference 1. The 7 day Completion Time is based on the availability of an OPERABLE subsystem capable of performing the original licensing basis SLC System function and the low probability of a Design Basis Accident (DBA) or severe transient occurring concurrent with the failure of the Control Rod Drive System to shut down the plant.
B.1 If both SLC subsystems are inoperable, at least one subsystem must be restored to OPERABLE status within 8 hours. The allowed Completion Time of 8 hours is considered acceptable, given the low probability of a DBA or transient occurring concurrent with the failure of the control rods to shut down the reactor.
C.1 and C.2 If any Required Action and associated Completion Time is not met, 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 3.1.7.1 and SR 3.1.7.2 REQUIREMENTS SR 3.1.7.1 and SR 3.1.7.2 are 24 hour Surveillances, verifying 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 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. The 24 hour Frequency of these SRs is based on operating experience that has shown there are relatively slow variations in the measured parameters of volume and temperature.The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.1.7-3                                  Revision 73
 
SLC System B 3.1.7 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.1.7.3 and SR 3.1.7.5 SR 3.1.7.3 verifies the continuity of the explosive charges in the injection valves to ensure proper operation will occur if required. Other administrative controls, such as those that limit the shelf life of the explosive charges, must be followed. The 31 day Frequency is based on operating experience that has demonstrated the reliability of the explosive charge continuity.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.1.7.5 verifies each valve in the system is in its correct position, but does not apply to the squib (i.e., explosive) valves. Verifying the correct alignment for manual and power operated 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 control. 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 apply to valves that cannot be inadvertently misaligned, such as check valves. 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 positions. The 31 day Frequency is based on engineering judgment and is consistent with the procedural controls governing valve operation that ensure correct valve positions. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.1.7.4 This Surveillance requires an examination of the sodium pentaborate solution by using chemical analysis to ensure the proper concentration of boron (measured in weight % sodium pentaborate decahydrate) exists in the storage tank. SR 3.1.7.4 must be performed anytime boron or water is added to the storage tank solution to establish that the boron solution concentration is within the specified limits. This Surveillance must be performed anytime the temperature is restored to within the limits of Figure 3.1.7-1, to ensure no significant boron precipitation occurred. The 31 day Frequency of this Surveillance is appropriate because of the relatively slow variation of boron concentration between surveillances.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.1.7-4                                      Revision 73
 
SLC System B 3.1.7 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.1.7.6 Demonstrating each SLC System pump develops a flow rate t 41.2 gpm at a discharge pressure t 1220 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 tests confirm component OPERABILITY and detect incipient failures by indicating abnormal performance. The Frequency of this Surveillance is in accordance with the Inservice Testing Program.
SR 3.1.7.7 and SR 3.1.7.8 These Surveillances ensure 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. 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. 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. Operating experience has shown these components usually pass the Surveillance test when performed at the 24 month Frequency; therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequency for SR 3.1.7.7 is controlled under the Surveillance Frequency Control Program.
Demonstrating that all heat traced piping between the boron solution storage tank and the suction valve to the injection pumps is unblocked ensures that there is a functioning flow path for injecting the sodium pentaborate solution. An acceptable method for verifying that the suction piping up to the suction valve is unblocked is to pump from the storage tank to the test tank. Upon completion of this verification, the pump suction piping must be drained and flushed with demineralized water since the suction piping between the pump suction valve and pump Columbia Generating Station            B 3.1.7-5                                    Revision 73
 
SLC System B 3.1.7 BASES SURVEILLANCE REQUIREMENTS (continued) suction is not heat traced. The 24 month Frequency is acceptable since there is a low probability that the subject piping will be blocked due to precipitation of the boron from solution in the heat traced piping. The Surveillance Frequency for SR 3.1.7.8 is controlled under the Surveillance Frequency Control Program. However, if, in performing SR 3.1.7.1, it is determined that the temperature of the solution in the storage tank has fallen below the specified minimum, SR 3.1.7.8 must be performed once within 24 hours after the solution temperature is restored within the limits of Figure 3.1.7-1.
SR 3.1.7.9 Enriched sodium pentaborate solution is made by mixing granular, enriched sodium pentaborate with water. Isotopic tests on the granular sodium pentaborate to verify the actual B-10 enrichment must be performed prior to addition to the SLC tank in order to ensure that the proper B-10 atom percentage is being used.
REFERENCES        1. 10 CFR 50.62.
: 2. FSAR, Section 9.3.5.3.
: 3. 10 CFR 50.36(c)(2)(ii).
: 4. Regulatory Guide 1.183, July 2000.
: 5. 10 CFR 50.67, "Accident Source Term."
Columbia Generating Station            B 3.1.7-6                                    Revision 73
 
SDV Vent and Drain Valves B 3.1.8 BASES ACTIONS (continued)
B.1 If both valves in a line are inoperable, the line must be isolated to contain the reactor coolant during a scram. The 8 hour Completion Time to isolate the line is based on the low probability of a scram occurring while the line is not isolated and unlikelihood of significant CRD seal leakage.
C.1 If any Required Action and associated Completion Time is not met, 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 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 3.1.8.1 REQUIREMENTS During normal operation, the 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 operation, which ensure correct valve positions. Improper valve position (closed) would not affect the isolation function.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.1.8.2 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.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.1.8-3                                      Revision 73
 
SDV Vent and Drain Valves B 3.1.8 BASES SURVEILLANCE REQUIREMENTS (continued)
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 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 testing of control rods in LCO 3.1.3, "Control Rod - OPERABILITY," overlap 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. Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency; therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES        1. FSAR, Section 4.6.1.1.2.4.2.5.
: 2. 10 CFR 50.67, "Accident Source Term."
: 3. NUREG-0803, "Generic Safety Evaluation Report Regarding Integrity of BWR Scram System Piping," August 1981.
: 4. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.1.8-4                                    Revision 73
 
APLHGR B 3.2.1 BASES APPLICABILITY      The APLHGR limits are primarily derived from fuel design evaluations and LOCA analyses that are assumed to occur at high power levels. Studies and operating experience have shown that as power is reduced, the margin to the required APLHGR limits increases. This trend continues down to the power range of 5% to 15% RTP when entry into MODE 2 occurs, thereby effectively removing any APLHGR limit compliance concern in MODE 2. Therefore, at THERMAL POWER levels 25% RTP, the reactor operates with substantial margin to the APLHGR limits; thus, this LCO is not required.
ACTIONS            A.1 If any APLHGR exceeds the required limits, an assumption regarding an initial condition of the DBA analyses may not be met. Therefore, prompt action is taken to restore the APLHGR(s) to within the required limits 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 limits and is acceptable based on the low probability of a DBA occurring simultaneously with the APLHGR out of specification.
B.1 If the APLHGR cannot be restored to within its required limits 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 < 25% RTP within 4 hours. The allowed Completion Time is reasonable, based on operating experience, to reduce THERMAL POWER to < 25% 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 t 25% 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 recognition of the slowness of changes in power distribution under normal conditions. The 12 hour allowance after THERMAL POWER t 25% RTP is achieved is acceptable given the large inherent margin to operating limits at low power levels. The periodic Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.2.1-2                                  Revision 73
 
MCPR B 3.2.2 BASES ACTIONS            A.1 If any MCPR is outside the required limits, an assumption regarding an initial condition of the design basis transient analyses may not be met.
Therefore, prompt action should be taken to restore the MCPR(s) to within the required limits such that the plant remains operating within analyzed conditions. The 2 hour Completion Time is normally sufficient to restore the MCPR(s) to within its limits and is acceptable based on the low probability of a transient or DBA occurring simultaneously with the MCPR out of specification.
B.1 If the MCPR cannot be restored to within the required limits 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 < 25% RTP within 4 hours. The allowed Completion Time is reasonable, based on operating experience, to reduce THERMAL POWER to < 25% RTP in an orderly manner and without challenging plant systems.
SURVEILLANCE        SR 3.2.2.1 REQUIREMENTS The MCPR is required to be initially calculated within 12 hours after THERMAL POWER is t 25% RTP and then every 24 hoursperiodically 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 slowness of changes in power distribution during normal operation. The 12 hour allowance after THERMAL POWER reaches t 25% RTP is acceptable given the large inherent margin to operating limits at low power levels. The periodic Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.2.2.2 Because the transient analysis takes credit for conservatism in the scram speed performance, it must be demonstrated that the specific scram speed distribution is consistent with that used in the transient analysis.
SR 3.2.2.2 determines the value of W, which is a measure of the actual scram speed distribution compared with the assumed distribution. The MCPR operating limit is then determined based on an interpolation between the applicable limits for Option A (scram times of LCO 3.1.4, "Control Rod Scram Times") and Option B (realistic scram times) analysis. The parameter W must be determined once within 72 hours after each set of scram time tests required by SR 3.1.4.1, SR 3.1.4.2, and Columbia Generating Station            B 3.2.2-3                                    Revision 82
 
LHGR B 3.2.3 BASES LCO                The LHGR is a basic assumption in the fuel design analysis. The fuel has been designed to operate at rated core power with sufficient design margin to the LHGR calculated to cause a 1% fuel cladding plastic strain.
The operating limit to accomplish this objective is specified in the COLR.
APPLICABILITY      The LHGR limits are derived from fuel design analysis that is limiting at high power level conditions. At core thermal power levels < 25% RTP, the reactor is operating with a substantial margin to the LHGR limits and, therefore, the Specification is only required when the reactor is operating at t 25% RTP.
ACTIONS            A.1 If any LHGR exceeds its required limit, an assumption regarding an initial condition of the fuel design analysis is not met. Therefore, prompt action should be taken to restore the LHGR(s) to within its required limits such that the plant is operating within analyzed conditions. The 2 hour Completion Time is normally sufficient to restore the LHGR(s) to within its limits and is acceptable based on the low probability of a transient or Design Basis Accident occurring simultaneously with the LHGR out of specification.
B.1 If the LHGR cannot be restored to within its required limits 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 < 25% RTP within 4 hours. The allowed Completion Time is reasonable, based on operating experience, to reduce THERMAL POWER to < 25% 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 t 25% RTP and then every 24 hoursperiodically 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 power distribution under normal conditions. The 12 hour allowance after THERMAL POWER t 25% RTP is achieved is acceptable given the large inherent margin to operating limits at lower power levels. The periodic Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.2.3-2                                      Revision 73
 
APRM Gain and Setpoint B 3.2.4 BASES ACTIONS (continued)
B.1 If the APRM gain or Flow Biased Simulated Thermal Power - High Function Allowable Value cannot be restored to within their required limits 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 < 25% RTP within 4 hours. The allowed Completion Time is reasonable, based on operating experience, to reduce THERMAL POWER to < 25% RTP in an orderly manner and without challenging plant systems.
SURVEILLANCE        SR 3.2.4.1 and SR 3.2.4.2 REQUIREMENTS The MFLPD is required to be calculated and compared to FRTP or APRM gain or Flow Biased Simulated Thermal Power - High Function Allowable Value to ensure that the reactor is operating within the assumptions of the safety analysis. These SRs are required only to determine the MFLPD and, assuming MFLPD is greater than FRTP, the appropriate APRM gain or Flow Biased Simulated Thermal Power - High Function Allowable Value, and is not intended to be a CHANNEL FUNCTIONAL TEST for the APRM gain or APRM Flow Biased Simulated Thermal Power - High Function circuitry. The 24 hour Frequency of SR 3.2.4.1 is chosen to coincide with the determination of other thermal limits, specifically those for the APLHGR and LHGR (LCO 3.2.1 and LCO 3.2.3, respectively).
The 24 hour Frequency is based on both engineering judgment and recognition of the slowness of changes in power distribution during normal operation. The 12 hour allowance of SR 3.2.4.1 after THERMAL POWER t 25% RTP is achieved is acceptable given the large inherent margin to operating limits at low power levels.
The 12 hour Frequency of SR 3.2.4.2 is required when MFLPD is greater than FRTP, because more rapid changes in power distribution are typically expected. The periodic Surveillance Frequencies of SR 3.2.4.1 and SR 3.2.4.2 are controlled under the Surveillance Frequency Control Program.
REFERENCES        1. 10 CFR 50, Appendix A, GDC 10, GDC 13, GDC 20, and GDC 29.
: 2. FSAR, Chapter 15.
: 3. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.2.4-5                                    Revision 73
 
RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.1.1 Performance of a CHANNEL CHECK once every 12 hours ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a qualitative assessment, by observation, of channel behavior during operation. This determination includes, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter. 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 significant deviation could indicate 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 Surveillance Frequency is controlled under the Surveillance Frequency Control Program. 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 3.3.1.1.2 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. LCO 3.2.4, "Average Power Range Monitor (APRM) Gain and Setpoint," allows the APRMs to be reading greater than actual THERMAL POWER to compensate for localized power peaking. When this adjustment is made, the requirement for the APRMs to indicate within 2% RTP of calculated power is modified to require the APRMs to indicate within 2% RTP of calculated MFLPD. The Frequency of once per 7 days is based on minor changes in LPRM sensitivity, which could affect the APRM reading between performances of SR 3.3.1.1.7. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
A restriction to satisfying this SR when < 25% RTP is provided that requires the SR to be met only at t 25% RTP because it is difficult to Columbia Generating Station          B 3.3.1.1-21                                    Revision 82
 
RPS Instrumentation B 3.3.1.1 accurately maintain APRM indication of core THERMAL POWER consistent with a heat balance when < 25% 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 t 25% RTP, the Columbia Generating Station        B 3.3.1.1-22                                Revision 82
 
RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE REQUIREMENTS (continued)
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 25% if the 7 day Frequency is not met per SR 3.0.2. In this event, the SR must be performed within 12 hours after reaching or exceeding 25% 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 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 3.3.1.1.3 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 7 day Frequency is not met per SR 3.0.2. In this event, the SR must be performed within 12 hours after entering MODE 2 from MODE 1.
Twelve hours is based on operating experience and in consideration of providing a reasonable time in which to complete the SR.
A Frequency of 7 days provides an acceptable level of system average unavailability over the Frequency interval and is based on reliability analysis (Ref. 11). The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.1.1.4 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the 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 11. The Manual Scram Functions CHANNEL FUNCTIONAL TEST Frequency was credited in the analysis to extend many automatic scram Functions Frequencies. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.1.1.5 and SR 3.3.1.1.6 Columbia Generating Station          B 3.3.1.1-23                                  Revision 82
 
RPS Instrumentation B 3.3.1.1 These Surveillances are established to ensure that no gaps in neutron flux indication exist from subcritical to power operation for monitoring core reactivity status.
Columbia Generating Station          B 3.3.1.1-24                                  Revision 82
 
RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE REQUIREMENTS (continued)
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 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 mid-scale on range 1 before SRMs have reached the upscale rod block. The IRM/APRM and SRM/IRM overlaps are also acceptable if a 1/2 decade overlap exists.
As noted, SR 3.3.1.1.6 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 determined and the appropriate channel(s) declared inoperable. Only those appropriate channel(s) that are required in the current MODE or condition should be declared inoperable.
The Surveillance Frequency for SR 3.3.1.1.6 is controlled under the Surveillance Frequency Control Program. A Frequency of 7 days is reasonable based on engineering judgment and the reliability of the IRMs and APRMs.
SR 3.3.1.1.7 LPRM gain settings are determined from the local flux profiles measured by the Traversing Incore Probe (TIP) System. This establishes the relative local flux profile for appropriate representative input to the APRM System. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The 1130 MWD/T Frequency is based on operating experience with LPRM sensitivity changes.
Columbia Generating Station          B 3.3.1.1-25                                    Revision 73
 
RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.1.8 and SR 3.3.1.1.13 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the channel will perform the intended function. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.
For Function 2.b, the CHANNEL FUNCTIONAL TEST includes the adjustment of the APRM channel to conform to a calibrated flow signal.
This ensures that the total loop drive flow signals from the flow unit used to vary the setpoint are appropriately compared to an injection test flow signal to verify the flow signal trip setpoint and, therefore, the APRM Function accurately reflects the required setpoint as a function of flow. If the flow signal trip setpoint is not within the appropriate limit, the APRMs that receive an input from the inoperable flow unit must be declared inoperable.
The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program. The 92 day Frequency of SR 3.3.1.1.8 is based on the reliability analysis of Reference 11. The 24 month Frequency of SR 3.3.1.1.13 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. Operating experience has shown that these components usually pass the Surveillance when performed at the 24 month Frequency.
SR 3.3.1.1.9 and SR 3.3.1.1.10 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.
Note 1 states that neutron detectors 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 7 day calorimetric calibration (SR 3.3.1.1.2) and the 1130 MWD/T LPRM calibration against the TIPs (SR 3.3.1.1.7). 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 Columbia Generating Station          B 3.3.1.1-26                                      Revision 73
 
RPS Instrumentation B 3.3.1.1 without utilizing jumpers, lifted leads, or moveable links. This Note allows entry into MODE 2 from MODE 1 if the associated Frequency is not met Columbia Generating Station          B 3.3.1.1-27                                  Revision 73
 
RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE REQUIREMENTS (continued) 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 Surveillance Frequencies are controlled under the Surveillance Frequency Control Program. The Frequency of SR 3.3.1.1.9 is based upon the assumption of a 184 day calibration interval in the determination of the magnitude of equipment drift in the setpoint analysis. The Frequency of SR 3.3.1.1.10 is based on the assumption of an 18 month calibration interval for Functions 1 through 4, 6, 7, and 9 through 11 in the determination of the magnitude of equipment drift in the setpoint analysis.
A Frequency of 24 months is assumed for Functions 5 and 8 because the position switches that perform these Functions are not susceptible to instrument drift.
SR 3.3.1.1.11 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 THERMAL 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 must be verified to ensure that the channel is accurately reflecting the desired parameter.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency of 18 months is based on engineering judgment and reliability of the components.
SR 3.3.1.1.12 This SR ensures that scrams initiated from the Turbine Throttle Valve -
Closure and Turbine Governor Valve Fast Closure, Trip Oil Pressure -
Low Functions will not be inadvertently bypassed when THERMAL POWER is t 30% RTP. This involves calibration of the bypass channels.
Adequate margins for the instrument setpoint methodology are incorporated into the Allowable Value and 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 during an in-service calibration at THERMAL POWER t 30% RTP to ensure that the calibration is valid.
If any bypass channel setpoint is nonconservative (i.e., the Functions are bypassed at t 30% RTP, either due to open main turbine bypass valve(s)
Columbia Generating Station          B 3.3.1.1-28                                      Revision 73
 
RPS Instrumentation B 3.3.1.1 or other reasons), then the affected Turbine Throttle Valve - Closure and Turbine Governor Valve Fast Closure, Trip Oil Pressure - Low Functions Columbia Generating Station        B 3.3.1.1-29                                  Revision 73
 
RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE REQUIREMENTS (continued) 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.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency of 18 months is based on engineering judgment and reliability of the components.
SR 3.3.1.1.14 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the 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 Surveillance Frequency is controlled under the Surveillance Frequency Control Program. 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 was performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillance when performed at the 24 month Frequency.
SR 3.3.1.1.15 This SR ensures that the 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 12.
As noted (Note 1), neutron detectors for Function 2 are excluded from RPS RESPONSE TIME testing because the principles of detector operation virtually ensure an instantaneous response time. In addition, Note 2 states that channel sensors for Functions 3 and 4 are excluded and therefore, it is not required to quantitatively measure the sensor response time to satisfy the requirement to verify RPS RESPONSE TIME.
This is acceptable since the sensor response time can be qualitatively verified by other methods (Ref. 13). If the response time of the sensor is not quantitatively measured, the acceptance criteria must be reduced by the time assumed for sensor response in the design analyses, as verified by statistical analyses or vendor data.
Columbia Generating Station          B 3.3.1.1-30                                    Revision 73
 
RPS Instrumentation B 3.3.1.1 BASES SURVEILLANCE REQUIREMENTS (continued)
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. 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 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. The 24 month Frequency is consistent with the typical industry refueling cycle and is based upon plant operating experience, which shows that random failures of instrumentation components causing serious time degradation, but not channel failure, are infrequent.
REFERENCES        1. FSAR, Section 7.2.
: 2. FSAR, Section 5.2.2.
: 3. Columbia Generating Station Calculation NE-02-94-66, Revision 0, November 13, 1995.
: 4. FSAR, Section 6.3.3.
: 5. FSAR, Chapter 15.
: 6. 10 CFR 50.36(c)(2)(ii).
: 7. FSAR, Section 15.4.1.
: 8. NEDO-23842, "Continuous Control Rod Withdrawal in the Startup Range," April 18, 1978.
: 9. FSAR, Section 15.4.9.
: 10. Letter, P. Check (NRC) to G. Lainas (NRC), "BWR Scram Discharge System Safety Evaluation," December 1, 1980.
: 11. NEDC-30851-P-A, "Technical Specification Improvement Analyses for BWR Reactor Protection System," March 1988.
: 12. Licensee Controlled Specifications Manual.
: 13. NEDO 32291-A, "System Analyses for Elimination of Selected Response Time Testing Requirements," October 1995.
Columbia Generating Station          B 3.3.1.1-31                                  Revision 80
 
SRM Instrumentation B 3.3.1.2 BASES SURVEILLANCE        As noted at the beginning of the SRs, the SRs for each SRM Applicable REQUIREMENTS        MODE or other specified condition are found in the SRs column of Table 3.3.1.2-1.
SR 3.3.1.2.1 and SR 3.3.1.2.3 Performance of the CHANNEL CHECK ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a qualitative assessment, by observation, of channel behavior during operation. This determination includes, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter. 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 that the instrument has drifted outside its limit.
The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.The Frequency of once every 12 hours for SR 3.3.1.2.1 is based on operating experience that demonstrates channel failure is rare. While in MODES 3 and 4, reactivity changes are not expected; therefore, the 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 when the fueled region encompasses more than one SRM, 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, Columbia Generating Station          B 3.3.1.2-5                                    Revision 82
 
SRM Instrumentation B 3.3.1.2 OPERABLE. In the event that only one SRM is required to be OPERABLE (when the fueled region encompasses only one SRM), per Columbia Generating Station      B 3.3.1.2-6                                  Revision 82
 
SRM Instrumentation B 3.3.1.2 BASES SURVEILLANCE REQUIREMENTS (continued)
Table 3.3.1.2-1, footnote (b), only the a. portion of this SR is required.
Note 2 clarifies that more than one of the three requirements can be met by the same OPERABLE SRM. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The 12 hour Frequency is based upon operating experience and supplements operational controls over refueling activities, which include steps to ensure that the SRMs required by the LCO are in the proper quadrant.
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 with the detector full in. This ensures that the detectors are indicating count rates indicative of neutron flux levels within the core.
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 critical.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is based upon channel redundancy and other information available in the control room, and ensures that the required channels are frequently monitored while core reactivity changes are occurring. When no reactivity changes are in progress, the Frequency is relaxed from 12 hours to 24 hours.
SR 3.3.1.2.5 and SR 3.3.1.2.6 Performance of a CHANNEL FUNCTIONAL TEST demonstrates the associated channel will function properly. SR 3.3.1.2.5 is required in MODE 5, and the 7 day Frequency ensures that the channels are OPERABLE while core reactivity changes could be in progress. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. This 7 day Frequency is reasonable, based on operating experience and on other Surveillances (such as a CHANNEL Columbia Generating Station            B 3.3.1.2-7                                    Revision 73
 
SRM Instrumentation B 3.3.1.2 CHECK) that ensure proper functioning between CHANNEL FUNCTIONAL TESTS.
Columbia Generating Station      B 3.3.1.2-8                              Revision 73
 
SRM Instrumentation B 3.3.1.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.2.6 is required in MODE 2 with IRMs on Range 2 or below and in MODES 3 and 4. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. Since core reactivity changes do not normally take place in MODES 3 and 4 and core reactivity changes are due only to control rod movement in MODE 2, the Frequency has been extended from 7 days to 31 days. The 31 day Frequency is based on operating experience and on other Surveillances (such as CHANNEL CHECK) that ensure proper functioning between CHANNEL FUNCTIONAL TESTS.
The signal to noise ratio is determined to ensure adequate SRM response to reactivity changes while shutdown. This determination is performed by comparing an SRM countrate including neutrons to an SRM countrate not including neutrons. One method is to compare the SRM countrate with the detector in the core to the SRM countrate with the SRM withdrawn from the core. Another method electronically eliminates the SRM countrate signal due to neutrons. This signal and a normal SRM signal are then compared to determine the signal to noise ratio.
With few fuel assemblies loaded, the SRMs will not have a high enough count rate to determine the signal to noise ratio. Therefore, allowances are made for loading sufficient "source" material, in the form of irradiated fuel assemblies, to establish the conditions necessary to determine the signal to noise ratio. To accomplish this, SR 3.3.1.2.5 is modified by a Note that states that the determination of signal to noise ratio 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, even with a control rod withdrawn the configuration will not be critical.
The Note to the SR 3.3.1.2.6 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 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.
Columbia Generating Station            B 3.3.1.2-9                                    Revision 73
 
SRM Instrumentation B 3.3.1.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.2.7 Performance of a CHANNEL CALIBRATION verifies the performance of the SRM detectors and associated circuitry. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.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 neutron detectors are excluded from the CHANNEL CALIBRATION (Note 1) 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.
Note 2 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 18 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.
Columbia Generating Station          B 3.3.1.2-10                                  Revision 73
 
OPRM Instrumentation B 3.3.1.3 BASES SURVEILLANCE        SR 3.3.1.3.1 REQUIREMENTS A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. A Frequency of 184 days provides an acceptable level of system average availability over the Frequency and is based on the reliability of the channel (Reference 7). The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.1.3.2 LPRM gain settings are determined from the local flux profiles measured by the Traversing Incore Probe (TIP) System. This establishes the relative local flux profile for appropriate representative input to the OPRM System. The 1130 MWD/T Frequency is based on operating experience with LPRM sensitivity changes.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.1.3.3 The CHANNEL CALIBRATION is a complete check of the instrument loop. 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. Calibration of the channel provides a check of the internal reference voltage and the internal processor clock frequency. It also compares the desired trip setpoints with those in processor memory.
Since the OPRM is a digital system, the internal reference voltage and processor clock frequency are, in turn, used to automatically calibrate the internal analog to digital converters. The Allowable Values are specified in the (COLR). As noted, neutron detectors are excluded from CHANNEL CALIBRATION because they are passive devices, with minimal drift, and because of the difficulty of simulating a meaningful signal. Changes in neutron detector sensitivity are compensated for by performing the 1130 MWD/T LPRM calibration using the TIPs (SR 3.3.1.3.2).
The Frequency of 24 months is based upon the assumption of the magnitude of equipment drift provided by the equipment supplier (Reference 7).The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.3.1.3-5                                    Revision 73
 
OPRM Instrumentation B 3.3.1.3 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.3.4 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the 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 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 OPRM self-test function may be utilized to perform this testing for those components that it is designed to monitor.
The 24 month Frequency is based on engineering judgment and reliability of the components and Operating experience.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.1.3.5 This SR ensures that trips initiated from the OPRM System will not be inadvertently bypassed when THERMAL POWER is t 30% RTP and core flow is d 60% rated core flow. This normally involves calibration of the bypass channels. Adequate margins for the instrument setpoint methodology are incorporated into the actual setpoints (Reference 7).
If any bypass channel setpoint is nonconservative (i.e., the OPRM module is bypassed at t 30% RTP and core flow d 60% rated core flow),
then the affected OPRM module is considered inoperable. Alternatively, the bypass channel can be placed in the conservative condition (Manual Enable). If placed in the Manual Enable condition, this SR is met and the module is considered OPERABLE.
The Frequency of 24 months is based on engineering judgment and reliability of the components.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.1.3.6 This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the accident analysis (Reference 6). The OPRM self-test function may be utilized to perform this testing for those components it is designed to monitor. The LPRM amplifier cards inputting to the OPRM are excluded from the OPRM response time testing. The RPS RESPONSE TIME acceptance criteria are included in Reference 8.
Columbia Generating Station            B 3.3.1.3-6                                Revision 73
 
OPRM Instrumentation B 3.3.1.3 BASES SURVEILLANCE REQUIREMENTS (continued)
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. This Frequency is based upon operating experience, which shows that random failures of instrumentation components causing serious time degradation, but not channel failure, are infrequent.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES        1. NEDO-31960-A, "BWR Owners Group Long-Term Stability Solutions Licensing Methodology," November 1995 (Sus) June 1991.
: 2. NEDO 31960-A, Supplement 1 "BWR Owners Group Long-Term Stability Solutions Licensing Methodology," November 1995 (Sus)
March 1992.
: 3. NRC Letter, A. Thadani to L.A. England, "Acceptance for Referencing of Topical Reports NEDO-31960, Supplement 1, 'BWR Owners Group Long-Term Stability Solutions Licensing Methodology,'"
July 12, 1994.
: 4. Generic Letter 94-02, "Long-Term Solutions and Upgrade of Interim Operating Recommendations for Thermal-Hydraulic Instabilities in Boiling Water Reactors," July 11, 1994.
: 5. BWROG Letter BWROG-94079, "Guidelines for Stability Interim Corrective Action," June 6, 1994.
: 6. NEDO-32465-A, "BWR Owners Group Reactor Stability Detect and Suppress Solution Licensing Basis Methodology and Reload Application," August 1996 & May 1995.
: 7. CENPD-400-P, Rev 01, "Generic Topical Report for the ABB Option III Oscillation Power Range Monitor (OPRM)," May 1995.
: 8. Licensee Controlled Specification Table 1.3.1.1-1.
Columbia Generating Station          B 3.3.1.3-7                                    Revision 73
 
Control Rod Block Instrumentation B 3.3.2.1 BASES SURVEILLANCE        As noted at the beginning of the SRs, the SRs for each Control Rod Block REQUIREMENTS        instrumentation Function are found in the SRs column of Table 3.3.2.1-1.
The Surveillances are modified by a second Note to indicate that when an RBM 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. 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. 7) 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 a control rod block will be initiated when necessary.
SR 3.3.2.1.1 A CHANNEL FUNCTIONAL TEST is performed for each RBM channel to ensure that the channel will perform the intended function. It includes the Reactor Manual Control Multiplexing System input.
Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology. The Frequency of 92 days is based on reliability analyses (Ref. 8). The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.2.1.2 and SR 3.3.2.1.3 A CHANNEL FUNCTIONAL TEST is performed for the RWM to ensure that the entire system will perform the intended function. The CHANNEL FUNCTIONAL TEST for the RWM is performed by attempting to withdraw a control rod not in compliance with the prescribed sequence and verifying a control rod block occurs and, for SR 3.3.2.1.2 only, by attempting to select a control rod not in compliance with the prescribed sequence and verifying a selection error occurs. As noted in the SRs, SR 3.3.2.1.2 is not required to be performed until 1 hour after any control rod is withdrawn at d 10% RTP in MODE 2, and SR 3.3.2.1.3 is not required to be performed until 1 hour after THERMAL POWER is d 10% RTP in MODE 1. This allows entry into MODE 2 (and if entering during a shutdown, concurrent power reduction to d 10% RTP) for SR 3.3.2.1.2, and THERMAL POWER reduction to d 10% RTP in MODE 1 for SR 3.3.2.1.3, to perform the required Surveillances if the 92 day Frequency is not met per SR 3.0.2. The 1 hour allowance is based on operating experience and in consideration of providing a reasonable time in which to complete the SRs. The 92 day Frequencies Columbia Generating Station            B 3.3.2.1-7                                  Revision 73
 
Control Rod Block Instrumentation B 3.3.2.1 are based on reliability analysis (Ref. 8).The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
Columbia Generating Station          B 3.3.2.1-8                                    Revision 73
 
Control Rod Block Instrumentation B 3.3.2.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.2.1.4 The RBM is automatically bypassed when power is below a specified value or if a peripheral control rod is selected. The power level is determined from the APRM signals input to each RBM channel. The automatic bypass setpoint must be verified periodically to be < 30% RTP.
In addition, it must also be verified that the RBM is not bypassed when a control rod that is not a peripheral control rod is selected (only one non-peripheral control rod is required to be verified). If any bypass setpoint is nonconservative, then the affected RBM channel is considered inoperable. Alternatively, the APRM channel can be placed in the conservative condition (non-bypass). If placed in this condition, the SR is met and the RBM channel is not considered inoperable. As noted, neutron detectors are excluded from the Surveillance because they are passive devices, with minimal drift, and because of the difficulty of simulating a meaningful signal. Neutron detectors are adequately tested in SR 3.3.1.1.2 and SR 3.3.1.1.7. The 92 day Frequency is based on the actual trip setpoint methodology utilized for these channels.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.2.1.5 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.
As noted, neutron detectors are excluded from the CHANNEL CALIBRATION because they are passive devices, with minimal drift, and because of the difficulty of simulating a meaningful signal. Neutron detectors are adequately tested in SR 3.3.1.1.2 and SR 3.3.1.1.7.
The Frequency is based upon the assumption of a 92 day calibration interval in the determination of the magnitude of equipment drift in the setpoint analysis.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station          B 3.3.2.1-9                                    Revision 73
 
Control Rod Block Instrumentation B 3.3.2.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.2.1.6 The RWM is automatically bypassed when power is above a specified value. The power level is determined from a steam flow signal. The automatic bypass setpoint must be verified periodically to be > 10% RTP.
If the RWM low power setpoint is nonconservative, then the RWM is considered inoperable. Alternately, the low power setpoint channel can be placed in the conservative condition (nonbypass). If placed in the nonbypassed condition, the SR is met and the RWM is not considered inoperable. The Frequency is based on instrument drift analysis and the trip setpoint methodology utilized for the low power setpoint channel.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.2.1.7 A CHANNEL FUNCTIONAL TEST is performed for the Reactor Mode Switch - Shutdown Position Function to ensure that the entire channel will perform the intended function. 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 links.
This allows entry into MODES 3 and 4 if the 24 month Frequency is not met per SR 3.0.2. The 1 hour allowance is based on operating experience and in consideration of providing a reasonable time in which to complete the SRs.
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. Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.3.2.1-10                                  Revision 73
 
Control Rod Block Instrumentation B 3.3.2.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.2.1.8 The RWM will only enforce the proper control rod sequence if the rod sequence is properly input into the RWM computer. This SR ensures that the proper sequence is loaded into the RWM so that it can perform its intended function. The Surveillance is performed once prior to declaring RWM OPERABLE following loading of sequence into RWM, since this is when rod sequence input errors are possible.
REFERENCES        1. FSAR, Section 7.7.1.8.
: 2. FSAR, Section 7.7.1.10.
: 3. FSAR, Sections 15.4.1 and 15.4.2.
: 4. 10 CFR 50.36(c)(2)(ii).
: 5. FSAR, Section 15.4.9.
: 6. NRC SER, "Acceptance of Referencing of Licensing Topical Report NEDE-24011-P-A," "General Electric Standard Application for Reactor Fuel, Revision 8, Amendment 17," December 27, 1987.
: 7. GENE-770-06-1-A, "Addendum to Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications," December 1992.
: 8. NEDC-30851-P-A, "Technical Specification Improvement Analysis for BWR Control Rod Block Instrumentation," October 1988.
Columbia Generating Station          B 3.3.2.1-11                                Revision 73
 
Feedwater and Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 BASES ACTIONS (continued)
The 2 hour Completion Time is sufficient for the operator to take corrective action, and takes into account the likelihood of an event requiring actuation of feedwater and main turbine high water level trip instrumentation occurring during this period. It is also consistent with the 2 hour Completion Time provided in LCO 3.2.2 for Required Action A.1, since this instrumentation's purpose is to preclude a MCPR violation.
C.1 With the required channels not restored to OPERABLE status or placed in trip, THERMAL POWER must be reduced to < 25% RTP within 4 hours.
As discussed in the Applicability section of the Bases, operation below 25% RTP results in sufficient margin to the required limits, and the feedwater and main turbine high water level trip instrumentation is not required to protect fuel integrity during the feedwater controller failure, maximum demand event. The allowed Completion Time of 4 hours is based on operating experience to reduce THERMAL POWER to
                    < 25% RTP 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 feedwater and main turbine high water level 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. 3) assumption that 6 hours is 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 feedwater pump turbines and main turbine will trip when necessary.
SR 3.3.2.2.1 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 qualitative assessment, by observation, of channel behavior during operation. This determination includes, where possible, comparison of the channel indication and status to other indications or status derived from independent channels measuring the same parameter. It is based on the assumption that instrument channels Columbia Generating Station            B 3.3.2.2-4                                    Revision 82
 
Feedwater and Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 BASES SURVEILLANCE REQUIREMENTS (continued) 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 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 limits.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is based on 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 the channels required by the LCO.
SR 3.3.2.2.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the 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 controlled under the Surveillance Frequency Control Program. The Frequency of 92 days is based on reliability analysis (Ref. 3).
SR 3.3.2.2.3 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 Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is based upon the assumption of a 24 month calibration interval in the determination of the magnitude of equipment drift in the setpoint analysis.
Columbia Generating Station            B 3.3.2.2-5                                    Revision 82
 
Feedwater and Main Turbine High Water Level Trip Instrumentation B 3.3.2.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.2.2.4 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required trip logic for a specific channel. The system functional test of the feedwater stop valves and main turbine throttle valves is included as part of this Surveillance and overlaps the LOGIC SYSTEM FUNCTIONAL TEST to provide complete testing of the assumed safety function. Therefore, if a valve is incapable of operating, the associated instrumentation would also be inoperable. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. 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. Operating experience has shown that these components usually pass the Surveillance when performed at the 24 month Frequency.
REFERENCES        1. FSAR, Section 15.1.2.
: 2. 10 CFR 50.36(c)(2)(ii).
: 3. GENE-770-06-1-A, "Bases for Changes to Surveillance Test Intervals and Allowed Out-Of-Service Times for Selected Instrumentation Technical Specifications," December 1992.
Columbia Generating Station            B 3.3.2.2-6                                  Revision 73
 
PAM Instrumentation B 3.3.3.1 BASES ACTIONS (continued)
F.1 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 follow the directions of Specification 5.6.4. These alternate means may be temporarily installed if the normal PAM channel cannot be 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.
SURVEILLANCE        As noted at the beginning of the SRs, the following SRs apply to each REQUIREMENTS        PAM instrumentation Function in Table 3.3.3.1-1.
The Surveillances are modified by a second 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 other required channel(s) in the associated Function are OPERABLE. 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. The 6 hour testing allowance is acceptable since it does not significantly reduce the probability of properly monitoring post-accident parameters, when necessary.
SR 3.3.3.1.1 Performance of a CHANNEL CHECK once every 12 hours ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a qualitative assessment, by observation, of channel behavior during operation. This determination includes, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter. Significant deviations between instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A significant deviation could indicate 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.
Columbia Generating Station            B 3.3.3.1-8                                    Revision 82
 
PAM Instrumentation B 3.3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
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 sensor or the signal processing equipment has drifted outside its limit.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.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 channels required by the LCO.
SR 3.3.3.1.3 and SR 3.3.3.1.4 A CHANNEL CALIBRATION is performed every 18 months for Functions 1, 2, 4, 5, and 10, and every 24 months for Functions 3, 6, and 7. 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. For Function 6, the CHANNEL CALIBRATION shall consist of an electronic calibration of the channel, excluding the detector, for range decades t 10 R/hour and a one point calibration check of the detector with an installed or portable gamma source for range decades < 10 R/hour. The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program. The 92 day, 18 month, and 24 month Frequencies are based on operating experience and engineering judgment.
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, "Washington Public Power Supply System, Nuclear Project No. 2, Conformance to Regulatory Guide 1.97," dated March 23, 1988.
: 3. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station          B 3.3.3.1-9                                    Revision 73
 
Remote Shutdown System B 3.3.3.2 BASES SURVEILLANCE        The Surveillances are modified by a Note to indicate that when an REQUIREMENTS        instrument 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. 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. The 6 hour testing allowance is acceptable since it does not significantly reduce the probability of properly operating the associated equipment, when necessary.
SR 3.3.3.2.1 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 qualitative assessment, by observation, of channel behavior during operation. This determination includes, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter. 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 that the sensor or the signal processing equipment has drifted outside its limit. As specified in the Surveillance, a CHANNEL CHECK is only required for those channels that are normally energized.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is based upon plant operating experience that demonstrates channel failure is rare.
SR 3.3.3.2.2 and SR 3.3.3.2.3 CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. The test verifies the channel responds to measured parameter values with the necessary range and accuracy.
The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program. The 18 month Frequency of SR 3.3.3.2.2 is Columbia Generating Station          B 3.3.3.2-4                                      Revision 82
 
Remote Shutdown System B 3.3.3.2 based upon operating experience and is consistent with the typical industry refueling cycle.
Columbia Generating Station          B 3.3.3.2-5                                Revision 82
 
Remote Shutdown System B 3.3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)
The 24 month Frequency of SR 3.3.3.2.3 is based upon operating experience and engineering judgment.
SR 3.3.3.2.4 SR 3.3.3.2.4 verifies each required Remote Shutdown System transfer switch and control circuit performs the intended function. This verification is performed from the remote and alternate shutdown panels, as appropriate. Operation of the equipment from the remote shutdown panel or alternate 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 or alternate shutdown panels. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. 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. Operating experience demonstrates that Remote Shutdown System controls usually pass the Surveillance when performed at the 24 month Frequency.
REFERENCES        1. 10 CFR 50, Appendix A, GDC 19.
: 2. 10 CFR 50.36(c)(2)(ii).
: 3. Licensee Controlled Specifications Manual.
Columbia Generating Station            B 3.3.3.2-6                                  Revision 82
 
EOC-RPT Instrumentation B 3.3.4.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.4.1.1 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the 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 reliability analysis (Ref. 5).The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.4.1.2.a and SR 3.3.4.1.2.b 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 for SR 3.3.4.1.2.b is based upon the assumption of an 18 month calibration interval, in the determination of the magnitude of equipment drift in the setpoint analysis.
A Frequency of 24 months is assumed for SR 3.3.4.1.2.a because the TTV position switches are not susceptible to instrument drift.The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
SR 3.3.4.1.3 This SR ensures that an EOC-RPT initiated from the TTV - Closure and TGV Fast Closure, Trip Oil Pressure - Low Functions will not be inadvertently bypassed when THERMAL POWER is t 30% RTP. This involves calibration of the bypass channels. Adequate margins for the instrument setpoint methodologies are incorporated into the actual setpoint. Because main turbine bypass flow can affect this setpoint nonconservatively (THERMAL POWER is derived from first stage pressure), the main turbine bypass valves must remain closed during an in-service calibration at THERMAL POWER t 30% RTP to ensure that the calibration is valid. If any bypass channel's setpoint is nonconservative (i.e., the Functions are bypassed at t 30% RTP either due to open main turbine bypass valves or other reasons), the affected TTV - Closure and TGV Fast Closure, Trip Oil Pressure - Low Functions Columbia Generating Station            B 3.3.4.1-7                                Revision 73
 
EOC-RPT Instrumentation B 3.3.4.1 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.
Columbia Generating Station          B 3.3.4.1-8                                  Revision 73
 
EOC-RPT Instrumentation B 3.3.4.1 BASES SURVEILLANCE REQUIREMENTS (continued)
The Frequency of 18 months is based on engineering judgement and reliability of the components.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.4.1.4 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 with the reactor at power. Operating experience has shown these components usually pass the Surveillance test when performed at the 24 month Frequency.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.4.1.5 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 arc suppression time may be assumed from the most recent performance of SR 3.3.4.1.6. This is allowed since the arc suppression time is short and does not appreciably change, due to the design of the breaker opening device and the fact that the breaker is not routinely cycled.
EOC-RPT SYSTEM RESPONSE TIME tests are conducted on a 24 month STAGGERED TEST BASIS. Response times cannot be determined at power because operation of final actuated devices is required. Therefore, the 24 month Frequency is consistent with the refueling cycle and is based upon plant operating experience, which shows that random failures of instrumentation components that cause serious response time degradation, but not channel failure, are infrequent occurrences.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.3.4.1-9                                Revision 73
 
EOC-RPT Instrumentation B 3.3.4.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.4.1.6 This SR ensures that the RPT breaker arc suppression time is provided to the EOC-RPT SYSTEM RESPONSE TIME test. The 60 month Frequency of the testing is based on the difficulty of performing the test and the reliability of the circuit breakers.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES        1. FSAR, Section 7.6.1.5.
: 2. FSAR, Section 5.2.2.
: 3. FSAR, Sections 15.2.2, 15.2.3, 15.2.5, and 15.2.6.
: 4. 10 CFR 50.36(c)(2)(ii).
: 5. GENE-770-06-1-A, "Bases for Changes To Surveillance Test Intervals And Allowed Out-Of-Service Times For Selected Instrumentation Technical Specifications," December 1992.
: 6. Licensee Controlled Specifications Manual.
Columbia Generating Station          B 3.3.4.1-10                                  Revision 73
 
ATWS-RPT Instrumentation B 3.3.4.2 BASES ACTIONS (continued)
D.1 and D.2 With any Required Action and associated Completion Time not met, the plant must be brought to a MODE or other specified condition in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 2 within 6 hours (Required Action D.2). Alternately, the associated recirculation pump may be removed from service since this 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 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 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. 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 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 qualitative assessment, by observation, of channel behavior during operation. This determination includes, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter. 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.
Columbia Generating Station            B 3.3.4.2-6                                    Revision 82
 
ATWS-RPT Instrumentation B 3.3.4.2 BASES SURVEILLANCE REQUIREMENTS (continued)
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 controlled under the Surveillance Frequency Control Program. 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 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 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 controlled under the Surveillance Frequency Control Program. The Frequency of 92 days is based on the reliability analysis of Reference 3.
SR 3.3.4.2.3 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 Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is based upon the assumption of an 18 month calibration interval in the determination of the magnitude of equipment drift in the setpoint analysis.
SR 3.3.4.2.4 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, included as part of this Surveillance, overlaps the LOGIC SYSTEM FUNCTIONAL TEST to Columbia Generating Station            B 3.3.4.2-7                                    Revision 73
 
ATWS-RPT Instrumentation B 3.3.4.2 provide complete testing of the assumed safety function. Therefore, if a breaker is incapable of operating, the associated instrument channel(s) would be inoperable.
Columbia Generating Station          B 3.3.4.2-8                                  Revision 73
 
ATWS-RPT Instrumentation B 3.3.4.2 BASES SURVEILLANCE REQUIREMENTS (continued)
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. 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. Operating experience has shown that these components usually pass the Surveillance when performed at the 24 month Frequency.
REFERENCES        1. FSAR, Section 15.8.
: 2. 10CFR 50.36(c)(2)(ii).
: 3. GENE-770-06-1-A, "Bases For Changes To Surveillance Test Intervals and Allowed Out-of-Service Times For Selected Instrumentation Technical Specifications," December 1992.
Columbia Generating Station          B 3.3.4.2-9                                    Revision 73
 
ECCS Instrumentation B 3.3.5.1 BASES ACTIONS (continued)
H.1 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, and 3.g; and (b) for Functions other than 3.c, 3.f, and 3.g provided the associated Function or 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. 5) 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 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 qualitative assessment, by observation, of channel behavior during operation. This determination includes, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter. 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 that the instrument has drifted outside its limit.
Columbia Generating Station          B 3.3.5.1-31                                    Revision 82
 
ECCS Instrumentation B 3.3.5.1 BASES SURVEILLANCE REQUIREMENTS (continued)
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.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 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 controlled under the Surveillance Frequency Control Program. The Frequency of 92 days is based on the reliability analyses of Reference 5.
SR 3.3.5.1.3, SR 3.3.5.1.4, and SR 3.3.5.1.5 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. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.
The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program. The Frequencies are based upon the assumption of a 92 day, 18 month, or 24 month calibration interval, as applicable, in the determination 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 Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The 24 month Frequency is based on the Columbia Generating Station          B 3.3.5.1-32                                Revision 73
 
ECCS Instrumentation B 3.3.5.1 need to perform this Surveillance under the conditions that apply during a plant outage (except for Division 3 which can be tested in any operational condition) and the potential for unplanned transients if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency.
Columbia Generating Station        B 3.3.5.1-33                                    Revision 73
 
RCIC System Instrumentation B 3.3.5.2 BASES ACTIONS (continued)
E.1 With any Required Action and associated Completion Time not met, the RCIC System may be incapable of performing the intended function, and the RCIC System must be declared inoperable immediately.
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 4; and (b) for up to 6 hours for Functions 1 and 3 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 (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 RCIC will initiate when necessary.
SR 3.3.5.2.1 Performance of a CHANNEL CHECK once every 12 hours ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a qualitative assessment, by observation, of channel behavior during operation. This determination includes, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter. 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 significant deviation could indicate 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.
Columbia Generating Station            B 3.3.5.2-8                                      Revision 82
 
RCIC System Instrumentation B 3.3.5.2 BASES SURVEILLANCE REQUIREMENTS (continued)
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. 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 3.3.5.2.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the 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 controlled under the Surveillance Frequency Control Program. The Frequency of 92 days is based on the reliability analysis of Reference 2.
SR 3.3.5.2.3 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.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is based on the assumption of an 18 month calibration interval in the determination of the magnitude of equipment drift in the setpoint analysis.
SR 3.3.5.2.4 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 Surveillance Frequency is controlled under the Surveillance Frequency Control Program. 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. Operating Columbia Generating Station            B 3.3.5.2-9                                  Revision 73
 
RCIC System Instrumentation B 3.3.5.2 experience has shown that these components usually pass the Surveillance when performed at the 24 month Frequency.
Columbia Generating Station        B 3.3.5.2-10                              Revision 73
 
Primary Containment Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE REQUIREMENTS (continued)
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 qualitative assessment, by observation, of channel behavior during operation. This determination includes, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter. 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 that the instrument has drifted outside its limit.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is based on 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 3.3.6.1.2 and SR 3.3.6.1.3 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the channel will perform the intended function. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.
The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program. The 92 day Frequency of SR 3.3.6.1.2 is based on reliability analysis described in References 10 and 11. The 184 day Frequency of SR 3.3.6.1.3 is based on engineering judgment and the reliability of the components.
SR 3.3.6.1.4 and SR 3.3.6.1.5 Columbia Generating Station          B 3.3.6.1-32                                    Revision 82
 
Primary Containment Isolation Instrumentation B 3.3.6.1 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 Columbia Generating Station        B 3.3.6.1-33                                    Revision 82
 
Primary Containment Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE REQUIREMENTS (continued) drifts between successive calibrations, consistent with the plant specific setpoint methodology. The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program. The Frequencies are based on the assumption of an 18 month or 24 month calibration interval, as applicable, in the determination of the magnitude of equipment drift in the setpoint analysis.
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 overlaps this Surveillance to provide complete testing of the assumed safety function. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. 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.
Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency.
SR 3.3.6.1.7 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 15 second start time when compared to the typical channel response time (milliseconds) so as to assure adequate response time without a specific measurement test (Ref. 12). A note to the surveillance states that channel sensors for Functions 1.a, 1.b, and 1.c are excluded and therefore, it is not required to quantitatively measure the sensor response time to satisfy the requirement to verify ISOLATION INSTRUMENTATION RESPONSE TIME. This is acceptable since the sensor response time can be qualitatively verified by other methods (Ref. 12). If the response time of the sensor is not quantitatively measured, the acceptance criteria must be reduced by the time assumed for sensor response in the design analyses, as verified by statistical analysis or vendor data. The instrument response times must be added to the PCIV closure times to obtain the ISOLATION SYSTEM RESPONSE TIME. However, failure to meet an ISOLATION SYSTEM Columbia Generating Station          B 3.3.6.1-34                                  Revision 82
 
Primary Containment Isolation Instrumentation B 3.3.6.1 RESPONSE TIME due to a PCIV closure time not within limits does not require the associated instrumentation to be declared inoperable; only the PCIV is required to be declared inoperable.
Columbia Generating Station        B 3.3.6.1-35                                  Revision 82
 
Primary Containment Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE REQUIREMENTS (continued)
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. ISOLATION SYSTEM RESPONSE TIME tests are conducted on a 24 month STAGGERED TEST BASIS. The 24 month test Frequency is consistent with the typical industry refueling cycle and is based upon plant operating experience that shows that random failures of instrumentation components causing serious response time degradation, but not channel failure, are infrequent.
REFERENCES        1. FSAR, Section 6.2.1.1.
: 2. FSAR, Chapter 15.
: 3. 10 CFR 50.36(c)(2)(ii).
: 4. FSAR, Section 15.1.3.
: 5. FSAR, Section 15.6.4.
: 6. FSAR, Section 15.2.5.
: 7. FSAR, Section 11.3.2.
: 8. FSAR, Section 9.3.5.2.
: 9. 10 CFR 50.62.
: 10. NEDC-31677-P-A, "Technical Specification Improvement Analysis for BWR Isolation Actuation Instrumentation," June 1989.
: 11. NEDC-30851-P-A, Supplement 2, "Technical Specifications Improvement Analysis for BWR Isolation Instrumentation Common to RPS and ECCS Instrumentation," March 1989.
: 12. NEDO-32291-A, "System Analyses for the Elimination of Selected Response Time Testing Requirements," October 1995.
Columbia Generating Station        B 3.3.6.1-36                                  Revision 73
 
Secondary Containment Isolation Instrumentation B 3.3.6.2 BASES ACTIONS (continued)
Alternatively, declaring the associated SCIVs or SGT subsystem inoperable (Required Actions C.1.2 and C.2.2) is also acceptable since the Required Actions of the respective LCOs (LCO 3.6.4.2 and LCO 3.6.4.3) provide appropriate actions for the inoperable components.
One hour is sufficient for plant operations personnel to establish required plant conditions or to declare the associated components inoperable without challenging plant systems.
SURVEILLANCE        As noted at the beginning of the SRs, the SRs for each Secondary REQUIREMENTS        Containment Isolation instrumentation Function are located in the SRs column of Table 3.3.6.2-1.
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 isolation 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 Action(s) taken.
This Note is based on the reliability analysis (Refs. 3 and 4) 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 SCIVs will isolate the associated penetration flow paths and the SGT System 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 qualitative assessment, by observation, of channel behavior during operation. This determination includes, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter. 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.
Columbia Generating Station          B 3.3.6.2-8                                      Revision 82
 
Secondary Containment Isolation Instrumentation B 3.3.6.2 BASES SURVEILLANCE REQUIREMENTS (continued)
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 controlled under the Surveillance Frequency Control Program. The Frequency is based on 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 3.3.6.2.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the 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 controlled under the Surveillance Frequency Control Program. The Frequency of 92 days is based upon the reliability analysis of References 4 and 5.
SR 3.3.6.2.3 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 Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is based upon the assumption of an 18 month calibration interval in the determination of the magnitude of equipment drift in the setpoint analysis.
SR 3.3.6.2.4 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required isolation logic for a specific channel. The system functional testing, performed on SCIVs and the SGT System in Columbia Generating Station            B 3.3.6.2-9                                    Revision 73
 
Secondary Containment Isolation Instrumentation B 3.3.6.2 LCO 3.6.4.2 and LCO 3.6.4.3, respectively, overlaps this Surveillance to provide complete testing of the assumed safety function.
Columbia Generating Station        B 3.3.6.2-10                                  Revision 73
 
Secondary Containment Isolation Instrumentation B 3.3.6.2 BASES SURVEILLANCE REQUIREMENTS (continued)
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. 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. Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency.
REFERENCES        1. FSAR, Section 15.6.5.
: 2. 10 CFR 50.36(c)(2)(ii).
: 3. NEDO-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 Instrumentation Common to RPS and ECCS Instrumentation," March 1989.
Columbia Generating Station        B 3.3.6.2-11                                    Revision 73
 
CREF System Instrumentation B 3.3.7.1 BASES SURVEILLANCE        As noted at the beginning of the SRs, the SRs for each CREF System REQUIREMENTS        instrumentation Function are located in the SRs column of Table 3.3.7.1-1.
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 CREF System 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 (Refs. 5, 6, and 7) 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 CREF 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 qualitative assessment, by observation, of channel behavior during operation. This determination includes, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter. 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 that the instrument has drifted outside its limit.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. 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 channels required by the LCO.
Columbia Generating Station          B 3.3.7.1-7                                      Revision 82
 
CREF System Instrumentation B 3.3.7.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.7.1.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the 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 controlled under the Surveillance Frequency Control Program. The Frequency of 92 days is based on the reliability analyses of References 5, 6, and 7.
SR 3.3.7.1.3 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. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations, consistent with the plant specific setpoint methodology.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. The Frequency is based on the assumption of an 18 month calibration interval in the determination of the magnitude of equipment drift in the setpoint analysis.
SR 3.3.7.1.4 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 Emergency Filtration (CREF) System," overlaps this Surveillance to provide complete testing of the assumed safety function.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. 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. Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency.
Columbia Generating Station            B 3.3.7.1-8                                  Revision 73
 
LOP Instrumentation B 3.3.8.1 BASES SURVEILLANCE        As noted at the beginning of the SRs, the SRs for each LOP REQUIREMENTS        Instrumentation Function are located in the SRs column of Table 3.3.8.1-1.
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 2 hours provided the associated Function maintains initiation capability. Initiation capability is maintained provided the following can be initiated by the Function (i.e., Loss of Voltage and Degraded Voltage) for two of the three DGs and 4.16 kV ESF buses: DG start, disconnect from the offsite power source, transfer to the alternate offsite power source, if available, DG output breaker closure, and load shed. Upon completion of the Surveillance, or expiration of the 2 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken.
SR 3.3.8.1.1 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the channel will perform the intended function. Any setpoint adjustments shall be consistent with the assumptions of the current plant specific setpoint methodology.
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.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.8.1.2 and 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. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations, consistent with the plant specific setpoint methodology.
The Frequencies are based on the assumption of an 18 month or 24 month calibration interval, as applicable, in the determination of the magnitude of equipment drift in the setpoint analysis.The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.3.8.1-8                                    Revision 73
 
LOP Instrumentation B 3.3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
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 power. Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES        1. FSAR, Section 8.3.1.1.1.
: 2. FSAR, Section 5.2.
: 3. FSAR, Section 6.3.
: 4. FSAR, Chapter 15.
: 5. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station          B 3.3.8.1-9                                  Revision 73
 
RPS Electric Power Monitoring B 3.3.8.2 BASES SURVEILLANCE REQUIREMENTS (continued)                continuation of SR 3.3.8.2.1 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 operation (the design of the system is such that the power source must be removed from service to conduct the Surveillance). In addition, if the plant will be shutdown in MODE 4 or 5 for an extended period of time it is acceptable to postpone the Surveillance until the plant is ready to go back to MODE 2 or 3. Performance of the SR immediately after shutdown would jeopardize the reliability of shutdown cooling during a time of high decay heat load. However, prior to restart it is reasonable to perform the surveillance to provide further assurance of the operability of equipment before returning to MODE 1. The 24 hours is intended to indicate an outage of sufficient duration to allow for scheduling and proper performance of the Surveillance if it has not been performed in the last 184 days. The 184 day Frequency and the Note in the Surveillance areis based on guidance provided in Generic Letter 91-09 (Ref. 3).
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.8.2.2 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 is based upon the assumption of a 24 month calibration interval in the determination of the magnitude of equipment drift in the setpoint analysis.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.3.8.2.3 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 Columbia Generating Station            B 3.3.8.2-6                                    Revision 73
 
RPS Electric Power Monitoring B 3.3.8.2 incapable of operating, the associated electric power monitoring assembly would be inoperable.
Columbia Generating Station        B 3.3.8.2-7                                    Revision 73
 
RPS Electric Power Monitoring B 3.3.8.2 BASES SURVEILLANCE REQUIREMENTS (continued)
The 24 month Frequency is based on instrument drift analysis, 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.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES        1. FSAR, Section 8.3.1.1.6.
: 2. 10 CFR 50.36(c)(2)(ii).
: 3. NRC Generic Letter 91-09, "Modification of Surveillance Interval for the Electric Protective Assemblies in Power Supplies for the Reactor Protection System."
Columbia Generating Station          B 3.3.8.2-8                                  Revision 73
 
Recirculation Loops Operating B 3.4.1 BASES SURVEILLANCE REQUIREMENTS (continued)            continuation of SR 3.4.1.1 The mismatch is measured in terms of percent of rated recirculation loop drive flow. If the flow mismatch exceeds the specified limits, the loop with the lower flow is considered not in operation. This SR is not required when both loops are not in operation since the mismatch limits are meaningless during single loop or natural circulation operation. The Surveillance must be performed within 24 hours after both loops are in operation. The 24 hour Frequency is consistent with the Frequency for jet pump OPERABILITY verification and has been shown by operating experience to be adequate to detect off normal jet pump loop flows in a timely manner.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Sections 6.3 and 15.6.
: 2. FSAR, Section 6.3.3.7.2.
: 3. FSAR, Section 5.4.1.
: 4. FSAR, Section 6.A.
: 5. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.4.1-5                                    Revision 73
 
Jet Pumps B 3.4.2 BASES SURVEILLANCE REQUIREMENTS (continued)                continuation of SR 3.4.2.1 loop flow, these relationships may need to be re-established each cycle.
Similarly, initial entry into extended single loop operation may also require establishment of these relationships. During the initial weeks of operation under such conditions, while base-lining new "established patterns,"
engineering judgement of the daily Surveillance results is used to detect significant abnormalities which could indicate a jet pump failure.
The recirculation pump speed operating characteristics (loop flow versus pump speed) are determined by the flow resistance from the loop suction through the jet pump nozzles. A change in the relationship may indicate a flow restriction, loss in pump hydraulic performance, leak, or new flow path between the recirculation pump discharge and jet pump nozzle. For this criterion, the loop flow versus pump speed relationship must be verified.
Total core flow can be determined from measurements of the recirculation loop drive flows. Once this relationship has been established, increased or reduced total core flow for the same recirculation loop drive flow may be an indication of failures in one or several jet pumps.
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.
The deviations from normal are considered indicative of a potential problem in the recirculation drive flow or jet pump system (Ref. 3).
Normal flow ranges and established jet pump flow and differential pressure patterns are established by plotting historical data as discussed in Reference 3.
The 24 hour Frequency has been shown by operating experience to be adequate to verify jet pump OPERABILITY and is consistent with the Frequency for recirculation loop OPERABILITY verification.The Surveillance Frequency is controlled under the Surveillance Frequency Control 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.
Columbia Generating Station              B 3.4.2-3                                    Revision 73
 
SRVs - t 25% RTP B 3.4.3 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.4.3.2 A manual actuation of each required SRV is performed to verify that, mechanically, the valve is functioning properly and no blockage exists in the valve discharge line. This can be demonstrated by the response of the turbine governor valves or bypass valves, by a change in the measured steam flow, or any other method suitable to verify steam flow.
If the valve fails to actuate due only to the failure of the solenoid but is capable of opening on overpressure, the safety function of the SRV is not considered inoperable.
The 24 month Frequency was developed based on the SRV tests required by the ASME OM Code (Ref. 7). Operating experience has shown that these components usually pass the Surveillance when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. ASME, Boiler and Pressure Vessel Code, Section III.
: 2. FSAR, Section 15.2.4.
: 3. FSAR, Chapter 15.
: 4. GE-NE-187-24-0992, "WPPSS Nuclear Project 2 SRV Setpoint Tolerance and Out-of-Service Analysis," Revision 2, July 1993.
: 5. NEDC-32115P, Columbia Generating Station, "SAFER/GESTR-LOCA Loss-of-Coolant Accident Analysis," Revision 2, July 1993.
: 6. 10 CFR 50.36(c)(2)(ii).
: 7. ASME Code for Operation and Maintenance of Nuclear Power Plants.
Columbia Generating Station              B 3.4.3-4                                    Revision 73
 
SRVs - < 25% RTP B 3.4.4 BASES SURVEILLANCE        SR 3.4.4.1 REQUIREMENTS This Surveillance demonstrates that the required SRVs will open at the pressures assumed in the safety analysis of Reference 2. The demonstration of the SRV safety function lift settings is in accordance with the Inservice Testing Program. The lift setting pressure shall correspond to ambient conditions of the valves at nominal operating temperatures and pressures.
SR 3.4.4.2 A manual actuation of each required SRV is performed to verify that, mechanically, the valve is functioning properly and no blockage exists in the valve discharge line. This can be demonstrated by the response of the turbine governor valves or bypass valves, by a change in the measured steam flow, or any other method suitable to verify steam flow.
Adequate reactor steam dome pressure must be available to perform this test to avoid damaging the valve. Also, adequate steam flow must be passing through the main turbine or turbine bypass valves to continue to control reactor pressure and flow when the SRVs divert steam flow upon opening. Sufficient time is therefore allowed after the required pressure and flow are achieved to perform this test. Adequate pressure at which this test is to be performed is 900 psig (consistent with the recommendations of the vendor). Adequate steam flow is represented by THERMAL POWER t 10% RTP. Plant startup is allowed prior to performing this test because valve OPERABILITY and the setpoints for overpressure protection are verified, per ASME requirements, prior to reactor startup. 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 and flow are reached is sufficient to achieve stable conditions for testing and provides a reasonable time to complete the SR. If the valve fails to actuate due only to the failure of the solenoid but is capable of opening on overpressure, the safety function of the SRV is not considered inoperable.
The 24 month Frequency was developed based on the SRV tests required by the ASME OM Code (Ref. 7). Operating experience has shown that these components usually pass the Surveillance when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.4.4-3                                    Revision 73
 
SRVs - < 25% RTP B 3.4.4 BASES REFERENCES          1. FSAR, Section 15.2.4.
: 2. Columbia Generating Station Calculation NE-02-94-66, Revision 0, November 13, 1995.
: 3. ASME, Boiler and Pressure Vessel Code, Section III.
: 4. FSAR, Chapter 15.
: 5. GE-NE-187-24-0992, "WPPSS Nuclear Project 2 SRV Setpoint Tolerance and Out-of-Service Analysis," Revision 2, July 1993.
: 6. 10 CFR 50.36(c)(2)(ii).
: 7. ASME Code for Operation and Maintenance of Nuclear Power Plants.
Columbia Generating Station          B 3.4.4-4                                    Revision 73
 
RCS Operational LEAKAGE B 3.4.5 BASES ACTIONS (continued) type 304 and type 316 austenitic stainless steel piping that is subject to high stress or that contains relatively stagnant or intermittent flow fluids and determine it is not the source of the increased LEAKAGE. This type of piping is very susceptible to IGSCC.
The 4 hour Completion Time is needed to properly reduce the LEAKAGE increase or verify the source before the reactor must be shut down.
C.1 and C.2 If any Required Action and associated Completion Time of Condition A or B is not met or if pressure boundary LEAKAGE exists, 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 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 3.4.5.1 REQUIREMENTS The RCS LEAKAGE is monitored by a variety of instruments designed to provide alarms when LEAKAGE is indicated and to quantify the various types of LEAKAGE. Leakage detection instrumentation is discussed in more detail in the Bases for LCO 3.4.7, "RCS Leakage Detection Instrumentation." Sump flow rate is typically monitored to determine actual LEAKAGE rates. However, any method may be used to quantify LEAKAGE within the guidelines of Reference 8. In conjunction with alarms and other administrative controls, a 12 hour Frequency for this Surveillance is appropriate for identifying changes in LEAKAGE and for tracking required trends (Ref. 9).The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
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.
Columbia Generating Station            B 3.4.5-4                                      Revision 73
 
RCS Operational LEAKAGE B 3.4.5 BASES REFERENCES (continued)
: 5. NUREG-75/067, "Investigation and Evaluation of Cracking in Austenitic Stainless Steel Piping of Boiling Water Reactors,"
October 1975.
: 6. FSAR, Section 5.2.5.5.2.
: 7. 10 CFR 50.36(c)(2)(ii).
: 8. Regulatory Guide 1.45, May 1973.
: 9. Generic Letter 88-01, Supplement 1, February 1992.
Columbia Generating Station          B 3.4.5-5                                    Revision 73
 
RCS Leakage Detection Instrumentation B 3.4.7 BASES 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 other required instrumentation (either the drywell floor drain sump flow monitoring system or the drywell atmospheric monitoring channel, as applicable) is OPERABLE. 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. The 6 hour testing allowance is acceptable since it does not significantly reduce the probability of properly monitoring drywell leakage.
SR 3.4.7.1 This SR requires the performance of a CHANNEL CHECK of the required drywell atmospheric monitoring system. 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 qualitative assessment, by observation, of channel behavior during operation. This determination includes, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter. 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. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.4.7.2 This SR requires the performance of a CHANNEL FUNCTIONAL TEST of the required RCS leakage detection instrumentation. The test ensures that the monitors can perform their function in the desired manner. The test also verifies the alarm setpoint and relative accuracy of the instrument string. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The Frequency of 31 days considers instrument reliability, and operating experience has shown it proper for detecting degradation.
SR 3.4.7.3 Columbia Generating Station            B 3.4.7-6                                    Revision 82
 
RCS Leakage Detection Instrumentation B 3.4.7 This SR requires the performance of a CHANNEL CALIBRATION of the required RCS leakage detection instrumentation channels. The calibration verifies the accuracy of the instrument string, including the Columbia Generating Station            B 3.4.7-7                                    Revision 82
 
RCS Leakage Detection Instrumentation B 3.4.7 BASES SURVEILLANCE REQUIREMENTS (continued) instruments located inside the drywell. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The Frequency of 18 months is a typical refueling cycle and considers channel reliability. Operating experience has proven this Frequency is acceptable.
REFERENCES          1. 10 CFR 50, Appendix A, GDC 30.
: 2. Regulatory Guide 1.45, Revision 0, Reactor Coolant Pressure Boundary Leakage Detection Systems, May 1973.
: 3. Deleted
: 4. GEAP-5620, "Failure Behavior in ASTM A106B Pipes Containing Axial Through-Wall Flaws," April 1968.
: 5. NUREG-75/067, "Investigation and Evaluation of Cracking in Austenitic Stainless Steel Piping of Boiling Water Reactors,"
October 1975.
: 6. FSAR, Section 5.2.5.5.
: 7. 10 CFR 50.36(c)(2)(ii).
: 8. FSAR 7.6.2.4.
Columbia Generating Station            B 3.4.7-8                                  Revision 82
 
RCS Specific Activity B 3.4.8 BASES ACTIONS (continued)
This allowance is acceptable due to the significant conservatism incorporated into the specific activity limit, the low probability of an event which is limiting due to exceeding this limit, and the ability to restore transient specific activity excursions while the plant remains at, or proceeds to power operation.
B.1, B.2.1, B.2.2.1, and B.2.2.2 If the DOSE EQUIVALENT I-131 cannot be restored to d 0.2 Ci/gm within 48 hours, or if at any time it is > 4.0 Ci/gm, it must be determined at least every 4 hours and all the main steam lines must be isolated within 12 hours. Isolating the main steam lines precludes the possibility of releasing radioactive material to the environment in an amount that is more than the requirements of 10 CFR 50.67 during a postulated MSLB accident.
Alternately, the plant can be brought to MODE 3 within 12 hours and to MODE 4 within 36 hours. This option is provided for those instances when isolation of main steam lines is not desired (e.g., due to the decay heat loads). In MODE 4, the requirements of the LCO are no longer applicable.
The Completion Time of once every 4 hours is the time needed to take and analyze a sample. The 12 hour Completion Time is reasonable, based on operating experience, to isolate the main steam lines in an orderly manner and without challenging plant systems. Also, the allowed Completion Times for Required Actions B.2.2.1 and B.2.2.2 for bringing the plant to MODES 3 and 4 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 3.4.8.1 REQUIREMENTS This Surveillance is performed to ensure iodine remains within limit during normal operation. The 7 day Frequency is adequate to trend changes in the iodine activity level.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. This SR is modified by a Note that requires this Surveillance to be performed only in MODE 1 because the level of fission products generated in other MODES is much less.
Columbia Generating Station            B 3.4.8-3                                        Revision 73
 
RHR Shutdown Cooling System - Hot Shutdown B 3.4.9 BASES ACTIONS (continued)
B.1, B.2, and B.3 With no RHR shutdown cooling subsystem and no recirculation pump in operation, except as is permitted by LCO Note 1, reactor coolant circulation by the RHR shutdown cooling subsystem or one recirculation pump must be restored without delay.
Until RHR or recirculation pump operation is re-established, an alternate method of reactor coolant circulation must be placed into service. This will provide the necessary circulation for monitoring coolant temperature.
The 1 hour Completion Time is based on the coolant circulation function and is modified such that the 1 hour is applicable separately for each occurrence involving a loss of coolant circulation. Furthermore, verification of the functioning of the alternate method must be reconfirmed every 12 hours thereafter. This will provide assurance of continued temperature monitoring capability.
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 recirculation pump is in operation and circulating reactor coolant. The required flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability. The Frequency of 12 hours is sufficient in view of other visual and audible indications available to the operator for monitoring the RHR subsystem in the control room.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
This Surveillance is modified by a Note allowing sufficient time to align the RHR System for shutdown cooling operation after achieving less than 48 psig reactor steam dome pressure, 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.
REFERENCES          1. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.4.9-4                                      Revision 73
 
RHR Shutdown Cooling System - Cold Shutdown B 3.4.10 BASES SURVEILLANCE        SR 3.4.10.1 REQUIREMENTS This Surveillance verifies that one RHR shutdown cooling subsystem or recirculation pump is in operation and circulating reactor coolant. The required flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability. The Frequency of 12 hours is sufficient in view of other visual and audible indications available to the operator for monitoring the RHR subsystem in the control room.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.4.10-4                                    Revision 73
 
RCS P/T Limits B 3.4.11 BASES ACTIONS (continued)
C.1 and C.2 Operation outside the P/T 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 LEFM analyses. The Required Action must be initiated without delay and continued until the limits are restored.
Besides restoring the P/T 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&deg;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.
Condition C is modified by a Note requiring Required Action C.2 be completed whenever the Condition is entered. The Note emphasizes the need to perform the evaluation of the effects of the excursion outside the allowable limits. Restoration alone per Required Action C.1 is insufficient because higher than analyzed stresses may have occurred and may have affected the RCPB integrity.
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 control room indication available 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 Frequency is controlled under the Surveillance Frequency Control Program. The limits of Figures 3.4.11-1, 3.4.11-2, and 3.4.11-3 are met when operation is to the right of the applicable limit curves.
Surveillance for heatup, cooldown, or inservice leakage and hydrostatic testing may be discontinued when the criteria given in the relevant plant procedure for ending the activity are satisfied.
This SR has been modified by a Note that requires this Surveillance to be performed only during system heatup and cooldown operations and inservice leakage and hydrostatic testing.
Columbia Generating Station            B 3.4.11-6                                    Revision 73
 
RCS P/T Limits B 3.4.11 BASES SURVEILLANCE REQUIREMENTS (continued)
An acceptable means of demonstrating compliance with the temperature differential requirement in SR 3.4.11.6 is to compare the temperatures of the operating recirculation loop and the idle loop.
Plant specific startup test data has determined that the bottom head is not subject to temperature stratification at power levels > 25% of RTP and with single loop flow rate > 10% of rated loop flow. Therefore, SR 3.4.11.5 and SR 3.4.11.6 have been modified by a Note that requires the Surveillance to be met only under these conditions. The Note for SR 3.4.11.6 further limits the requirement for this Surveillance to exclude comparison of the idle loop temperature if the idle loop is isolated from the RPV since the water in the loop can not be introduced into the remainder of the Reactor Coolant System.
SR 3.4.11.7, SR 3.4.11.8, and SR 3.4.11.9 Limits on the reactor vessel flange and head flange temperatures are generally bounded by the other P/T 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 temperature d 90&deg;F, 30 minute checks of the flange temperatures are required because of the reduced margin to the limits.
When in MODE 4 with RCS temperature d 100&deg;F, monitoring of the flange temperature is required every 12 hours to ensure the temperatures are within the specified limits.
The 30 minute Frequency reflects the urgency of maintaining the temperatures within limits, and also limits the time that the temperature limits could be exceeded. The 12 hour Frequency is reasonable based on the rate of temperature change possible at these temperatures.The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
SR 3.4.11.7 is modified by a Note that requires the Surveillance to be performed only when tensioning the reactor vessel head bolting studs.
SR 3.4.11.8 is modified by a Note that requires the Surveillance to be initiated 30 minutes after RCS temperature d 90&deg;F in MODE 4.
Columbia Generating Station            B 3.4.11-8                                    Revision 73
 
Reactor Steam Dome Pressure B 3.4.12 BASES ACTIONS            A.1 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.
B.1 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 d 1035 psig ensures that the initial conditions of the vessel overpressure protection analysis is 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 Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Section 5.2.2.
: 2. FSAR, Chapter 15.
: 3. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.4.12-2                                  Revision 73
 
ECCS - Operating B 3.5.1 BASES ACTIONS (continued)
H.1 When multiple ECCS subsystems are inoperable, as stated in Condition H, the plant is in a condition outside of the accident analyses.
Therefore, LCO 3.0.3 must be entered immediately.
SURVEILLANCE        SR 3.5.1.1 REQUIREMENTS The flow path piping has the potential to develop voids and pockets of entrained air. Maintaining the pump discharge lines of the HPCS System, LPCS System, and LPCI subsystems full of water ensures that the systems will perform properly, injecting their full capacity into the RCS upon demand. This will also prevent a water hammer following an ECCS initiation signal. One acceptable method of ensuring the lines are full is to vent at the high points. The 31 day Frequency is based on operating experience, on the procedural controls governing system operation, and on the gradual nature of void buildup in the ECCS piping.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.5.1.2 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 potentially capable of being mispositioned are in the correct position.
This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves.
The 31 day Frequency of this SR was derived from the Inservice Testing program requirements for performing valve testing at least once every 92 days. The Frequency of 31 days is further justified because the 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.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.5.1-8                                      Revision 73
 
ECCS - Operating B 3.5.1 BASES SURVEILLANCE REQUIREMENTS (continued)
In MODE 3 with the reactor steam dome pressure less than 48 psig, the RHR System may be required to operate in the shutdown cooling mode to remove decay heat and sensible heat from the reactor. Therefore, this SR is modified by a Note that allows LPCI subsystems to be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned (remote or local) to the LPCI mode and not otherwise inoperable. Alignment and operation for decay heat removal includes when the required RHR pump is not operating or when the system is being realigned from or to the RHR shutdown cooling mode.
At the low pressures and decay heat loads associated with operation in MODE 3 with reactor steam dome pressure less than 48 psig, a reduced complement of low pressure ECCS subsystems should provide the required core cooling, thereby allowing operation of RHR shutdown cooling, when necessary.
SR 3.5.1.3 Verification every 31 days that ADS accumulator backup compressed gas system average pressure in the required bottles is t 2200 psig assures an adequate and OPERABLE air supply to the ADS valves. The minimum number of required bottles is 14 bottles in Division 1 and 17 in Division 2. The remote nitrogen cylinder connection in the DG corridor may be used to make up the minimum number of required bottles, provided the bottle(s) is properly installed to satisfy the seismic Category 1 restraint requirements and the bottle(s) capacity is greater than or equal to the capacity of the bottle being replaced. The nitrogen banks are sized to provide a 30 day supply of nitrogen for the ADS function. The ADS function is required to provide a flow path for alternate shutdown cooling. Alternate shutdown cooling is accomplished utilizing one RHR subsystem and the ADS to provide a path to the suppression pool for decay heat removal. The Surveillance Frequency is controlled under the Surveillance Frequency Control 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).
Columbia Generating Station            B 3.5.1-9                                      Revision 73
 
ECCS - Operating B 3.5.1 BASES SURVEILLANCE REQUIREMENTS (continued)
The pump flow rates are verified against a system pressure difference.
For the LPCS and LPCI pumps the pressure difference is equivalent to that between the reactor and the suppression pool air volume. For the HPCS pump it is equivalent to the differential above the suction source (suppression pool or condensate storage tank). Under these conditions 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. A 92 day Frequency for this Surveillance is in accordance with the Inservice 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 to their required positions. 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 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. Operating experience has shown that these components usually pass the SR when performed at the 24 month Frequency, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
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.
Columbia Generating Station            B 3.5.1-10                                    Revision 73
 
ECCS - Operating B 3.5.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.1.6 The ADS designated SRVs 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. This Surveillance also ensures the automatic alignment of the ADS accumulator backup compressed gas system on an actual or simulated ADS header pressure low signal. SR 3.5.1.7 and the LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.1 overlap 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 3 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. Operating experience has shown that these components usually pass the SR when performed at the 24 month Frequency, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
This SR is modified by a Note that excludes valve actuation since the valves are individually tested in accordance with SR 3.5.1.7. This also prevents an RPV pressure blowdown.
SR 3.5.1.7 A manual actuation of each required ADS valve is performed to verify that the valve and solenoids are functioning properly and that no blockage exists in the SRV discharge lines. This is demonstrated by the response of the turbine control or bypass valve, by a change in the measured steam flow, or by any other method suitable to verify steam flow.
Adequate reactor steam dome pressure must be available to perform this test to avoid damaging the valve. Also, adequate steam flow must be passing through the main turbine or turbine bypass valves to continue to control reactor pressure when the ADS valves divert steam flow upon opening. Sufficient time is therefore allowed, after the required pressure and flow are achieved, to perform this test. Adequate pressure at which this test is to be performed is 900 psig (consistent with the recommendations of the vendor). Adequate steam flow is represented by THERMAL POWER t 10% RTP. Reactor startup is allowed prior to Columbia Generating Station            B 3.5.1-11                                    Revision 73
 
ECCS - Operating B 3.5.1 performing this test because valve OPERABILITY and the setpoints for overpressure protection are verified, per ASME requirements, prior to Columbia Generating Station          B 3.5.1-12                                Revision 73
 
ECCS - Operating B 3.5.1 BASES SURVEILLANCE REQUIREMENTS (continued) reactor startup. 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 and flow are reached is sufficient to achieve stable conditions and provides adequate time to complete the SR. SR 3.5.1.6 and the LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.1 overlap this Surveillance to provide complete testing of the assumed safety function.
The Frequency of 24 months on a STAGGERED TEST BASIS ensures that both ADS trip system solenoids for each required ADS valve are alternately tested. The Frequency is based on the need to perform this Surveillance under the conditions that apply just prior to or during a startup from a plant outage.
Operating experience has shown that these components usually pass the SR when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.5.1.8 This SR ensures that the ECCS RESPONSE TIME for each ECCS injection/spray subsystem is less than or equal to the maximum value assumed in the accident analysis. Response time testing acceptance criteria are included in Reference 15. This SR has been modified by a Note that allows the instrumentation portion of the response time to be excluded and therefore, it is not required to quantitatively measure the sensor response time to satisfy the requirement to verify ECCS RESPONSE TIME. This is acceptable since the instrumentation response time is a small part of the response time and can be qualitatively verified by other methods (Reference 16.) If the response time of the instrumentation is not quantitatively measured, the acceptance criteria must be reduced by a minimum of the time assumed for the instrumentation response in the design analyses, as supported by operating experience.
ECCS RESPONSE TIME tests are conducted on a 24 month STAGGERED TEST BASIS. The 24 month Frequency is consistent with the typical industry refueling cycle and is based upon plant operating experience.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.5.1-13                                  Revision 73
 
ECCS - Shutdown B 3.5.2 BASES SURVEILLANCE        SR 3.5.2.1 and SR 3.5.2.2 REQUIREMENTS The minimum water level of 18 ft 6 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 (135,000 gallons consistent with the CST volume requirements described below), 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 (Ref. 5).
When the suppression pool level is < 18 ft 6 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 t 18 ft 6 inches or the HPCS System is aligned to take suction from the CST and the CST contains t 135,000 gallons of water. This volume of water is equivalent to a level of 16.5 ft in a single CST or 10.5 ft in each CST above the top of the suction line. This ensures that the HPCS System can supply makeup water to the RPV. Calculations that determine this water level are listed as References 3 and 4.
The 12 hour Frequency of these SRs was developed considering operating experience related to suppression pool and CST water level variations and instrument drift 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.
The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
SR 3.5.2.3, SR 3.5.2.5, and SR 3.5.2.6 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 Columbia Generating Station              B 3.5.2-4                                    Revision 73
 
ECCS - Shutdown B 3.5.2 BASES SURVEILLANCE REQUIREMENTS (continued) 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. The 31 day Frequency is appropriate because the valves are operated under procedural control and the probability of their being mispositioned during this time period is low.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
In MODES 4 and 5, the RHR System may be required to operate in the shutdown cooling mode to remove decay heat and sensible heat from the reactor. Therefore, this SR is modified by a Note that allows one LPCI subsystem to be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned (remote or local) to the LPCI mode and not otherwise inoperable. Alignment and operation for decay heat removal includes when the required RHR pump is not operating or when the system is being realigned from or to the RHR shutdown cooling mode. Because of the low pressure and low temperature conditions in MODES 4 and 5, sufficient time will be available to manually align and initiate LPCI subsystem operation to provide core cooling prior to postulated fuel uncovery. This will ensure adequate core cooling if an inadvertent vessel draindown should occur.
REFERENCES          1. FSAR, Section 6.3.3.4.
: 2. 10 CFR 50.36(c)(2)(ii).
: 3. E/I-02-91-1011.
: 4. E/I-02-98-1002.
: 5. TM 2092.
Columbia Generating Station          B 3.5.2-5                                        Revision 73
 
RCIC System B 3.5.3 BASES ACTIONS (continued) certain abnormal events with no LOCA, RCIC (as opposed to HPCS) is the preferred source of makeup coolant because of its relatively small capacity, which allows easier control of RPV water level. Therefore, a limited time is allowed to restore the inoperable RCIC to OPERABLE status.
The 14 day Completion Time is based on a reliability study (Ref. 4) that evaluated the impact on ECCS availability, assuming that various components and subsystems were taken out of service. The results were used to calculate the average availability of ECCS equipment needed to mitigate the consequences of a LOCA as a function of allowed outage times (AOTs). Because of the similar functions of the HPCS and RCIC, the AOTs (i.e., Completion Times) determined for the HPCS are also applied to RCIC.
B.1 and B.2 If the RCIC System cannot be restored to OPERABLE status within the associated Completion Time, or if the HPCS System is simultaneously inoperable, the plant must be brought to a condition 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 reactor steam dome pressure reduced to d 150 psig 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 3.5.3.1 REQUIREMENTS The flow path piping has the potential to develop voids and pockets of entrained air. Maintaining the pump discharge line of the RCIC System full of water ensures that the system will perform properly, injecting its full capacity into the Reactor Coolant System upon demand. This will also prevent a water hammer following an initiation signal. One acceptable method of ensuring the line is full is to vent at the high points. The 31 day Frequency is based on the gradual nature of void buildup in the RCIC piping, the procedural controls governing system operation, and operating experience.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.5.3-3                                      Revision 73
 
RCIC System B 3.5.3 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.3.2 Verifying the correct alignment for manual, power operated, and 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 31 day Frequency of this SR was derived from the Inservice Testing Program requirements for performing valve testing at least every 92 days.
The Frequency of 31 days is further justified because the valves are operated under procedural control and because improper valve position would affect only the RCIC System. This Frequency has been shown to be acceptable through operating experience.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.5.3.3 and SR 3.5.3.4 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 against a system head corresponding to reactor pressure is tested both at the higher and lower operating ranges of the system. The required system head should overcome the RPV pressure and associated discharge line losses. Adequate reactor steam pressure must be available to perform these tests. 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. Therefore, sufficient time is allowed after adequate pressure and flow are achieved to perform these SRs. Adequate reactor steam pressure to perform SR 3.5.3.3 is 935 psig and to perform SR 3.5.3.4 is 150 psig. Adequate steam flow to perform SR 3.5.3.3 is represented by THERMAL POWER t 10% RTP and to perform SR 3.5.3.4 is represented by turbine bypass valves t 10%
Columbia Generating Station            B 3.5.3-4                                      Revision 73
 
RCIC System B 3.5.3 BASES SURVEILLANCE REQUIREMENTS (continued) open. Reactor startup is allowed prior to performing the low pressure Surveillance because the reactor pressure is low and the time to satisfactorily perform 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 are not required to be performed until 12 hours after the reactor steam pressure and flow are adequate to perform the test. The 12 hours allowed for the flow tests after the required pressure and flow are reached is sufficient to achieve stable conditions for testing and provides a reasonable time to complete the SRs.
A 92 day Frequency for SR 3.5.3.3 is consistent with the Inservice Testing Program requirements. The 24 month Frequency for SR 3.5.3.4 is based on the need to perform this Surveillance under the conditions that apply just prior to or during startup from a plant outage. Operating experience has shown that these components usually pass the SR when performed at the 24 month Frequency, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
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, 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 overlaps this Surveillance to provide complete testing of the assumed design function.
While this Surveillance can be performed with the reactor at power, operating experience has shown that these components usually pass the SR when performed at the 24 month Frequency, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.5.3-5                                      Revision 73
 
Primary Containment B 3.6.1.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.1.1.2 Maintaining the pressure suppression function of primary containment requires limiting the leakage from the drywell to the suppression chamber.
Thus, if an event were to occur that pressurized the drywell, the steam would be directed through the downcomers into the suppression pool.
This SR measures drywell to suppression chamber differential pressure during a 4 hour period to ensure that the leakage paths that would bypass the suppression pool are within allowable limits.
Satisfactory performance of this SR can be achieved by establishing a known differential pressure (t 1.5 psid) between the drywell and the suppression chamber and verifying that the bypass leakage is equivalent to that through an area  10% of the acceptable design value of d 0.050 ft2. The leakage test is performed every 120 months. The Frequency was developed considering it is prudent that this Surveillance be performed during a unit outage and also in view of the fact that component failures that might have affected this test are identified by other primary containment SRs.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. One test failure increases the Surveillance Frequency to 48 months. Two consecutive as found test failures, however, would indicate unexpected primary containment degradation; in this event increasing the Frequency to once every 24 months is required until the situation is remedied as evidenced by passing two consecutive tests.
SR 3.6.1.1.3 Maintaining the pressure suppression function of the primary containment requires limiting the leakage from the drywell to the suppression chamber.
Thus, if an event were to occur that pressurizes the drywell, the steam would be directed through the downcomers into the suppression pool.
This SR measures the drywell to suppression chamber vacuum relief valve bypass leakage to ensure that these leakage paths that would bypass the suppression pool are within allowable limits.
Satisfactory performance of this SR can be achieved by establishing a known initial differential pressure (> 1.5 psid) between the drywell side and the suppression chamber side of the suppression to drywell chamber vacuum relief valve and verifying that the measured bypass leakage is
                    < 1.2% of the acceptable design value of 0.050 ft2. The leakage test is performed every 24 months. The 24 month Frequency was developed considering it is prudent that this Surveillance be performed during a unit refueling outage.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.6.1.1-4                                  Revision 73
 
Primary Containment B 3.6.1.1 BASES SURVEILLANCE REQUIREMENTS (continued)
The SR is modified by a Note stating that performance of SR 3.6.1.1.2 satisfies this Surveillance Requirement. This is acceptable since drywell to suppression chamber vacuum relief valve leakage is included in the measurement of the drywell to suppression chamber bypass leakage required by SR 3.6.1.1.2.
SR 3.6.1.1.4 Maintaining the pressure suppression function of the primary containment requires limiting the leakage from the drywell to the suppression chamber.
Thus, if an event were to occur that pressurizes the drywell, the steam would be directed through the downcomers into the suppression pool.
This SR determines the total drywell to suppression chamber vacuum relief valve bypass leakage to ensure that these leakage paths that would bypass the suppression pool are within allowable limits.
For those outages where the drywell to suppression chamber bypass leak rate test (BLRT) is not conducted, the suppression chamber to drywell vacuum breaker (CVB) leakage test verifies that even with the maximum allowable CVB leakage, a margin of 70% remains for potential passive structural leakage. Previous drywell to suppression chamber bypass test data indicates that the bypass leakage through the passive structural components will be a small fraction of the remaining 70% margin. The CVB leakage limit, combined with negligible leakage from the passive structural area, ensures that the drywell to suppression chamber bypass leakage limit is met for those outages in which the BLRT is not performed.
Satisfactory performance of this SR is achieved by summing the individual drywell to suppression chamber vacuum relief valve bypass leakages from SR 3.6.1.1.3 and verifying that the total measured bypass leakage is < 3.0% of the acceptable design value of 0.050 ft2. The acceptable bypass leakage determination of this Surveillance is performed every 24 months. The 24 month Frequency was developed considering it is prudent that this Surveillance be performed during a unit refueling outage.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
The SR is modified by a Note stating that performance of SR 3.6.1.1.2 satisfies this Surveillance Requirement. This is acceptable since drywell to suppression changer vacuum relief valve leakage is included in the measurement of the drywell to suppression chamber bypass leakage required by SR 3.6.1.1.2.
Columbia Generating Station          B 3.6.1.1-5                                    Revision 73
 
Primary Containment Air Lock B 3.6.1.2 BASES SURVEILLANCE        SR 3.6.1.2.1 REQUIREMENTS Maintaining the primary containment air lock OPERABLE requires compliance with the leakage rate test requirements of the Primary Containment Leakage Rate Testing Program. This SR reflects the leakage rate testing requirements with regard to air lock leakage (Type B leakage tests). The acceptance criteria were established as a small fraction of the total allowable primary containment leakage. 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 a DBA. 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 (the Primary Containment Leakage Rate Testing Program).
This ensures that air lock leakage is properly accounted for in determining the combined Type B and C primary containment leakage.
SR 3.6.1.2.2 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 the air lock are designed to withstand the maximum expected post accident primary containment pressure (Ref. 6), 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 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 purely mechanical nature of this interlock, and given that the interlock mechanism is not normally challenged when the primary containment air lock door is used for entry and exit (procedures require strict adherence to single door opening), this test is only required to be performed every 24 months. 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 loss of primary containment OPERABILITY if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency. The 24 month Frequency is based on engineering judgment and is considered adequate given that the interlock is not Columbia Generating Station            B 3.6.1.2-6                                    Revision 73
 
Primary Containment Air Lock B 3.6.1.2 challenged during use of the air lock. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station          B 3.6.1.2-7                                  Revision 73
 
PCIVs B 3.6.1.3 BASES ACTIONS (continued)
E.1 and E.2 If any Required Action and associated Completion Time cannot be met in MODE 1, 2, or 3, 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.
F.1 and F.2 If any Required Action and associated Completion Time cannot be met for PCIV(s) required OPERABLE in MODE 4 or 5, the plant must be placed in a condition in which the LCO does not apply. Action must be immediately initiated to suspend operations with a potential for draining the reactor 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 shutdown cooling 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 24 inch and 30 inch primary containment purge valves are closed as required or, if open, opened for an allowable reason.
The SR is modified by a Note 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 inerting, de-inerting, pressure control, ALARA, or air quality considerations for personnel entry, or for surveillances that require the valves to be open. 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 discussed in SR 3.6.1.3.2.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.6.1.3-8                                  Revision 73
 
PCIVs B 3.6.1.3 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.1.3.2 This SR verifies that each primary containment isolation manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured 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 isolation devices outside primary containment, and not locked, are in the correct position. Since verification of valve position for isolation devices outside primary containment is relatively easy, the 31 day Frequency was chosen to provide added assurance that the isolation devices are in the correct positions.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing.
Two Notes are added to this SR. The first 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 isolation devices, once they have been verified to be in the proper position, is low.
A second Note is included to clarify that PCIVs open under administrative controls are not required to meet the SR during the time the PCIVs are open. These controls consist of stationing a dedicated operator at the controls of the valve, who is in continuous communication with the control room. In this way, the penetration can be rapidly isolated when a need for primary containment isolation is indicated.
SR 3.6.1.3.3 This SR verifies that each primary containment manual isolation valve and blind flange located inside primary containment and not locked, sealed, or otherwise secured and required to be closed during accident conditions, is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside the primary containment boundary is within design limits. For isolation devices inside primary containment, the Frequency of "prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days," is appropriate since these isolation devices are Columbia Generating Station          B 3.6.1.3-9                                    Revision 73
 
PCIVs B 3.6.1.3 operated under administrative controls and the probability of their misalignment is low. This SR does not apply to valves that are locked, Columbia Generating Station        B 3.6.1.3-10                                    Revision 73
 
PCIVs B 3.6.1.3 BASES SURVEILLANCE REQUIREMENTS (continued) sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing.
Two Notes are added to this SR. The first Note allows valves and blind flanges located in high radiation areas to be verified by use of administrative controls. Allowing verification by administrative controls is considered acceptable since the primary containment is inerted and access to these areas is typically restricted during MODES 1, 2, and 3 for ALARA and personnel safety. Therefore, the probability of misalignment of these isolation devices, once they have been verified to be in their proper position, is low. A second Note is included to clarify that PCIVs that are open under administrative controls are not required to meet the SR during the time that the PCIVs are open. These controls consist of stationing a dedicated operator at the controls of the valve, who is in continuous communication with the control room. In this way, the penetration can be rapidly isolated when a need for primary containment isolation is indicated.
SR 3.6.1.3.4 The traversing incore probe (TIP) shear isolation valves are actuated by explosive charges. Surveillance of explosive charge continuity provides assurance that TIP valves will actuate when required. Other administrative controls, such as those that limit the shelf life and operating life, as applicable, of the explosive charges, must be followed. The 31 day Frequency is based on operating experience that has demonstrated the reliability of the explosive charge continuity.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.6.1.3.5 Verifying the isolation time of each power operated, 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 each valve will isolate in a time period less than or equal to that assumed in the safety analysis. The Frequency of this SR is in accordance with the Inservice Testing Program.
Columbia Generating Station            B 3.6.1.3-11                                    Revision 73
 
PCIVs B 3.6.1.3 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.1.3.6 Verifying that the full closure isolation time of each MSIV is within the specified limits is required to demonstrate OPERABILITY. The full closure isolation time test ensures that the MSIV will isolate in a time period that does not exceed the times assumed in the DBA and transient analyses. The Frequency of this SR is in accordance with the Inservice Testing Program.
SR 3.6.1.3.7 Automatic PCIVs close on a primary containment isolation signal to prevent leakage of radioactive material from primary containment following a DBA. 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 LCO 3.3.6.1, "Primary Containment Isolation Instrumentation," 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 with the reactor at power. Operating experience has shown that these components usually pass this Surveillance when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.6.1.3.8 This SR requires a demonstration that a representative sample of reactor instrument lines excess flow check valves (EFCVs) are OPERABLE by verifying that each tested valve actuates to the isolation position on an actual or simulated instrument line break condition. The representative sample consists of an approximately equal number of EFCVs, such that each EFCV is tested at least once every 10 years (nominal). In addition, the EFCVs in the sample are representative of the various plant configurations, models, sizes and operating environments. This ensures that any potentially common problem with a specific type or application of EFCV is detected at the earliest possible time. This SR provides assurance that the reactor instrumentation lines EFCVs will perform as designed. The excess flow check valves in reactor instrument lines are tested by providing an instrument line break signal with pressure at 85 psig to 1050 psig, and at no more than 212&deg;F, RPV coolant temperature, while the EFCV is being exercised. Testing within this Columbia Generating Station          B 3.6.1.3-12                                    Revision 73
 
PCIVs B 3.6.1.3 pressure range provides a high degree of assurance that these valves will close during an instrument line break while at normal operating pressure.
Columbia Generating Station        B 3.6.1.3-13                                  Revision 73
 
PCIVs B 3.6.1.3 BASES SURVEILLANCE REQUIREMENTS (continued)
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. The nominal 10 year interval is based on performance testing. Furthermore, any EFCV failures will be evaluated to determine if additional testing in that test interval is warranted to ensure overall reliability is maintained. Operating experience has demonstrated that these components are highly reliable and that failures to isolate are very infrequent. Therefore, testing of a representative sample was concluded to be acceptable from a reliability standpoint (Reference 5).
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. In addition, due to operational concerns, the Surveillance should not be performed during MODES 1, 2, or 3. This restriction has been established to limit the thermal cycles at the containment penetration.
SR 3.6.1.3.9 The TIP shear isolation valves are actuated by explosive charges. An in place functional test is not possible with this design. The explosive squib is removed and tested to provide assurance that the valves will actuate when required. The replacement charge for the explosive squib shall be from the same manufactured batch as the one fired or from another batch that has been certified by having one of the batch successfully fired.
Other administrative controls, such as those that limit the shelf life and operating life, as applicable, of the explosive charges, must be followed.
The Frequency of 24 months on a STAGGERED TEST BASIS is considered adequate given the administrative controls on replacement charges and the frequent checks of circuit continuity (SR 3.6.1.3.4).The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.6.1.3.10 This SR ensures that the leakage rate of secondary containment bypass leakage paths is less than the specified leakage rate. This provides assurance that the assumptions in the radiological evaluations that form the basis of the FSAR (Ref. 1) are met. The leakage rate of each bypass leakage path is assumed to be the maximum pathway leakage (leakage through the worse of the two isolation valves) unless the penetration is isolated by use of one closed and de-activated automatic valve, closed manual valve, or blind flange. In this case, the leakage rate of the isolated bypass leakage path is assumed to be the actual pathway leakage through the isolation device. If both isolation valves in the Columbia Generating Station            B 3.6.1.3-14                                    Revision 73
 
PCIVs B 3.6.1.3 penetration are closed, the actual leakage rate is the lesser leakage rate of the two valves. The Frequency is required by the Primary Containment Leakage Rate Testing Program. This SR simply imposes additional acceptance criteria.
Columbia Generating Station        B 3.6.1.3-15                                    Revision 73
 
PCIVs B 3.6.1.3 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.1.3.11 The radiological consequences associated with MSIV leakage following the design basis LOCA, is based on the testing leakage limit of 16.0 scfh as specified in this Surveillance. The test pressure, Pt (25 psig) specified in this Surveillance is less than the peak accident pressure, Pa. The specified Pt is less than Pa due to testing configuration constraints. The leakage assumed in the design basis LOCA analysis (Ref. 76) is calculated by converting the specified test leakage limit to the equivalent leakage rate for Pa conditions. This Surveillance ensures that MSIV leakage is properly accounted for in determining the overall primary containment leakage rate. The Frequency is required by the Primary Containment Leakage Rate Testing Program.
SR 3.6.1.3.12 Surveillance of hydrostatically tested lines provides assurance that the calculation assumptions of Reference 1 are met. The acceptance criteria for the combined leakage of all hydrostatically tested lines is d 1.0 gpm times the total number of hydrostatically tested PCIVs when tested at 1.1 Pa (41.8 psig). The combined leakage rates must be tested at the Frequency required by the Primary Containment Leakage Rate Testing Program.
REFERENCES          1. FSAR, Chapter 6.2.
: 2. FSAR, Section 15.2.4.
: 3. 10 CFR 50.36(c)(2)(ii).
: 4. Licensee Controlled Specifications Manual.
: 5. NEDO-32977-A, "Excess Flow Check Valve Testing Relaxation,"
dated June 2000.
: 65. FSAR, Section 15.6.4.
: 76. FSAR, Section 15.6.5.
: 87. Regulatory Guide 1.183, Appendix A, July 2000.
Columbia Generating Station          B 3.6.1.3-16                                  Revision 73
 
Drywell Air Temperature B 3.6.1.4 BASES ACTIONS (continued)
B.1 and B.2 If the drywell average air temperature cannot be restored to within the 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 3.6.1.4.1 REQUIREMENTS Verifying that the drywell 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 drywell average air temperature, an arithmetic average is calculated, using inlet air temperature measurements taken from a minimum of three operating drywell cooling units. This provides a representative sample of the overall drywell atmosphere.
The 24 hour Frequency of this SR was developed based on operating experience related to drywell average air temperature variations and temperature dependent drift of instrumentation located in the drywell during the applicable MODES and the low probability of a DBA occurring between surveillances. 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 drywell air temperature condition.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Section 6.2.1.1.3.3.
: 2. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.6.1.4-2                                  Revision 73
 
RHR Drywell Spray B 3.6.1.5 BASES ACTIONS (continued)
C.1 and C.2 If any Required Action and associated Completion Time cannot be met, 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 the correct alignment for manual and power operated valves in the RHR drywell spray mode flow path provides assurance that the proper flow paths will exist for system 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 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 drywell spray 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 inadvertently misaligned, such as check valves.
The 31 day Frequency of this SR is justified because the valves are operated under procedural control, improper valve position would affect only a single subsystem, the probability of an event requiring initiation of the system is low, and the system is a manually initiated system. This Frequency has been shown to be acceptable based on operating experience.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.6.1.5.2 This Surveillance is performed every 10 years to verify, by performance of an air or smoke flow test, that the spray nozzles are not obstructed and that flow will be provided when required. The 10 year Frequency is adequate to detect degradation in performance due to the passive nozzle design and its normally dry state and has been shown to be acceptable through operating experience.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.6.1.5-3                                    Revision 73
 
Reactor Building-to-Suppression Chamber Vacuum Breakers B 3.6.1.6 BASES ACTIONS (continued)
D.1 With two or more lines with one or more vacuum breakers inoperable for opening, the primary containment boundary is intact. However, in the event of a containment depressurization, the function of the vacuum breakers is lost. Therefore, all vacuum breakers in two lines must be restored to OPERABLE status within 1 hour. This Completion Time is consistent with the ACTIONS of LCO 3.6.1.1, which requires that primary containment be restored to OPERABLE status within 1 hour.
E.1 and E.2 If any Required Action and associated Completion Time cannot be met, 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 3.6.1.6.1 REQUIREMENTS Each vacuum breaker is verified to be closed to ensure that a potential breach in the primary containment boundary is not present. This Surveillance is performed by observing local or control room indications of vacuum breaker position or by verifying a differential pressure of
                    > 0.5 psid is maintained between the reactor building and suppression chamber. The 14 day Frequency is based on engineering judgment, is considered adequate in view of other indications of vacuum breaker status available to operations personnel, and has been shown to be acceptable through operating experience.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Two Notes are added to this SR. The first Note allows reactor building-to-suppression chamber vacuum breakers opened in conjunction with the performance of a surveillance to not be considered as failing this SR.
These periods of opening vacuum breakers are controlled by plant procedures and do not represent inoperable vacuum breakers. The second Note is included to clarify that vacuum breakers open due to an actual differential pressure, are not considered as failing this SR.
Columbia Generating Station          B 3.6.1.6-4                                    Revision 73
 
Reactor Building-to-Suppression Chamber Vacuum Breakers B 3.6.1.6 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.1.6.2 Each vacuum breaker must be cycled to ensure that it opens properly to perform its design function and returns to its fully closed position. This ensures that the safety analysis assumptions are valid. The Frequency of this SR is in accordance with the Inservice Testing Program.
SR 3.6.1.6.3 Demonstration of vacuum breaker opening setpoint is necessary to ensure that the safety analysis assumption regarding vacuum breaker full open differential pressure of < 0.5 psid is valid. The 24 month Frequency is based on requirements associated with instruments that monitor differential pressure between the reactor building and suppression chamber. The 24 month Frequency has been shown to be acceptable, based on operating experience, and is further justified because of other surveillances performed at shorter Frequencies that convey the proper functioning status of each vacuum breaker.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Section 6.2.1.1.4.
: 2. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station          B 3.6.1.6-5                                    Revision 73
 
Suppression Chamber-to-Drywell Vacuum Breakers B 3.6.1.7 BASES ACTIONS (continued)
C.1 With one or more vacuum breakers with two disks not closed, this allows communication between the drywell and suppression chamber, and, as a result, there is the potential for primary containment overpressurization due to this bypass leakage if a LOCA were to occur. Therefore, one open vacuum breaker disk must be closed. A short time is allowed to close one of the vacuum breaker disks due to the low probability of an event that would pressurize primary containment. If vacuum breaker position indication is not reliable, an alternate method of verifying that the vacuum breaker disks are closed is to verify that a differential pressure of t 0.5 psid between the suppression chamber and drywell is maintained for 1 hour without makeup. The required 2 hour Completion Time is considered adequate to perform this test.
D.1 and D.2 If any Required Action and associated Completion Time cannot be met, 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 3.6.1.7.1 REQUIREMENTS Each vacuum breaker is verified closed (except when the vacuum breaker is performing its intended design function) to ensure that this potential large bypass leakage path is not present. This Surveillance is performed by observing the vacuum breaker position indication or by verifying that a differential pressure of t 0.5 psid between the suppression chamber and drywell is maintained for 1 hour without makeup. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 14 day Frequency is based on engineering judgment, is considered adequate in view of other indications of vacuum breaker status available to operations personnel, and has been shown to be acceptable through operating experience.
A Note is added to this SR which allows suppression chamber-to-drywell vacuum breakers opened in conjunction with the performance of a surveillance to not be considered as failing this SR. These periods of opening vacuum breakers are controlled by plant procedures and do not represent inoperable vacuum breakers.
Columbia Generating Station            B 3.6.1.7-4                                    Revision 73
 
Suppression Chamber-to-Drywell Vacuum Breakers B 3.6.1.7 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.1.7.2 Each required vacuum breaker must be cycled to ensure that it opens adequately to perform its design function and returns to the fully closed position. This ensures that the safety analysis assumptions are valid.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 31 day Frequency of this SR was developed, based on Inservice Testing Program requirements to perform valve testing at least once every 92 days. A 31 day Frequency was chosen to provide additional assurance that the vacuum breakers are OPERABLE, since they are located in a harsh environment (the suppression chamber airspace). In addition, this functional test is required within 12 hours after a discharge of steam to the suppression chamber from the safety/relief valves.
SR 3.6.1.7.3 Verification of the vacuum breaker opening setpoint is necessary to ensure that the safety analysis assumption regarding vacuum breaker full open differential pressure of  0.5 psid is valid. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.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. The 24 month Frequency has been shown to be acceptable, based on operating experience, and is further justified because of other surveillances performed at shorter Frequencies that convey the proper functioning status of each vacuum breaker.
REFERENCES          1. FSAR, Section 6.2.1.1.4.
: 2. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station          B 3.6.1.7-5                                    Revision 82
 
Suppression Pool Average Temperature B 3.6.2.1 BASES ACTIONS (continued)
                    > 110&deg;F, increased monitoring of pool temperature is required to ensure that it remains  120&deg;F. The once per 30 minute Completion Time is adequate, based on operating experience. Given the high pool temperature in this condition, the monitoring Frequency is increased to twice that of Condition A. Furthermore, the 30 minute Completion Time is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal suppression pool average temperature condition.
E.1 and E.2 If suppression pool average temperature cannot be maintained  120&deg;F, the plant must be brought to a MODE in which the LCO 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&deg;F could result in exceeding the design basis maximum allowable values for primary containment temperature or pressure. Furthermore, if a blowdown were to occur when temperature was > 120&deg;F, the maximum allowable bulk and local temperatures could be exceeded very quickly.
SURVEILLANCE        SR 3.6.2.1.1 REQUIREMENTS The suppression pool average temperature is regularly monitored to ensure that the required limits are satisfied. Average temperature is determined by taking an arithmetic average of eight functional suppression pool water temperature channels, two per sector (there is no divisional requirement for this SR). The 24 hour Frequency has been shown to be acceptable based on operating experience.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. When heat is being added to the suppression pool by testing, however, it is necessary to monitor suppression pool temperature more frequently. The 5 minute Frequency during testing is justified by the rates at which testing will heat up the suppression pool, has been shown to be acceptable based on operating experience, and provides assurance that allowable pool temperatures are not exceeded. The Frequencyies areis 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.
Columbia Generating Station            B 3.6.2.1-4                                    Revision 73
 
Suppression Pool Water Level B 3.6.2.2 BASES 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 has been shown to be acceptable based on operating experience. 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 suppression pool water level condition.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Section 6.2.
: 2. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station          B 3.6.2.2-3                                    Revision 73
 
RHR Suppression Pool Cooling B 3.6.2.3 BASES 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 inadvertently misaligned, such as check valves.
The Frequency of 31 days is justified because the valves are operated under procedural control, improper valve position would affect only a single subsystem, the probability of an event requiring initiation of the system is low, and the system is a manually initiated system. This Frequency has been shown to be acceptable, based on operating experience.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.6.2.3.2 Verifying each RHR pump develops a flow rate t 7100 gpm, while operating in the suppression pool cooling mode with flow through the associated heat exchanger, ensures that the primary containment peak pressure and temperature can be maintained below the design limits during a DBA (Ref. 2). The normal test of centrifugal pump performance required by the ASME OM Code (Ref. 4) is covered by the requirements of LCO 3.5.1, "ECCS - Operating." Such inservice tests confirm component OPERABILITY, and detect incipient failures by indicating abnormal performance. The Frequency of this SR is in accordance with the Inservice Testing Program.
REFERENCES          1. FSAR, Section 6.2.1.1.3.3.
: 2. FSAR, Section 6.2.2.3.
: 3. 10 CFR 50.36(c)(2)(ii).
: 4. ASME Code for Operation and Maintenance of Nuclear Power Plants.
Columbia Generating Station            B 3.6.2.3-3                                    Revision 73
 
Primary Containment Atmosphere Mixing System B 3.6.3.2 BASES SURVEILLANCE        SR 3.6.3.2.1 REQUIREMENTS Operating each head area return fan for t 15 minutes ensures that each subsystem is OPERABLE and that all associated controls are functioning properly. It also ensures that blockage or fan or motor failure can be detected for corrective action. The 92 day Frequency is consistent with the Inservice Testing Program Frequencies, operating experience, the known reliability of the fan motors and controls, and the two redundant fans available.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. Regulatory Guide 1.7, Revision 1, September 1976.
: 2. FSAR, Section 6.2.5.2.1.
: 3. Columbia Generating Station Technical Memo TM-2065, "Requirements for Containment Mixing Fans," Revision 0, July 15, 1994.
: 4. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station          B 3.6.3.2-4                                  Revision 73
 
Primary Containment Oxygen Concentration B 3.6.3.3 BASES APPLICABILITY (continued) within the last 24 hours before a shutdown, is low enough that these "windows," when the primary containment is not inerted, are also justified.
The 24 hour time period is a reasonable amount of time to allow plant personnel to perform inerting or de-inerting.
ACTIONS            A.1 If oxygen concentration is t 3.5 v/o at any time while operating in MODE 1, with the exception of the relaxations allowed during startup and shutdown, oxygen concentration must be restored to < 3.5 v/o within 24 hours. The 24 hour Completion Time is allowed when oxygen concentration is t 3.5 v/o because of the low probability and long duration of an event that would generate significant amounts of hydrogen and oxygen occurring during this period.
B.1 If oxygen concentration 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, power must be reduced to  15% RTP within 8 hours. The 8 hour Completion Time is reasonable, based on operating experience, to reduce reactor power from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE        SR 3.6.3.3.1 REQUIREMENTS The primary containment must be determined to be inerted by verifying that oxygen concentration is < 3.5 v/o. The 7 day Frequency is based on the slow rate at which oxygen concentration can change and on other indications of abnormal conditions (which would lead to more frequent checking by operators in accordance with plant procedures). Also, this Frequency has been shown to be acceptable through operating experience.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Section 6.2.5.
: 2. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station          B 3.6.3.3-2                                  Revision 73
 
Secondary Containment B 3.6.4.1 BASES ACTIONS (continued)
C.1 OPDRVs can be postulated to cause fission product release to the secondary containment. In such cases, the secondary containment is the only barrier to release of fission products to the environment.
Action must be immediately initiated to suspend OPDRVs if the secondary containment is inoperable to minimize the probability of a vessel draindown and subsequent potential for fission product release.
Actions must continue until OPDRVs are suspended.
SURVEILLANCE        SR 3.6.4.1.1 REQUIREMENTS This SR verifies the secondary containment boundary is being maintained in a sufficiently leak tight condition to preclude exfiltration under normal operating conditions. This is accomplished by verifying the indicated secondary containment pressure is greater than or equal to 0.25 inches of vacuum water gauge. The value of greater than or equal to 0.25 inches of water gauge is an indication of pressure at one location in the secondary containment and not a value maintained at every surface within the secondary containment. The containment drawn down to 0.25 inches of vacuum water gauge, as determined by a single representative location, is sufficient to demonstrate adequate performance. Minor amounts of exfiltration under these conditions are expected to have a minimal impact on the radiological consequences and does not present a safety concern. The instrument used to perform this surveillance measures pressure at reactor building elevation 572' in an area that has open communication with the rest of the secondary containment volume. The use of 0.25 inches of vacuum water gauge includes margin to account for uncertainties. The 24 hour Frequency of this SR was developed based on operating experience related to secondary containment vacuum variations during the applicable MODES and the low probability of a DBA occurring between surveillances.
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 secondary containment vacuum condition.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.6.4.1.2 and SR 3.6.4.1.3 Verifying that secondary containment equipment hatches and each inner access door or each outer access door in each access opening are closed at all times when secondary containment is required ensures that Columbia Generating Station            B 3.6.4.1-3                                    Revision 79
 
Secondary Containment B 3.6.4.1 the infiltration of outside air of such a magnitude as to prevent maintaining the desired negative pressure does not occur.
Columbia Generating Station            B 3.6.4.1-4                                  Revision 79
 
Secondary Containment B 3.6.4.1 BASES SURVEILLANCE REQUIREMENTS (continued)
Verifying that all such openings are closed provides adequate assurance that exfiltration from the secondary containment will not occur.
SR 3.6.4.1.2 also requires equipment hatches to be sealed. In this application, the term "sealed" has no connotation of leak tightness.
Maintaining secondary containment OPERABILITY requires verifying either all inner doors or all outer doors in the access opening are closed at all times when secondary containment is required. However, each secondary containment access door is normally kept closed, except when the access opening is being used for entry and exit or when maintenance is being performed on an access. The 31 day Frequency for these SRs has been shown to be adequate based on operating experience, and is considered adequate in view of the other indications of door and hatch status that are available to the operator.The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
SR 3.6.4.1.4 and SR 3.6.4.1.5 The SGT System exhausts the secondary containment 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 secondary containment that is less than the pressure external to the secondary containment boundary. This is accomplished by verifying the secondary containment can be drawn down to an indicated pressure of greater than or equal to 0.25 inches of vacuum water gauge in less than or equal to 120 seconds, following the start of a single SGT fan.
SR 3.6.4.1.5 demonstrates that each SGT subsystem can maintain an indicated secondary containment pressure of  0.25 inches of vacuum water gauge for 1 hour at an indicated flow rate  2240 cfm. The 1 hour test period allows secondary containment to be in thermal equilibrium at steady state conditions.
The value of greater than or equal to 0.25 inches of vacuum water gauge in these Surveillances is an indication of pressure at one location in the secondary containment and not a value maintained at every surface within the secondary containment. The instrument used to perform these Surveillances measures pressure at reactor building elevation 572' in an area that has open communication with the rest of the secondary containment volume. The use of 0.25 inches of vacuum water gauge includes margin to account for uncertainties.
Columbia Generating Station            B 3.6.4.1-5                                  Revision 79
 
Secondary Containment B 3.6.4.1 BASES SURVEILLANCE REQUIREMENTS (continued)
Therefore, these two tests are used to assess secondary containment boundary integrity. The inoperability of the SGT System does not necessarily constitute a failure of these Surveillance(s) relative to the secondary containment boundary. Since these SRs are secondary containment tests, they need not be performed with each SGT subsystem. The SGT subsystems are tested on a STAGGERED TEST BASIS, however, to ensure that in addition to the requirements of LCO 3.6.4.3, either SGT subsystem will perform this test. Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Sections 15.6.5.
: 2. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station          B 3.6.4.1-6                                      Revision 73
 
SCIVs B 3.6.4.2 BASES SURVEILLANCE        SR 3.6.4.2.1 REQUIREMENTS This SR verifies each secondary containment isolation manual valve and blind flange that is not locked, sealed, or otherwise secured, 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 secondary containment boundary is within design limits. This SR does not require any testing or valve manipulation. Rather, it involves verification that those SCIVs in secondary containment that are capable of being mispositioned are in the correct position.
Since these SCIVs are readily accessible to personnel during normal unit operation and verification of their position is relatively easy, the 31 day Frequency was chosen to provide added assurance that the SCIVs are in the correct positions.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing.
Two Notes have been added to this SR. The first 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 isolation devices, once they have been verified to be in the proper position, is low.
A second Note has been included to clarify that SCIVs that are open under administrative controls are not required to meet the SR during the time the SCIVs are open. These controls consist of stationing a dedicated operator at the controls of the valve, who is in continuous communication with the control room. In this way, the penetration can be rapidly isolated when a need for secondary containment isolation is indicated.
SR 3.6.4.2.2 Verifying the isolation time of each power operated, automatic SCIV listed in Licensee Controlled Specification Table 1.6.4.2-1 is within limits is required to demonstrate OPERABILITY. The isolation time test ensures that the SCIV will isolate in a time period less than or equal to that assumed in the safety analyses. The Frequency of this SR is in accordance with the Inservice Testing Program.
Columbia Generating Station            B 3.6.4.2-5                                    Revision 73
 
SCIVs B 3.6.4.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.4.2.3 Verifying that each automatic SCIV closes on a secondary containment isolation signal is required to prevent leakage of radioactive material from secondary containment following a DBA or other accidents. This SR ensures that each automatic SCIV will actuate to the isolation position on a secondary containment isolation signal. The LOGIC SYSTEM FUNCTIONAL TEST in LCO 3.3.6.2, "Secondary Containment Isolation Instrumentation," 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 with the reactor at power. Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Section 15.6.5.
: 2. FSAR, Section 6.2.3.2.
: 3. 10 CFR 50.36(c)(2)(ii).
: 4. Licensee Controlled Specifications Manual.
Columbia Generating Station            B 3.6.4.2-6                                  Revision 73
 
SGT System B 3.6.4.3 BASES ACTIONS (continued)
C.1 and C.2 During OPDRVs, when Required Action A.1 cannot be completed within the required Completion Time, the OPERABLE SGT subsystem should be immediately placed in operation. This Required Action ensures that the remaining subsystem is OPERABLE, that no failures that could prevent automatic actuation will occur, and that any other failure would be readily detected.
An alternative to Required Action C.1 is to immediately suspend activities that represent a potential for releasing radioactive material to the secondary containment, thus placing the unit in a condition that minimizes risk. Action must be immediately initiated to suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential for fission product release. Action must continue until OPDRVs are suspended.
D.1 If both SGT subsystems are inoperable in MODE 1, 2, or 3, the SGT System may not be capable of supporting the required radioactive release control function. Therefore, actions are required to enter LCO 3.0.3 immediately.
E.1 When two SGT subsystems are inoperable, actions must be immediately initiated to suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential for fission product release. Action must continue until OPDRVs are suspended.
SURVEILLANCE        SR 3.6.4.3.1 REQUIREMENTS Operating (from the control room) each SGT subsystem for t 10 continuous hours 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. Operation with the heaters on (automatic heater cycling to maintain temperature) for t 10 continuous hours every 31 days eliminates moisture on the adsorbers and HEPA filters. The 31 day Frequency was developed in consideration of the known reliability of fan motors and controls and the redundancy available in the system.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station          B 3.6.4.3-4                                    Revision 73
 
SGT System B 3.6.4.3 BASES SURVEILANCE REQUIREMENTS (continued)
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. 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).
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 LCO 3.3.6.2, "Secondary Containment Isolation Instrumentation," overlaps this SR to provide complete testing of the safety function. While this Surveillance can be performed with the reactor at power, operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.6.4.3.4 This SR requires verification that the primary SGT filter cooling recirculation valve can be opened and the primary fan started. This ensures that the ventilation mode of SGT System operation is available.
While this Surveillance can be performed with the reactor at power, operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. 10 CFR 50, Appendix A, GDC 41.
: 2. FSAR, Section 6.5.1.2.
: 3. FSAR, Section 15.6.5.
: 4. 10 CFR 50.36(c)(2)(ii).
: 5. Regulatory Guide 1.52, Rev. 2.
Columbia Generating Station          B 3.6.4.3-5                                    Revision 73
 
SW System and UHS B 3.7.1 BASES ACTIONS (continued)
C.1 and C.2 If the SW subsystem cannot be restored to OPERABLE status within the associated Completion Time, or both SW subsystems are inoperable, or the UHS is determined inoperable for reasons other than Condition A, the unit must be placed in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed 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 unit conditions from full power conditions in an orderly manner and without challenging unit systems.
SURVEILLANCE        SR 3.7.1.1 REQUIREMENTS Verification of the UHS spray pond level ensures adequate long term (30 days) cooling can be maintained. The 24 hour Frequency is based on operating experience related to trending of the parameter variations during the applicable MODES.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.7.1.2 Verification of the UHS spray pond temperature ensures that the heat removal capability of the SW System is within the assumptions of the DBA analysis. The 24 hour Frequency is based on operating experience related to trending of the parameter variations during the applicable MODES.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.7.1.3 Verifying the correct alignment for each manual, power operated, and automatic valve in each SW subsystem flow path provides assurance that the proper flow paths will exist for SW 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 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.
Columbia Generating Station            B 3.7.1-5                                      Revision 73
 
SW System and UHS B 3.7.1 BASES SURVEILLANCE REQUIREMENTS (continued)
This SR is modified by a Note indicating that isolation of the associated SW subsystem to components or systems may render those components or systems inoperable, but does not affect the OPERABILITY of the SW subsystem. As such, when all SW pumps, valves, and piping are OPERABLE, but a branch connection off the main header is isolated, the SW subsystem 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 Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.7.1.4 Verification of the average sedimentation depth in each UHS spray pond ensures that adequate long term (30 days) cooling can be maintained.
The 92 day Frequency is based on operating experience related to trending of the sedimentation buildup.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.7.1.5 This SR verifies that the automatic isolation valves of the SW System will automatically switch to the safety or emergency position to provide cooling water exclusively to the safety related equipment during an accident event. This is demonstrated by use of an actual or simulated initiation signal. This SR also verifies the automatic start capability of the SW pump in each subsystem.
Operating experience has shown that these components usually pass the SR when performed on the 24 month Frequency. Therefore, this Frequency is concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.7.1-6                                    Revision 73
 
HPCS SW System B 3.7.2 BASES ACTIONS            A.1 When the HPCS SW System is inoperable, the capability of the HPCS System to perform its intended function cannot be ensured. Therefore, if the HPCS SW System is inoperable, the HPCS System must be declared inoperable immediately and the applicable Condition(s) of LCO 3.5.1, "ECCS - Operating," entered.
SURVEILLANCE        SR 3.7.2.1 REQUIREMENTS Verifying the correct alignment for each manual, power operated, and automatic valve in the HPCS SW System flow path provides assurance that the proper flow paths will exist for HPCS SW System operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these valves are 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 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.
This SR is modified by a Note indicating that isolation of the HPCS SW System to components or systems may render those components or systems inoperable, but does not affect the OPERABILITY of the HPCS SW System. As such, when the HPCS SW System pump and all valves and piping are OPERABLE, but a branch connection off the main header is isolated, the HPCS SW System 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 Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.7.2-2                                    Revision 73
 
HPCS SW System B 3.7.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.7.2.2 This SR verifies that the automatic valves of the HPCS SW System will automatically switch to the safety or emergency position to provide cooling water exclusively to the safety related equipment during an accident event. This is demonstrated by use of an actual or simulated initiation signal. This SR also verifies the automatic start capability of the HPCS SW pump.
Operating experience has shown that these components usually pass the SR when performed at the 24 month Frequency. Therefore, this Frequency is concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Section 9.2.7.
: 2. FSAR, Chapter 6.
: 3. FSAR, Chapter 15.
: 4. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.7.2-3                                    Revision 73
 
CREF System B 3.7.3 BASES SURVEILLANCE        SR 3.7.3.1 REQUIREMENTS Operating (from the control room) each CREF subsystem for t 10 continuous hours 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. Operation with the heaters on (automatic heater cycling to maintain humidity) for t 10 continuous hours every 31 days reduces moisture on the adsorbers and HEPA filters. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The 31 day Frequency was developed in consideration of the known reliability of fan motors and controls and the redundancy available in the system.
SR 3.7.3.2 This SR verifies that the required CREF testing is performed in accordance with the Ventilation Filter Testing Program (VFTP). The CREF filter tests are in accordance with Regulatory Guide 1.52 (Ref. 6).
The VFTP includes testing HEPA filter performance, charcoal adsorber efficiency, 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 3.7.3.3 This SR verifies that each CREF subsystem starts and operates on an actual or simulated initiation signal. This SR also includes ensuring the control room isolates (i.e., the normal intake dampers close and the exhaust fan trips and associated discharge damper closes). The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.7.1.4 overlaps this SR to provide complete testing of the safety function. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.The Frequency of 24 months is based on industry operating experience and is consistent with the typical refueling cycle. Therefore, the Frequency was found to be acceptable from a reliability standpoint.
SR 3.7.3.4 This SR verifies the OPERABILITY of the CRE boundary by testing for unfiltered air inleakage past the CRE boundary and into the CRE. The details of the testing are specified in the Control Room Envelope Habitability Program.
Columbia Generating Station            B 3.7.3-6                                    Revision 73
 
Control Room AC System B 3.7.4 BASES ACTIONS (continued)
E.1 During OPDRVs with two control room AC subsystems inoperable, action must be taken to immediately suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential for fission product release. Action must continue until the OPDRVs are suspended.
SURVEILLANCE        SR 3.7.4.1 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 analyses.
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.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Section 6.4.
: 2. FSAR, Section 9.4.1.
: 3. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.7.4-4                                  Revision 73
 
Main Condenser Offgas B 3.7.5 BASES ACTIONS            A.1 If the offgas radioactivity rate limit is exceeded, 72 hours is allowed to restore the gross gamma activity rate to within the limit. The 72 hour Completion Time is reasonable, based on engineering judgment considering the time required to complete the Required Action, the large margins associated with permissible dose and exposure limits, and the low probability of a Main Condenser Offgas System failure occurring.
B.1, B.2, B.3.1, and B.3.2 If the gross gamma activity rate is not restored to within the limits within the associated Completion Time, all main steam lines or the SJAE must be isolated. This isolates the Main Condenser Offgas System from significant sources of radioactive steam. The main steam lines are considered isolated if at least one main steam isolation valve in each main steam line is closed, and at least one main steam line drain valve in each drain line is closed. The 12 hour Completion Time is reasonable, based on operating experience, to perform the actions from full power conditions in an orderly manner and without challenging unit systems.
An alternative to Required Actions B.1 and B.2 is to place the unit in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed 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 unit conditions from full power conditions in an orderly manner and without challenging unit systems.
SURVEILLANCE        SR 3.7.5.1 REQUIREMENTS This SR, on a 31 day Frequency, requires an isotopic analysis of an offgas sample (taken at the discharge of the main condenser air ejector prior to dilution) to ensure that the required limits are satisfied. The noble gases to be sampled are Xe-133, Xe-135, Xe-138, Kr-85, Kr-87, and Kr-88. If the measured rate of radioactivity increases significantly (by t 50% after correcting for expected increases due to changes in THERMAL POWER), an isotopic analysis is also performed 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 31 day Frequency is adequate in view of other instrumentation that continuously monitor the offgas, and is acceptable based on operating experience.The Surveillance Frequency is controlled under the Surveillance Frequency 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 Columbia Generating Station              B 3.7.5-2                                      Revision 73
 
Main Turbine Bypass System B 3.7.6 BASES APPLICABILITY      The Main Turbine Bypass System is required to be OPERABLE at t 25% RTP to ensure that the fuel cladding integrity Safety Limit is not violated during the feedwater controller failure, maximum demand event.
As discussed in the Bases for LCO 3.2.2, sufficient margin to this limit exists < 25% RTP. Therefore, these requirements are only necessary when operating at or above this power level.
ACTIONS            A.1 If the Main Turbine Bypass System is inoperable (one or more bypass valves inoperable), and the MCPR limits for an inoperable Main Turbine Bypass System, as specified in the COLR, are not applied, the assumptions of the design basis transient analysis may not be met.
Under such circumstances, prompt action should be taken to restore the Main Turbine Bypass System to OPERABLE status or adjust the MCPR limits accordingly. The 2 hour Completion Time is reasonable, based on the time to complete the Required Action and the low probability of an event occurring during this period requiring the Main Turbine Bypass System.
B.1 If the Main Turbine Bypass System cannot be restored to OPERABLE status and the MCPR limits for an inoperable Main Turbine Bypass System are not applied, THERMAL POWER must be reduced to
                    < 25% RTP. As discussed in the Applicability section, operation at
                    < 25% RTP results in 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 3.7.6.1 REQUIREMENTS Cycling each main turbine bypass valve through one complete cycle 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.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.7.6-2                                    Revision 73
 
Main Turbine Bypass System B 3.7.6 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.7.6.2 The Main Turbine Bypass System is required to actuate automatically to perform its design function. This SR demonstrates that, with the required system initiation signals, the valves will actuate to their required position.
The 24 month Frequency is based on the need to perform this Surveillance under the 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 power. Operating experience has shown the 24 month Frequency, which is based on the refueling cycle, is acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.7.6.3 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 the Licensee Controlled Specifications Manual (Ref. 4). While this Surveillance can be performed with the reactor at power, operating experience has shown that these components usually pass the SR when performed at the 24 month Frequency, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Section 7.7.1.5.
: 2. FSAR, Section 15.1.2.
: 3. 10 CFR 50.36(c)(2)(ii).
: 4. Licensee Controlled Specifications Manual.
Columbia Generating Station            B 3.7.6-3                                      Revision 73
 
Spent Fuel Storage Pool Water Level B 3.7.7 BASES ACTIONS            A.1 LCO 3.0.3 is not applicable while in MODE 4 or 5. However, since irradiated fuel assembly movement can occur in MODE 1, 2, or 3, 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 the spent fuel storage pool level less than required, the movement of irradiated fuel assemblies in the spent fuel storage pool is suspended immediately.
Suspension 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 3.7.7.1 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 must be checked periodically. The 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.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Section 9.1.2.
: 2. FSAR, Section 15.7.4.
: 3. 10 CFR 50.67, "Accident Source Term."
: 4. Regulatory Guide 1.183, July 2000.
: 5. 10 CFR 50.36(cd)(2)(ii).
Columbia Generating Station            B 3.7.7-2                                      Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
These voltage tolerances for EDG steady state performance are conservative with respect to a minimum steady state voltage of 3740 V which is 90% of the nominal 4160 V output voltage. This value, which is specified in ANSI C84.1 (Ref. 187), allows for voltage drop to the terminals of 4000 V motors whose minimum operating voltage is specified as 90%, or 3600 V. It also allows for voltage drops to motors and other equipment down through the 120 V level, where minimum operating voltage is also usually specified as 90% of nameplate rating. A detailed description of the onsite Class 1E 4.16 kV ESF buses is found in FSAR chapter 8 (Ref. 2). The specified maximum steady state output voltage of 4400 V is equal to the maximum operating voltage specified for 4000 V motors. It ensures that for a lightly loaded distribution system, the voltage at the terminals of 4000 V motors is no more than the maximum rated operating voltages. Where the SRs discussed herein specify frequency tolerances the specified minimum and maximum frequencies of the DG are 58.8 Hz and 61.2 Hz, respectively. These values are equal to +/- 2% of the 60 Hz nominal frequency and are derived from the recommendations given in Safety Guide 9 (Ref. 5) and Regulatory Guide 1.9 (Ref. 12).
SR 3.8.1.1 This SR ensures proper circuit continuity for the offsite AC electrical power supply to the onsite distribution network and availability of offsite AC electrical power. The breaker alignment verifies that each breaker is in its correct position to ensure that distribution buses and loads are connected to their preferred power source and that appropriate independence of offsite circuits is maintained. The 7 day Frequency is adequate since breaker position is not likely to change without the operator being aware of it and because its status is displayed in the control room.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.8.1-16                                    Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
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 (Note 1 for SR 3.8.1.7 and Note 1 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 warmup 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.
In order to reduce stress and wear on diesel engines, the manufacturer recommends that the starting speed of DGs be limited, that warmup be limited to this lower speed, and that DGs be gradually accelerated to synchronous speed prior to loading. These start procedures are the intent of Note 2 to SR 3.8.1.2, which is only applicable when such procedures are recommended by the manufacturer.
SR 3.8.1.7 requires that, at a 184 day Frequency, the DG starts from standby conditions and achieves required voltage and frequency within 15 seconds. The 15 second start requirement supports the assumptions in the design basis LOCA analysis (Ref. 7). The 15 second start requirement may not be applicable to SR 3.8.1.2 (see Note 2 of SR 3.8.1.2), when a modified start procedure as described above is used.
If a modified start is not used, the 15 second start requirement of SR 3.8.1.7 applies.
The 31 day Frequency for SR 3.8.1.2 is consistent with Regulatory Guide 1.9 (Ref. 12). The 184 day Frequency for SR 3.8.1.7 is a reduction in cold testing consistent with Generic Letter 84-15 (Ref. 10). These Frequencies provide adequate assurance of DG OPERABILITY, while minimizing degradation resulting from testing.The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.8.1-17                                  Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.1.3 This Surveillance demonstrates that the DGs are capable of synchronizing and accepting a load approximately equivalent to that corresponding to the continuous rating. A 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 when running synchronized with the grid. Since the generator is rated at a particular kVA at 0.8 power factor, the 0.8 value is the design rating of the machine. The 1.0 is an operational condition where the reactive power component is zero, which minimizes the reactive heating of the generator. Operating the generator at a power factor between 0.8 lagging and 1.0 avoids adverse conditions associated with underexciting the generator and more closely represents the generator operating requirements when performing its safety function (running isolated on its associated ESF bus). The load band is provided to avoid routine overloading of the DG. Routine overloading may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY.
The 31 day Frequency for this Surveillance is consistent with Regulatory Guide 1.9 (Ref. 12).The Surveillance Frequency is controlled under the Surveillance Frequency Control 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 because of changing bus loads do not invalidate this test.
Note 3 indicates that this Surveillance must 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.
Columbia Generating Station            B 3.8.1-18                                  Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
Note 5 stipulates that performance of the endurance test of SR 3.8.1.14 can be used to satisfy the requirements of SR 3.8.1.3. The upper load limits of SR 3.8.1.3 may be exceeded provided the remaining requirements of SR 3.8.1.3 are met. The reason for this allowance is to avoid having to perform an unnecessary test on the DG.
SR 3.8.1.4 This SR ensures that the volume of fuel oil in the day tank provides for DG operation for a minimum of one hour at full load plus 10%. The minimum amount of fuel oil required to satisfy one hour at 110%
correlates to 390 gallons for the Division 1 DG, 397 gallons for the Division 2 DG, and 231 gallons for the Division 3 DG. The day tank low level alarm is set at 1400 gallons for all three DGs, which is higher than the above specified minimum required values. The volume of fuel that constitutes the differential from the alarm set point and the one hour at 110% discussed above is utilized to support the 7 day and 6 day fuel oil storage requirements (see Bases for SR 3.8.3.1). For DGs 1 and 2, 1400 gallons supports approximately 3.5 hours of operation at 110% of continuous rated load. For DG-3, 1400 gallons supports approximately 7 hours of operation at continuous rated load. The 31 day Frequency is adequate to assure that a sufficient supply of fuel oil is available, since low level alarms are provided and facility operators would be aware of any large uses of fuel oil during this period.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
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 Rremoval of water from the fuel oil day tanks once every 31 days eliminates the necessary environment for bacterial survival. This is the most effective means in 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, rain water, contaminated fuel oil, and breakdown of the fuel oil by bacteria. Frequent checking for and removal of accumulated water minimizes fouling and provides data regarding the watertight integrity of the fuel oil system. The Surveillance Frequency is established by Regulatory Guide 1.137 (Ref. 14). The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. This SR is for preventive maintenance. The presence of water does not necessarily represent a Columbia Generating Station            B 3.8.1-19                                      Revision 73
 
AC Sources - Operating B 3.8.1 failure of this SR provided that accumulated water is removed during performance of this Surveillance.
Columbia Generating Station            B 3.8.1-20                                Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.1.6 This Surveillance demonstrates that each required fuel oil transfer pump operates and automatically 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 Frequency for this SR corresponds to the testing requirements for pumps as contained in the ASME OM Code (Ref. 16).The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.8.1.8 Transfer of Division 1 and 2 4.16 kV ESF buses (SM-7 and SM-8) power supply from the startup offsite circuit to the backup offsite circuit demonstrates the OPERABILITY of the alternate circuit distribution network to power the Division 1 and 2 shutdown loads.
The 24 month Frequency of the Surveillance is based on engineering judgment taking into consideration the plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths. Operating experience has shown that these components usually pass the SR when performed on the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
This SR is modified by a Note which applies to verification of the automatic transfer function. 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.
This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow the Surveillance to be performed for the purpose of re-establishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns) provided an assessment determines plant safety is maintained or enhanced. This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed Surveillance, a successful Surveillance, and a perturbation of the offsite or onsite system Columbia Generating Station            B 3.8.1-21                                      Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)                  continuation of SR 3.8.1.9 Testing performed for this SR is normally conducted with the DG being tested (and the associated safety-related and/or non safety-related distribution buses) connected to one offsite source, while the remaining safety-related (and associated non safety-related) distribution buses are aligned to the unit auxiliary transformers (or other offsite source). This minimizes the possibility of common cause failures resulting from offsite/grid voltage perturbations.
The 24 month Frequency takes into consideration the plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
This SR has been modified by two Notes. The reason for Note 1 is that credit may be taken for unplanned events that satisfy this SR. 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 must be performed at a power factor as close to the power factor of the single largest post-accident load as practicable.
The approximate analyzed power factor value is 0.92 for DG-1, 0.86 for DG-2, and 0.92 for DG-3. These power factors are representative of the actual single largest inductive load that the DGs could experience when running isolated from offsite power. Under certain conditions, however, Note 2 allows the Surveillance to be conducted at a power factor other than these single largest load values. These conditions occur when grid voltage is high, and the additional field excitation needed to get the power factor to these levels results in voltages on the emergency busses that are higher than recommended. Under these conditions, the power factor should be maintained as close as practicable to these values while still maintaining acceptable voltage limits on the emergency busses. In other circumstances, the grid voltage may be such that the DG excitation levels needed to obtain a power factor as close as practicable to the analyzed value of 0.92 for DG-1, 0.86 for DG-2, and 0.92 for DG-3 may not cause unacceptable voltages on the emergency busses, but the excitation levels are in excess of those recommended for the DG.
In such cases, the power factor shall be maintained as close a practicable to these levels, allowing margin for changing grid conditions, without exceeding the DG excitation limits.
Therefore, to ensure the DG is not placed in an unsafe condition during this test, the power factor limit does not have to be met if grid voltage does not permit the power factor limit to be met when the DG is tied to the grid. When this occurs, the power factor should be maintained as close to the limit as practicable.
Columbia Generating Station            B 3.8.1-24                                    Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
The requirements of SR 3.8.1.9 and SR 3.8.1.10 can be met with the performance of a single load reject test if the test methodology ensures that the acceptance criteria for both SRs is demonstrated.
SR 3.8.1.10 Consistent with Regulatory Guide 1.9 (Ref. 12), paragraph C.2.2.8, this Surveillance demonstrates the DG capability to reject a full 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 continues 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 at a power factor as close to the accident load power factor as practicable.
The approximate analyzed power factor limit is 0.89 for DG-1, 0.88 for DG-2, and 0.91 for DG-3. These power factors are representative of the actual design basis inductive loading that the DGs could experience when running isolated from offsite power.
Testing performed for this SR is normally conducted with the DG being tested (and the associated safety-related and/or non safety-related distribution buses) connected to one offsite source, while the remaining safety-related (and associated non safety-related) distribution buses are aligned to the unit auxiliary transformers (or other offsite source). This minimizes the possibility of common cause failures resulting from offsite/grid voltage perturbations.
The 24 month Frequency takes into consideration the plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.8.1-25                                    Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)              continuation of SR 3.8.1.11 LCO 3.3.8.1. 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 testing may include any series of sequential, overlapping, or total steps so that the entire connection and loading sequence is verified.
The Frequency of 24 months takes into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
This SR is modified by two Notes. 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. The reason for Note 2 is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge plant safety systems. This restriction from normally performing the Surveillance in MODE 1, 2, or 3 is further amplified to allow portions of the Surveillance to be performed for the purpose of re-establishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns) provided an assessment determines plant safety is maintained or enhanced.
This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed Surveillance, a successful partial Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the partial Surveillance; as well as the operator procedures available to cope with these outcomes.
These shall be measured against the avoided risk of plant shutdown and startup to determine that plant safety is maintained or enhanced when the Columbia Generating Station          B 3.8.1-27                                    Revision 73
 
AC Sources - Operating B 3.8.1 Surveillance is performed in MODE 1, 2, or 3. Risk insights or deterministic methods may be used for this assessment. If the Columbia Generating Station          B 3.8.1-28                                    Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued) assessment cannot demonstrate that plant safety is maintained or enhanced (i.e., that the proposed testing will not cause electrical perturbations that would challenge continued steady state operation or challenge plant safety systems), the Note shall not be invoked and the surveillance testing shall not be performed. Usage of the allowance of the Note shall be an invoked and the surveillance testing shall not be performed. Usage of the allowance of the Note shall be an infrequently performed test evolution. Credit may be taken for unplanned events that satisfy this SR.
SR 3.8.1.12 Consistent with Regulatory Guide 1.9 (Ref. 12), paragraph C.2.2.5, this Surveillance demonstrates that the DG automatically starts and achieves the required voltage and frequency within the specified time (15 seconds) from the design basis actuation signal (LOCA signal) and operates for t 5 minutes. The 5 minute period provides sufficient time to demonstrate stability. SR 3.8.1.12.d and SR 3.8.1.12.e ensure that permanently connected loads and emergency loads are energized from the offsite electrical power system on an ECCS signal without loss of offsite power.
The requirement to verify the connection and power supply of permanent and autoconnected loads is intended to satisfactorily show the relationship of these loads to the loading logic for loading onto offsite power. 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 testing may include any series of sequential, overlapping, or total steps so that the entire connection and loading sequence is verified.
The Frequency of 24 months takes into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with the expected fuel cycle lengths.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station          B 3.8.1-29                                    Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)              continuation of SR 3.8.1.13 concurrent with an ECCS initiation test signal and critical protective functions (engine overspeed, generator differential current, and incomplete starting sequence) trip the DG to avert substantial damage to the DG unit. The non-critical trips are bypassed during DBAs and provide an alarm on an abnormal engine condition. This alarm provides the operator with sufficient time to react appropriately.
The DG availability to mitigate the DBA is more critical than protecting the engine against minor problems that are not immediately detrimental to emergency operation of the DG.
The 24 month Frequency is based on engineering judgment, taking into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
The SR is modified by a Note. The reason for the Note is that credit may be taken for unplanned events that satisfy this SR.
SR 3.8.1.14 Consistent with Regulatory Guide 1.9 (Ref. 12), paragraph C.2.2.9, this Surveillance requires demonstration that the DGs can start and run continuously at full load capability for an interval of not less than 24 hours, 22 hours of which is at a load equivalent to 90% to 100% of the continuous rating of the DG and 2 hours of which is at a load equivalent to 105% to 110% of the continuous duty rating of the DG. The DG starts for this Surveillance can be performed either 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 at a power factor as close to the accident load power factor as practicable.
The approximate analyzed power factor value is 0.89 for DG-1, 0.88 for DG-2, and 0.91 for DG-3. These power factors are representative of the actual design basis inductive loading that the DGs could experience when running isolated from offsite power.
Columbia Generating Station            B 3.8.1-31                                      Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
Testing performed for this SR is normally conducted with the DG being tested (and the associated safety-related and/or non safety-related distribution buses) connected to one offsite source, while the remaining safety-related (and associated non safety-related) distribution buses are aligned to the unit auxiliary transformers (or other offsite source). This minimizes the possibility of common cause failures resulting from offsite/grid voltage perturbations.
The 24 month Frequency takes into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
This Surveillance is modified by three Notes. Note 1 states that momentary transients due to changing bus loads do not invalidate this test. The load band is provided to avoid routine overloading of the DG.
Routine overloading may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY. Similarly, momentary transients of excitation current or power factor do not invalidate the test. The reason for Note 2 is that credit may be taken for unplanned events that satisfy this SR. Note 3 ensures that the DG is tested under load conditions that are as close to design basis conditions as practicable. When synchronized with offsite power, testing should be performed as close as practicable to the analyzed value of the accident load power factor of 0.89 for DG-1, 0.88 for DG-2, and 0.91 for DG-3. This power factor is representative of the actual inductive loading of DG would see under design bases accident conditions. Under these conditions, the power factor should be maintained as close as practicable to these levels while still maintaining acceptable voltage limits on the emergency busses. In other circumstances, the grid voltage may be such that the DG excitation levels needed to obtain power factors of these levels may not cause unacceptable voltages on the emergency busses, but the excitation levels are in excess of those recommended for the DG. In such cases, the power factor shall be maintained as close a practicable to these levels, allowing margin for changing grid conditions, without exceeding the DG excitation limits.
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 15 seconds. The 15 second time is derived from the requirements of the Columbia Generating Station            B 3.8.1-32                                    Revision 73
 
AC Sources - Operating B 3.8.1 accident analysis for responding to a design basis large break LOCA (Ref. 7).
Columbia Generating Station          B 3.8.1-33                                  Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
The 24 month Frequency takes into consideration the plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
This SR has been modified by two Notes. Note 1 ensures that the test is performed with the diesel sufficiently hot. The requirement that the diesel has operated for at least 1 hour at full load conditions prior to performance of this Surveillance is based on manufacturer recommendations for achieving hot conditions. Momentary transients due to changing bus loads do not invalidate this test. Note 2 allows all DG starts to be preceded by an engine prelube period to minimize wear and tear on the diesel during testing.
SR 3.8.1.16 Consistent with Regulatory Guide 1.9 (Ref. 12), paragraph C.2.2.11, this Surveillance ensures that the manual synchronization and load transfer from the DG to the offsite source can be made and that the DG can be returned to ready-to-load status when offsite power is restored. It also ensures that the auto-start 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 individual load timers are reset.
The Frequency of 24 months takes into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycles.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
This SR is modified by a Note. 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.
This restriction from normally performing the Surveillance in MODE 1, 2, or 3 is further amplified to allow the Surveillance to be performed for the purpose of re-establishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns) provided an assessment determines plant safety is maintained or enhanced.
Columbia Generating Station            B 3.8.1-34                                    Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed Surveillance, a successful Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the Surveillance; as well as the operator procedures available to cope with these outcomes.
These shall be measured against the avoided risk of plant shutdown and startup to determine that plant safety is maintained or enhanced when the Surveillance is performed in MODE 1, 2, or 3. Risk insights or deterministic methods may be used for this assessment. If the assessment cannot demonstrate that plant safety is maintained or enhanced (i.e., that the proposed testing will not cause electrical perturbations that would challenge continued steady state operation or challenge plant safety systems), the Note shall not be invoked and the surveillance testing shall not be performed. Usage of the allowance of the Note shall be an infrequently performed test evolution. Credit may be taken for unplanned events that satisfy this SR.
SR 3.8.1.17 Consistent with Regulatory Guide1.9 (Ref. 12), paragraph C.2.2.13, demonstration of the parallel 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. 176), paragraph 6.2.6(2).
The requirement to automatically energize the emergency loads with offsite power is essentially identical to that of SR 3.8.1.12. The intent in the requirement associated with SR 3.8.1.17.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 sequential, overlapping, or total steps so that the entire connection and loading sequence is verified.
Columbia Generating Station            B 3.8.1-35                                    Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
Testing performed for this SR is normally conducted with the DG being tested (and the associated safety-related and/or non safety-related distribution buses) connected to one offsite source, while the remaining safety-related (and associated non safety-related) distribution buses are aligned to the unit auxiliary transformers (or other offsite source). This minimizes the possibility of common cause failures resulting from offsite/grid voltage perturbations.
The 24 month Frequency takes into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.The Surveillance Frequency is controlled under the Surveillance Frequency Control 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.
SR 3.8.1.18 Under accident conditions, loads are sequentially connected to the bus by the automatic load sequence time delay relays. The sequencing logic controls the permissive and starting signals to motor breakers to prevent overloading of the DGs due to high motor starting currents. The 10% load sequence time interval tolerance ensures that a sufficient time interval exists for the DG to restore frequency and voltage prior to applying the next load and that safety analysis assumptions regarding ESF equipment time delays are not violated. Reference 2 provides a summary of the automatic loading of ESF buses. Since only DG-1 and DG-2 have more than one load block, this SR is only applicable to these DGs.
The Frequency of 24 months takes into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. This SR is modified by a Note. 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. This restriction from normally performing the Surveillance in MODE 1, 2, or 3 is further amplified to allow the Surveillance to be performed for the purpose of re- establishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns) provided an assessment determines plant safety is maintained or enhanced. This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed Columbia Generating Station            B 3.8.1-36                                    Revision 73
 
AC Sources - Operating B 3.8.1 Surveillance, a successful Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the Surveillance; as well Columbia Generating Station          B 3.8.1-37                                    Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued) as the operator procedures available to cope with these outcomes.
These shall be measured against the avoided risk of plant shutdown and startup to determine that plant safety is maintained or enhanced when the Surveillance is performed in MODE 1, 2, or 3. Risk insights or deterministic methods may be used for this assessment. If the assessment cannot demonstrate that plant safety is maintained or enhanced (i.e., that the proposed testing will not cause electrical perturbations that would challenge continued steady state operation or challenge plant safety systems), the Note shall not be invoked and the surveillance testing shall not be performed. Usage of the allowance of the Note shall be an invoked and the surveillance testing shall not be performed. Usage of the allowance of the Note shall be an infrequently performed test evolution. Credit may be taken for unplanned events that satisfy this SR.
SR 3.8.1.19 In the event of a DBA 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 3.8.1.11, during a loss of offsite power actuation test signal in conjunction with an ECCS initiation signal. Since the DG-3 Loss of Voltage - Time Delay Function is bypassed during an ECCS initiation signal, a 15 second DG-3 start time applies, consistent with the DBA LOCA analysis (Ref. 7). 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, overlapping, or total steps so that the entire connection and loading sequence is verified.
The Frequency of 24 months takes into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with an expected fuel cycle length.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
This SR is modified by two Notes. 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. The reason for Note 2 is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge plant safety systems. This restriction from normally performing the Surveillance in MODE 1, 2, or 3 is further amplified to allow portions of Columbia Generating Station          B 3.8.1-38                                    Revision 73
 
AC Sources - Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued) the Surveillance to be performed for the purpose of re-establishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns) provided an assessment determines plant safety is maintained or enhanced.
This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed Surveillance, a successful partial Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the partial Surveillance; as well as the operator procedures available to cope with these outcomes.
These shall be measured against the avoided risk of plant shutdown and startup to determine that plant safety is maintained or enhanced when the Surveillance is performed in MODE 1, 2, or 3. Risk insights or deterministic methods may be used for this assessment. If the assessment cannot demonstrate that plant safety is maintained or enhanced (i.e., that the proposed testing will not cause electrical perturbations that would challenge continued steady state operation or challenge plant safety systems), the Note shall not be invoked and the surveillance testing shall not be performed. Usage of the allowance of the Note shall be an invoked and the surveillance testing shall not be performed. Usage of the allowance of the Note shall be an infrequently performed test evolution. Credit may be taken for unplanned events that satisfy this SR.
SR 3.8.1.20 This Surveillance demonstrates that the DG starting independence has not been compromised. Also, this Surveillance demonstrates that each engine can achieve proper speed within the specified time when the DGs are started simultaneously.
The 10 year Frequency is consistent with the recommendations of Regulatory Guide 1.9 (Ref. 12), paragraph C.2.2.14.The Surveillance Frequency is controlled under the Surveillance Frequency Control 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.
Columbia Generating Station          B 3.8.1-39                                    Revision 73
 
AC Sources - Operating B 3.8.1 BASES REFERENCES        1. 10 CFR 50, Appendix A, GDC 17.
: 2. FSAR, Chapter 8.
: 3. Deleted.
: 4. FSAR, Tables 8.3-1, 8.3-2, and 8.3-3.
: 5. Safety Guide 9, Revision 0, March 1971.
: 6. FSAR, Chapter 6.
: 7. FSAR, Chapter 15.
: 8. 10 CFR 50.36(c)(2)(ii).
: 9. Regulatory Guide 1.93, Revision 0, December 1974.
: 10. Generic Letter 84-15, July 2, 1984.
: 11. 10 CFR 50, Appendix A, GDC 18.
: 12. Regulatory Guide 1.9, July 1993.
: 13. Regulatory Guide 1.108, Revision 1, August 1977.
: 14. Regulatory Guide 1.137, Revision 1, October 1979.
: 15. Calculations Nos. E/I-02-87-07 and 2-12-58.
: 16. ASME Code for Operation and Maintenance of Nuclear Power Plants.
176. IEEE Standard 308-1974.
178. ANSI C84.1, 1982.
189. Letter, GO2-13-043, Request for Technical Specification Interpretation Regarding the Offsite Power Supplies to the Onsite Class 1E AC Power Distribution System.
Columbia Generating Station          B 3.8.1-40                                  Revision 76
 
Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE        SR 3.8.3.1 REQUIREMENTS This SR provides verification that there is an adequate inventory of fuel oil in the storage subsystem to support each DGs operation for 7 days at full load. The fuel oil storage subsystem for each DG consist of the respective fuel storage tank and the volume in the day tank that is in excess of 1 hour at full load plus 10 % (see Bases for SR 3.8.1.4) Table B 3.8.3-1 specifies the fuel oil level equivalent to a 7 day supply for each storage subsystem when calculated in accordance with References 2, and 3. The required fuel storage volume is determined using the most limiting energy content of the stored fuel. Using the known correlation of diesel fuel oil absolute specific gravity or API gravity to energy content, the required diesel generator output, and the corresponding fuel consumption rate, the onsite fuel storage volume required for 7 days or operation can be determined. SR 3.8.3.3 requires new fuel to be tested in accordance with ASTM D975-08 (Ref. 7) to verify that the new fuel absolute specific gravity or API gravity is within the range assumed in the diesel fuel oil consumption calculations. 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 low level alarms are provided and unit operators would be aware of any large uses of fuel oil during this period.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.8.3.2 This Surveillance ensures that sufficient lube oil inventory (combined inventory in the DG lube oil sump(s) and in the warehouse) is available to support at least 7 days of full load operation for each DG. The lube oil level equivalent to a 7 day supply is 330 gallons for Division 1 or 2 DG, and 165 gallons for a Division 3 DG. The lube oil level equivalent to a 7 day supply is 330 gallons for Division 1 or 2 DG, and 165 gallons for Division 3 DG. The 330 gallon requirement for Divisions 1 and 2 DGs and the 165 gallon requirement for Division 3 DG are based on the DG manufacturer's consumption values for the run time of the DG. Normally, sufficient volume is maintained in the DG lube oil sump(s). However, 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(s) do not hold adequate inventory for 7 days of full load operation without the level reaching the manufacturer's recommended minimum level.
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 Columbia Generating Station            B 3.8.3-6                                      Revision 73
 
Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 staff.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.8.3-7                                  Revision 73
 
Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE REQUIREMENTS (continued)
Testing Program, to be performed within 31 days following sampling and addition. This 31 day requirement is intended to assure that:
: a.      The new fuel oil sample taken is no more than 31 days old at the time of adding the new fuel oil to the DG storage tank; and
: b.      The results of the new fuel oil sample are obtained within 31 days after addition of the new fuel oil to the DG storage tank.
The 31 day period is acceptable because the fuel oil properties of interest, even if not within stated limits, would not have an immediate effect on DG operation. This Surveillance ensures the availability of high quality fuel oil for the DGs.
Fuel oil degradation during long term storage shows up as an increase in particulate, mostly due to oxidation. The presence of particulate does not mean that the fuel oil will not burn properly in a diesel engine. However, the particulate can cause fouling of filters and fuel oil injection equipment, which can cause engine failure.
Particulate concentrations should be determined in accordance with ASTM D5452-06 (Ref. 7). This method involves a gravimetric determination of total particulate concentration in the fuel oil and has a limit of 10 mg/l. It is acceptable to obtain a field sample for subsequent laboratory testing in lieu of field testing.
The Frequency of this Surveillance takes into consideration fuel oil degradation trends indicating that particulate concentration 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. The system design requirements provide for a minimum of five engine start cycles for Division 1 and 2 DGs and three engine start cycles for the Division 3 DG without recharging. The pressure specified in this SR is intended to reflect the lowest value at which the five or three starts, as applicable, can be accomplished.
The 31 day Frequency takes into account the capacity, capability, redundancy, and diversity of the AC sources and other indications available in the control room, including alarms, to alert the operator to below normal air start pressure.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station              B 3.8.3-9                                      Revision 73
 
Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE REQUIREMENTS (continued)
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 Rremoval of water from the storage tanks once every 92 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, rain water, contaminated fuel oil, and from breakdown of the fuel oil by bacteria.
Frequent checking for and removal of accumulated water minimizes fouling and provides data regarding the watertight integrity of the fuel oil system. The Surveillance Frequency is established by Regulatory Guide 1.137 (Ref. 2) and is 92 days since the ground water table is lower than the bottom of the fuel oil storage tanks.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. This SR is for preventive maintenance. The presence of water does not necessarily represent a failure of this SR provided that accumulated water is removed during performance of the Surveillance.
REFERENCES          1. FSAR, Section 9.5.4.
: 2. Regulatory Guide 1.137, Revision 1, October 1979.
: 3. ANSI N195, Appendix B, 1976.
: 4. FSAR, Chapter 6.
: 5. FSAR, Chapter 15.
: 6. 10 CFR 50.36(c)(2)(ii).
: 7. ASTM Standards: D4057-06; D975-08; D1298-99; D4176-04; D2709-96; D2622-94; D4294-08; D5453-08; D3120-06; D5452-06.
Columbia Generating Station          B 3.8.3-10                                      Revision 73
 
DC Sources - Operating B 3.8.4 BASES ACTIONS (continued)
J.1 and J.2 If the inoperable Division 1 or Division 2 125 VDC electrical power subsystem 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 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.
The Completion Time to bring the unit to MODE 4 is consistent with the time specified in Regulatory Guide 1.93 (Ref. 10).
SURVEILLANCE        SR 3.8.4.1 REQUIREMENTS Verifying battery terminal voltage while on float charge helps to ensure the effectiveness of the battery chargers, which support 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 and maintain the battery in a fully charged state while supplying the continuous steady state loads of the associated DC subsystem. On float charge, battery cells will receive adequate current to optimally charge the battery. The voltage requirements are based on the nominal design voltage of the battery and are consistent with the minimum float voltage established by the battery manufacturer 2.17 Vpc or 126.0 V for the 125 V batteries and 252.0 V for the 250 V battery at the battery terminals. This voltage maintains the battery plates in a condition that supports maintaining the grid life (expected to be approximately 20 years). The 7 day Frequency is conservative when compared with the manufacturer's recommendations.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.8.4.2 Battery charger capability requirements are based on the design capacity of the chargers (Ref. 4). According to Regulatory Guide 1.32 (Ref. 12),
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 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. The charger shall be Columbia Generating Station            B 3.8.4-8                                      Revision 73
 
DC Sources - Operating B 3.8.4 BASES SURVEILLANCE REQUIREMENTS (continued) loaded, to a minimum, at three separate and sequential load ratings, 50%, 75%, and 100%, for > 30 minutes at each load rating. The 100%
load rating for the Divisions 1 and 2 125 V battery chargers is 200 amps, for the Division 3 125 V battery charger is 50 amps, and for the Division 1 250 V battery charger is 400 amps.
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 with expected fuel cycle lengths.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.8.4.3 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.
The Surveillance Frequency of 24 months is acceptable, given unit conditions required to perform the test and the other requirements existing to ensure adequate battery performance during these 24 month intervals. In addition, this Frequency is intended to be consistent with expected fuel cycle lengths.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
This SR is modified by two Notes. Note 1 allows the performance of a modified performance discharge test in lieu of a service test. This substitution is acceptable because a modified performance discharge test represents a more severe test of battery capacity than SR 3.8.4.3. 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. Credit may be taken for unplanned events that satisfy the Surveillance.
Columbia Generating Station            B 3.8.4-9                                      Revision 73
 
Battery Parameters B 3.8.6 BASES SURVEILLANCE REQUIREMENTS (continued)                continuation of SR 3.8.6.1 of time. The 7 day frequency is adequate to ensure the battery is capable of performing its design function.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. A measuring device accuracy of + 10% of reading is adequate to verify float current to be within nominal values.
This SR is modified by a Note that states the float current requirement is not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1. When this float voltage is not maintained, the Required Action of LCO 3.8.4 ACTION A are being taken, which provide the necessary and appropriate verifications of the battery condition. Furthermore, the float current limit of 2 amps is established based on the nominal float voltage value and is not directly applicable when the voltage is not maintained.
SR 3.8.6.2 and SR 3.8.6.5 Optimal long term battery performance is obtained by maintaining a float voltage greater than or equal to the minimum established design limits provided by the battery manufacturer, which corresponds to 126.0 V for the 125 V batteries and 252.0 V for the 250 V battery at the battery terminals, or 2.17 Vpc. This provides adequate over-potential, which limits the formation of lead sulfate and self discharge, which could eventually render the battery inoperable. Float voltage in this range or less, but greater than 2.07 Vpc, are addressed in Technical Specification 5.5.13. SRs 3.8.6.2 and 3.8.6.5 require verification that the cell float voltages are equal to or greater than the short term absolute minimum voltage of 2.07 V. The verification of individual cell voltage readings every 31 days for the pilot cell and 92 days for all cells is consistent with the manufacturers recommendations.The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
SR 3.8.6.3 The minimum established design limit for electrolyte level is the low level mark. This limit ensures that the plates suffer no physical damage and maintains adequate electron transfer capability. The verification of cell electrolyte level every 31 days is consistent with the manufacturers recommendation.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
Columbia Generating Station            B 3.8.6-6                                      Revision 73
 
Battery Parameters B 3.8.6 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.6.4 This Surveillance verifies that the pilot cell temperature is greater than or equal to the minimum established design limit (i.e., 60&deg;F). Pilot cell electrolyte temperature is maintained above this temperature to assure the battery can provide the required current and voltage to meet the design requirements. Temperatures lower than assumed in battery sizing calculations may act to inhibit or reduce battery capacity. The verification of the pilot cell temperature every 31 days is consistent with the manufacturers recommendations.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.8.6.6 A battery performance discharge 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.
Either the battery performance discharge test or the modified performance discharge test is acceptable for satisfying SR 3.8.6.6; however, only the modified performance discharge test may be used to satisfy the battery service test requirements of SR 3.8.4.3.
A modified performance discharge test is a test of the battery capacity and its ability to provide a high rate, short duration load (usually the highest rate of the duty cycle). This will often confirm the battery's ability to meet the critical period of the load duty cycle, in addition to determining its percentage of rated capacity. Initial conditions for the modified performance discharge test should be identical to those specified for a service test when the modified performance discharge test is performed in lieu of a service test.
A battery modified performance discharge test is a simulated duty cycle normally consisting of just two rates; the one minute rate published for the battery or the largest current load of the duty cycle, followed by the test rate employed for the performance discharge test, both of which envelope the duty cycle of the service test. Since the ampere-hours removed at a rated one minute discharge represents a very small portion of the battery capacity, the test rate can be changed to that for the performance test without compromising the results of the performance discharge test. The battery terminal voltage for the modified performance discharge test must remain above the minimum battery terminal voltage specified in the Columbia Generating Station            B 3.8.6-7                                      Revision 73
 
Battery Parameters B 3.8.6 battery service test for the duration of time equal to that of the service test.
Columbia Generating Station          B 3.8.6-8                                        Revision 73
 
Battery Parameters B 3.8.6 BASES SURVEILLANCE REQUIREMENTS (continued)
The acceptance criteria for this Surveillance are consistent with IEEE 485 (Ref. 5) for the 125 V batteries. This reference recommends that the battery be replaced if its capacity is below 80% of the manufacturer's rating, since IEEE 485 (Ref. 5) recommends using an aging factor of 125% in the battery sizing calculations. The acceptance criteria for this Surveillance for the 250 V battery is consistent with Reference 6. This reference recommended that the battery be replaced if its capacity is below 83.4% of the manufacturer's rating in lieu of Reference 5 recommendation of 80%, since the battery sizing calculation in Reference 6 uses an aging factor of 120%. A capacity of 80% for the 125 V battery and 83.4% for the 250 V battery shows that the battery rate of deterioration is increasing even if there is ample capacity to meet the load requirements. Furthermore, the battery is sized to meet the assumed duty cycle loads when the battery design capacity reaches this 80% limit.
The Surveillance Frequency for this test is normally 60 months.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. If the battery shows degradation, or if the battery has reached 85% of its expected life and capacity is < 100% of the manufacturer's rating, the Surveillance Frequency is reduced to 12 months. However, if the battery shows no degradation but has reached 85% of its expected life, the Surveillance Frequency is only reduced to 24 months for batteries that retain capacity > 100% of the manufacturer's rating. Degradation is indicated, when the battery capacity drops by more than 10% relative to its previous performance test or when it is below 90% of the manufactures rating. This is consistent with the normal aging curve for lead-acid batteries because at 90% (or a 10% change), the slope of the aging curve has started to increase. For the 250 V battery, degradation is indicated when it is below 93.4% of the manufacturer's rating in lieu of 90%. This ensures the accelerated testing schedule is implemented when the 250 V battery capacity decreases to 10% above the capacity at which the battery must be replaced (consistent with the 125 V batteries), since the 250 V battery must be replaced when the capacity falls to 83.4%. The 12 month and 60 month Frequencies are consistent with the normal aging curve of lead-acid batteries. The 24 month Frequency is also derived from the aging curve.
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. This restriction from normally performing the Surveillance in MODE 1, 2, or 3 is further amplified to allow portions of the Surveillance to be performed for the purpose of re-establishing OPERABILITY (e.g., post work testing following corrective maintenance, Columbia Generating Station            B 3.8.6-9                                      Revision 80
 
Distribution Systems - Operating B 3.8.7 BASES ACTIONS (continued)
E.1 With the Division 3 electrical power distribution system inoperable, the Division 3 powered systems are not capable of performing their intended functions. Immediately declaring the High Pressure Core Spray System 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 power 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 3.8.7.1 REQUIREMENTS This Surveillance verifies that the AC and DC 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 power is available to each required bus. The verification of energization of the buses ensures that the required power is readily available for motive as well as control functions for critical system loads connected to these buses. This may be performed by verification of absence of low voltage alarms or by verifying a load powered from the bus is operating.
The 7 day Frequency takes into account the redundant capability of the AC and DC electrical power distribution subsystems, and other indications available in the control room that alert the operator to subsystem malfunctions.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Chapter 6.
: 2. FSAR, Chapter 15.
: 3. 10 CFR 50.36(c)(2)(ii).
: 4. Regulatory Guide 1.93, December 1974.
Columbia Generating Station          B 3.8.7-7                                      Revision 73
 
Distribution Systems - Shutdown B 3.8.8 BASES ACTIONS (continued)
Suspension of these activities shall not preclude completion of actions to establish a safe conservative condition. These actions minimize the probability of the occurrence of postulated events. It is further required to immediately initiate action to restore the required AC and DC electrical power distribution subsystems and to continue this action until restoration is accomplished in order to provide the necessary power to the plant safety systems.
Notwithstanding performance of the above conservative Required Actions, a required residual heat removal-shutdown cooling (RHR-SDC) subsystem may be inoperable. In this case, Required Actions A.2.1 and A.2.2 do not adequately address the concerns relating to coolant circulation and heat removal. Pursuant to LCO 3.0.6, the RHR-SDC ACTIONS would not be entered. Therefore, Required Action A.2.3 is provided to direct declaring RHR-SDC inoperable, which results in taking the appropriate RHR-SDC ACTIONS.
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 3.8.8.1 REQUIREMENTS This Surveillance verifies that the AC and DC electrical power distribution subsystems are functioning properly, with the correct breaker alignment.
The correct breaker alignment ensures power is available to each required bus. The verification of energization of the buses ensures that the required power is readily available for motive as well as control functions for critical system loads connected to these buses. This may be performed by verification of absence of low voltage alarms or by verifying a load powered from the bus is operating. The 7 day Frequency takes into account the redundant capability of the electrical power distribution subsystems, as well as other indications available in the control room that alert the operator to subsystem malfunctions.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Chapter 6.
: 2. FSAR, Chapter 15.
: 3. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.8.8-3                                    Revision 73
 
Refueling Equipment Interlocks B 3.9.1 BASES APPLICABILITY (continued)
In MODES 1, 2, 3, and 4, the reactor pressure vessel head is on, and no fuel loading activities are possible. Therefore, the refueling interlocks are not required to be OPERABLE in these MODES.
ACTIONS            A.1 With one or more of the required refueling equipment interlocks inoperable, the unit must be placed in a condition in which the LCO does not apply. In-vessel fuel movement with the affected refueling equipment must be immediately suspended. This action ensures that operations are not performed with equipment that would potentially not be blocked from unacceptable operations (e.g., loading fuel into a cell with a control rod withdrawn). Suspension of in-vessel fuel movement shall not preclude completion of movement of a component to a safe position.
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 channel is tested.
The 7 day Frequency is based on engineering judgment and is considered adequate in view of other indications of refueling interlocks and their associated input status that are available to unit operations personnel.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. 10 CFR 50, Appendix A, GDC 26.
: 2. FSAR, Section 7.7.1.13.
: 3. FSAR, Section 15.4.1.1.
: 4. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.9.1-3                                      Revision 73
 
Refuel Position One-Rod-Out Interlock B 3.9.2 BASES SURVEILLANCE REQUIREMENTS (continued) continuation of SR 3.9.2.1 The Frequency of 12 hours is sufficient in view of other administrative controls utilized during refueling operations to ensure safe operation.The Surveillance Frequency is controlled under 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. The 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 withdrawals, and visual and audible indications available in the control room to alert the operator of control rods not fully inserted.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. 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, SR 3.9.2.2 has been modified by a Note that states the CHANNEL FUNCTIONAL TEST is not required to be performed until 1 hour after any control rod is withdrawn.
REFERENCES          1. 10 CFR 50, Appendix A, GDC 26.
: 2. FSAR, Section 7.7.1.13.
: 3. FSAR, Section 15.4.1.1.
: 4. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station              B 3.9.2-3                                    Revision 73
 
Control Rod Position B 3.9.3 BASES APPLICABILITY      During MODE 5, loading fuel into core cells with control rods withdrawn may result in inadvertent criticality. Therefore, the control rods must be inserted before loading fuel into a core cell. All control rods must be inserted before loading fuel to ensure that a fuel loading error does not result in loading fuel into a core cell with the control rod withdrawn.
In MODES 1, 2, 3, and 4, the reactor pressure vessel head is on, and no fuel loading activities are possible. Therefore, this Specification is not applicable in these MODES.
ACTIONS            A.1 With all control rods not fully inserted during the applicable conditions, an inadvertent criticality could occur that is not analyzed in the FSAR. All fuel loading operations must be immediately suspended. Suspension of these activities shall not preclude completion of movement of a component to a safe position.
SURVEILLANCE        SR 3.9.3.1 REQUIREMENTS During refueling, to ensure that the reactor remains subcritical, all control rods must be fully inserted prior to and during fuel loading. Periodic checks of the control rod position ensure this condition is maintained.
The 12 hour Frequency takes into consideration the procedural controls on control rod movement during refueling as well as the redundant functions of the refueling interlocks.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. 10 CFR 50, Appendix A, GDC 26.
: 2. FSAR, Section 15.4.1.1.
: 3. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.9.3-2                                        Revision 73
 
Control Rod OPERABILITY - Refueling B 3.9.5 BASES APPLICABILITY (continued)
For MODES 1 and 2, control rod requirements are found in LCO 3.1.2, "Reactivity Anomalies," LCO 3.1.3, "Control Rod OPERABILITY,"
LCO 3.1.4, "Control Rod Scram Times," and LCO 3.1.5, "Control Rod Scram Accumulators." During MODES 3 and 4, control rods are not able to be withdrawn since the reactor mode switch is in shutdown and a control rod block is applied. This provides adequate requirements for control rod OPERABILITY during these conditions.
ACTIONS            A.1 With one or more withdrawn control rods inoperable, action must be immediately initiated to fully insert the inoperable control rod(s). Inserting the control rod(s) ensures that the shutdown and scram capabilities are not adversely affected. Actions must continue until the inoperable control rod(s) is fully inserted.
SURVEILLANCE        SR 3.9.5.1 and SR 3.9.5.2 REQUIREMENTS During MODE 5, the OPERABILITY of control rods is primarily required to ensure that a withdrawn control rod will automatically insert if a signal requiring a reactor shutdown occurs. Because no explicit analysis exists for automatic shutdown during refueling, the shutdown function is satisfied if the withdrawn control rod is capable of automatic insertion and the associated CRD scram accumulator pressure is t 940 psig.
The 7 day Frequency takes into consideration equipment reliability, procedural controls over the scram accumulators, and control room alarms and indicating lights that indicate low accumulator charge pressures.The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
SR 3.9.5.1 is modified by a Note that allows 7 days after withdrawal of the control rod to perform the Surveillance. This acknowledges that the control rod must first be withdrawn before performance of the Surveillance, 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. FSAR, Section 15.4.1.1.
: 3. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.9.5-2                                    Revision 73
 
RPV Water Level - Irradiated Fuel B 3.9.6 BASES APPLICABILITY      LCO 3.9.6 is applicable when moving irradiated fuel assemblies within the RPV. The LCO minimizes the possibility of a fuel handling accident in containment that is beyond the assumptions of the safety analysis. If irradiated fuel is not present within the RPV, there can be no significant radioactivity release as a result of a postulated fuel handling accident.
Requirements for handling of new fuel assemblies or control rods (where water depth to the RPV flange is not of concern) are covered by LCO 3.9.7, "RPV Water Level - New Fuel or Control Rods."
Requirements for fuel handling accidents in the spent fuel storage pool are covered by LCO 3.7.7, "Fuel Pool Water Level."
ACTIONS            A.1 If the water level is < 22 ft above the top of the RPV flange, all operations involving movement of irradiated fuel assemblies within the RPV shall be suspended immediately to ensure that a fuel handling accident cannot occur. The suspension of irradiated fuel movement shall not preclude completion of movement of a component to a safe position.
SURVEILLANCE        SR 3.9.6.1 REQUIREMENTS Verification of a minimum water level of 22 ft above the top of the RPV flange ensures that the design basis for the postulated fuel handling accident analysis during refueling operations is met. Water at the required level limits the consequences of damaged fuel rods, which are postulated to result from a fuel handling accident in containment (Ref. 2).
The Frequency of 24 hours is based on engineering judgment and is considered adequate in view of the large volume of water and the normal procedural controls on valve positions, which make significant unplanned level changes unlikely.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. Regulatory Guide 1.183, July 2000.
: 2. FSAR, Section 15.7.4.
: 3. 10 CFR 50.67, "Accident Source Term."
: 4. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.9.6-2                                    Revision 73
 
RPV Water Level - New Fuel or Control Rods B 3.9.7 BASES APPLICABILITY      LCO 3.9.7 is applicable when moving new fuel assemblies or handling control rods (i.e., movement with other than the normal control rod drive) over irradiated fuel assemblies seated within the RPV. The LCO minimizes the possibility of a fuel handling accident in containment that is beyond the assumptions of the safety analysis. If irradiated fuel is not present within the RPV, there can be no significant radioactivity release as a result of a postulated fuel handling accident. Requirements for fuel handling accidents in the spent fuel storage pool are covered by LCO 3.7.7, "Fuel Pool Water Level." Requirements for handling irradiated fuel over the RPV are covered by LCO 3.9.6, "Reactor Pressure Vessel (RPV) Water Level - Irradiated Fuel."
ACTIONS            A.1 If the water level is < 23 ft above the top of irradiated fuel assemblies seated within the RPV, all operations involving movement of new fuel assemblies and handling of control rods within the RPV shall be suspended immediately to ensure that a fuel handling accident cannot occur. The suspension of fuel movement and control rod handling shall not preclude completion of movement of a component to a safe position.
SURVEILLANCE        SR 3.9.7.1 REQUIREMENTS Verification of a minimum water level of 23 ft above the top of the irradiated fuel assemblies seated within the RPV ensures that the design basis for the postulated fuel handling accident analysis during refueling operations is met. Water at the required level limits the consequences of damaged fuel rods, which are postulated to result from a fuel handling accident in containment (Ref. 2).
The Frequency of 24 hours is based on engineering judgment and is considered adequate in view of the large volume of water and the normal procedural controls on valve positions, which make significant unplanned level changes unlikely.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. Regulatory Guide 1.183, July 2000.
: 2. FSAR, Section 15.7.4.
: 3. 10 CFR 50.67, "Accident Source Term."
: 4. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.9.7-2                                      Revision 73
 
RHR - High Water Level B 3.9.8 BASES ACTIONS (continued) in each associated penetration flow path not isolated that is assumed to be isolated to mitigate radioactive releases (i.e., one secondary containment isolation valve and associated instrumentation are OPERABLE or other acceptable administrative controls to assure isolation capability. These administrative controls consist of stationing a dedicated operator, who is in continuous communication with the control room, at the controls of the isolation device. In this way, the penetration can be rapidly isolated when a need for secondary containment isolation is indicated). This may be performed as an administrative check, by examining logs or other information to determine whether the components are out of service for maintenance or other reasons. It does not mean to perform the surveillances needed to demonstrate the OPERABILITY of the components. If, however, any required component is inoperable, then it must be restored to OPERABLE status. In this case, a surveillance may need to be performed to restore the component to OPERABLE status. Actions must continue until all required components are OPERABLE.
C.1 and C.2 If no RHR shutdown cooling subsystem is in operation, an alternate method of coolant circulation is required to be established within 1 hour.
The Completion Time is modified such that 1 hour is applicable separately for each occurrence involving a loss of coolant circulation.
During the period when the reactor coolant is being circulated by an alternate method (other than by the required RHR shutdown cooling subsystem), the reactor coolant temperature must be periodically monitored to ensure proper functioning of the alternate method. The once per hour Completion Time is deemed appropriate.
SURVEILLANCE        SR 3.9.8.1 REQUIREMENTS This Surveillance demonstrates that the required RHR shutdown cooling subsystem is in operation and circulating reactor coolant. The required flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability. The Frequency of 12 hours is sufficient in view of other visual and audible indications available to the operator for monitoring the RHR shutdown cooling subsystem in the control room.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. 10 CFR 50, Appendix A, GDC 34.
: 2. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.9.8-3                                    Revision 73
 
RHR - Low Water Level B 3.9.9 BASES ACTIONS (continued)
(i.e., one secondary containment isolation valve and associated instrumentation are OPERABLE or other acceptable administrative controls to assure isolation capability. These administrative controls consist of stationing a dedicated operator, who is in continuous communication with the control room, at the controls of the isolation device. In this way, the penetration can be rapidly isolated when a need for secondary containment isolation is indicated). This may be performed as an administrative check, by examining logs or other information to determine whether the components are out of service for maintenance or other reasons. It is not necessary to perform the surveillances needed to demonstrate the OPERABILITY of the components. If, however, any required component is inoperable, then it must be restored to OPERABLE status. In this case, the surveillance may need to be performed to restore the component to OPERABLE status. Actions must continue until all required components are OPERABLE.
C.1 and C.2 If no RHR shutdown cooling subsystem is in operation, an alternate method of coolant circulation is required to be established within 1 hour.
The Completion Time is modified such that the 1 hour is applicable separately for each occurrence involving a loss of coolant circulation.
During the period when the reactor coolant is being circulated by an alternate method (other than by the required RHR shutdown cooling subsystem), the reactor coolant temperature must be periodically monitored to ensure proper function of the alternate method. The once per hour Completion Time is deemed appropriate.
SURVEILLANCE        SR 3.9.9.1 REQUIREMENTS This Surveillance demonstrates that one RHR shutdown cooling subsystem is in operation and circulating reactor coolant. The required flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability. The Frequency of 12 hours is sufficient in view of other visual and audible indications available to the operator for monitoring the RHR shutdown cooling subsystem in the control room.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. 10 CFR 50, Appendix A, GDC 34.
: 2. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.9.9-3                                    Revision 73
 
Reactor Mode Switch Interlock Testing B 3.10.2 BASES ACTIONS (continued)
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. In addition, the all rods fully inserted Surveillance (SR 3.10.2.1) must be verified by a second licensed operator (Reactor Operator or Senior Reactor Operator) or other qualified member of the technical staff. The Surveillances performed at the 12 hour and 24 hour Frequencies are intended to provide appropriate assurance that each operating shift is aware of and verify compliance with these Special Operations LCO requirements.The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Section 7.2.
: 2. FSAR, Section 15.4.1.1.
: 3. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.10.2-4                                      Revision 73
 
Single Control Rod Withdrawal - Hot Shutdown B 3.10.3 BASES SURVEILLANCE REQUIREMENTS (continued) continuation of SR 3.10.3.1, SR 3.10.3.2, and SR 3.10.3.3 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 administrative controls on control rod withdrawals, the protection afforded by the LCOs involved, and hardware interlocks that preclude additional control rod withdrawals.The Surveillance Frequencies for SR 3.10.3.2 and SR 3.10.3.3 are controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Section 15.4.1.1.
: 2. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.10.3-4                                      Revision 73
 
Single Control Rod Withdrawal - Cold Shutdown B 3.10.4 BASES 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. The control rods can be hydraulically disarmed by closing the drive water and exhaust water isolation valves.
Electrically, the control rods can be disarmed by disconnecting power from all four directional control valve solenoids. Verification that all the other control rods are fully inserted is required to meet the SDM 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. The 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.The Surveillance Frequencies for SR 3.10.4.2, SR 3.10.4.3, and SR 3.10.4.4 are controlled under the Surveillance Frequency Control Program.
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. FSAR, Section 15.4.1.1.
: 2. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.10.4-5                                      Revision 73
 
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 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 SDM 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. The control rods can be hydraulically disarmed by closing the drive water and exhaust water isolation valves. Electrically, the control rods can be disarmed by disconnecting power from all four directional control valve solenoids.
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 Surveillance for LCO 3.1.1, 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 Operations LCO is prudent to preclude the possibility of an inadvertent criticality. The 24 hour Frequency is acceptable, given the administrative controls on control rod removal and hardware interlocks to block an additional control rod withdrawal.The Surveillance Frequencies for SR 3.10.5.1, SR 3.10.5.2, SR 3.10.5.3, and SR 3.10.5.5 are controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Section 15.4.1.1.
: 2. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.10.5-4                                      Revision 73
 
Multiple Control Rod Withdrawal - Refueling B 3.10.6 BASES 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. The Surveillance Frequencies are controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Section 15.4.1.1.
: 2. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.10.6-3                                    Revision 73
 
SDM Test - Refueling B 3.10.8 BASES ACTIONS (continued)
B.1 With one or more of the requirements of this LCO not met, for reasons other than an uncoupled control rod, the testing should be immediately stopped by placing the reactor mode switch in the shutdown or refuel position. This results in a condition that is consistent with the requirements for MODE 5 where the provisions of this Special Operations LCO are no longer required.
SURVEILLANCE        SR 3.10.8.1, SR 3.10.8.2, and SR 3.10.8.3 REQUIREMENTS LCO 3.3.1.1, Functions 2.a and 2.d, made applicable in this Special Operations LCO, are required to have applicable Surveillances met to establish that this Special Operations LCO is being met (SR 3.10.8.1).
However, the control rod withdrawal sequences during the SDM tests may be enforced by the RWM (LCO 3.3.2.1, Function 2, MODE 2 requirements) or by a second licensed operator (Reactor Operator or Senior Reactor Operator) or other qualified member of the technical staff.
As noted, either the applicable SRs for the RWM (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 aware of and verifies compliance with these Special Operations LCO requirements.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
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 Columbia Generating Station            B 3.10.8-4                                    Revision 73
 
SDM Test - Refueling B 3.10.8 BASES SURVEILLANCE REQUIREMENTS (continued) 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.
SR 3.10.8.6 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. Since the reactor is depressurized in MODE 5, there is insufficient reactor pressure to scram the control rods. Verification of charging water header pressure ensures that if a scram were required, capability for rapid control rod insertion would exist. The minimum pressure of 940 psig is well below the expected pressure of 1400 psig to 1500 psig while still ensuring sufficient pressure for rapid control rod insertion. The 7 day Frequency has been shown to be acceptable through operating experience and takes into account indications available in the control room.The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES          1. FSAR, Chapter 15.
: 2. 10 CFR 50.36(c)(2)(ii).
Columbia Generating Station            B 3.10.8-5                                    Revision 73
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 1 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance Surveillance Surveillance    NUREG-1434                                            Frequency    Frequency Requirement    Revision 4                                            modified by  modified in Number          Surveillance                                          TSTF-425    Columbia Requirement                                            (Yes/No/NA)  License Number                                                              Amendment SR 3.1.1.1      SR 3.1.1.1        Prior to each in vessel...          No          No AND Once within 4 hours...
SR 3.1.2.1      SR 3.1.2.1        Once within 24 hours...            No          No AND 1000 MWD/T thereafter...
SR 3.1.3.1      SR 3.1.3.1        24 hours                            Yes          Yes SR 3.1.3.2      SR 3.1.3.2        31 days (Note: Applies to partially Yes          Yes withdrawn rod - whereas NUREG-1434 applies to each withdrawn rod (partial and full) (See TSTF-475)
SR 3.1.3.3      SR 3.1.3.3        In accordance with SR 3.1.4.1... No          No SR 3.1.3.4      SR 3.1.3.4        Each time the control rod...        No          No AND Prior to declaring control rod OPERABLE...
SR 3.1.4.1      SR 3.1.4.1        Prior to exceeding 40% RTP...      No          No
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 2 of 33 Columbia        Equivalent        Columbia Surveillance Frequency  Surveillance Surveillance Surveillance    NUREG-1434                                          Frequency    Frequency Requirement    Revision 4                                          modified by  modified in Number          Surveillance                                        TSTF-425    Columbia Requirement                                        (Yes/No/NA)  License Number                                                          Amendment SR 3.1.4.2      SR 3.1.4.2        200 days cumulative operation in Yes          Yes MODE 1 SR 3.1.4.3      SR 3.1.4.3        Prior to declaring Control Rod  No          No OPERABLE...
SR 3.1.4.4      SR 3.1.4.4        Prior to exceeding 40% RTP... No          No AND Prior to exceeding 40% RTP...
SR 3.1.5.1      SR 3.1.5.1        7 days                          Yes          Yes SR 3.1.6.1      SR 3.1.6.1        24 hours                        Yes          Yes SR 3.1.7.1      SR 3.1.7.1        24 hours                        Yes          Yes SR 3.1.7.2      SR 3.1.7.2        24 hours                        Yes          Yes NA              SR 3.1.7.3        NA                              Yes          NA SR 3.1.7.3      SR 3.1.7.4        31 days                          Yes          Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 3 of 33 Columbia        Equivalent        Columbia Surveillance Frequency        Surveillance    Surveillance Surveillance    NUREG-1434                                                Frequency        Frequency Requirement    Revision 4                                                modified by      modified in Number          Surveillance                                              TSTF-425        Columbia Requirement                                              (Yes/No/NA)      License Number                                                                    Amendment SR 3.1.7.4      SR 3.1.7.5        31 days                                Yes (31 day      Yes (31 day Frequency only)  Frequency only)
AND Once with 24 hours after water or boron..
AND Once within 24 hours after solution...
SR 3.1.7.5      SR 3.1.7.6        31 days                                Yes              Yes SR 3.1.7.6      SR 3.1.7.7        In accordance with the IST Program    Yes (92 day      No Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
SR 3.1.7.7      SR 3.1.7.8        24 months on a Staggered Test Basis    Yes              Yes SR 3.1.7.8      SR 3.1.7.9        24 months                              Yes (24 month    Yes (24 month Frequency only)  Frequency only)
AND Once within 24 hours after solution...
SR 3.1.7.9      SR 3.1.7.10        Prior to addition to the SLC tank      No              No
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 4 of 33 Columbia        Equivalent        Columbia Surveillance Frequency Surveillance    Surveillance Surveillance    NUREG-1434                                        Frequency      Frequency Requirement    Revision 4                                        modified by    modified in Number          Surveillance                                      TSTF-425        Columbia Requirement                                        (Yes/No/NA)    License Number                                                            Amendment SR 3.1.8.1      SR 3.1.8.1        31 days                        Yes            Yes SR 3.1.8.2      SR 3.1.8.2        92 days                        Yes            Yes SR 3.1.8.3      SR 3.1.8.3        24 months                      Yes            Yes SR 3.2.1.1      SR 3.2.1.1        Once with 12 hours...          Yes (24 hours  Yes (24 hours thereafter      thereafter AND                            Frequency only) Frequency only) 24 hours thereafter SR 3.2.2.1      SR 3.2.2.1        Once with 12 hours...          Yes (24 hours  Yes (24 hours thereafter      thereafter AND                            Frequency only) Frequency only) 24 hours thereafter SR 3.2.2.2      SR 3.2.2.2        Once within 72 hours after... No              No (NUREG-1433)
SR 3.2.3.1      SR 3.2.3.1        Once with 12 hours...          Yes (24 hours  Yes (24 hours thereafter      thereafter AND                            Frequency only) Frequency only) 24 hours thereafter
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 5 of 33 Columbia        Equivalent        Columbia Surveillance Frequency  Surveillance    Surveillance Surveillance    NUREG-1434                                          Frequency      Frequency Requirement    Revision 4                                          modified by    modified in Number          Surveillance                                        TSTF-425        Columbia Requirement                                        (Yes/No/NA)    License Number                                                              Amendment SR 3.2.4.1      SR 3.2.4.1        Once with 12 hours...            Yes (24 hours  Yes (24 hours thereafter      thereafter AND                              Frequency only) Frequency only) 24 hours thereafter SR 3.2.4.2      SR 3.2.4.2        12 hours                        Yes            Yes SR 3.3.1.1.1    SR 3.3.1.1.1      12 hours                        Yes            Yes SR 3.3.1.1.2    SR 3.3.1.1.2      7 days                          Yes            Yes NA              SR 3.3.1.1.3      NA                              Yes            NA SR 3.3.1.1.3    SR 3.3.1.1.4      7 days                          Yes            Yes SR 3.3.1.1.4    SR 3.3.1.1.5      7 days                          Yes            Yes SR 3.3.1.1.5    NA                Prior to withdrawing SRMs... No              No SR 3.3.1.1.6    NA                7 days                          No              Yes SR 3.3.1.1.7    SR 3.3.1.1.6      1130 MWD/T average core exposure Yes            Yes SR 3.3.1.1.8    SR 3.3.1.1.7      92 days                          Yes            Yes NA              SR 3.3.1.1.8      NA                              Yes            NA SR 3.3.1.1.9    SR 3.3.1.1.9      184 days                        Yes            Yes (Pre- PRNM Implementation)
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 6 of 33 Columbia        Equivalent        Columbia Surveillance Frequency  Surveillance Surveillance Surveillance    NUREG-1434                                          Frequency    Frequency Requirement    Revision 4                                          modified by  modified in Number          Surveillance                                        TSTF-425    Columbia Requirement                                          (Yes/No/NA)  License Number                                                            Amendment SR 3.3.1.1.9    SR 3.3.1.1.9      NA (SR deleted)                  Yes          NA (Post-PRNM Implementation)
SR 3.3.1.1.10  SR 3.3.1.1.11      18 months or 24 months            Yes          Yes SR 3.3.1.1.11  SR 3.3.1.1.12      18 months                        Yes          Yes (Pre- PRNM Implementation)
SR 3.3.1.1.11  SR 3.3.1.1.12      NA (SR deleted)                  Yes          NA (Post- PRNM Implementation)
SR 3.3.1.1.12  SR 3.3.1.1.14      18 months                        Yes          Yes SR 3.3.1.1.13  SR 3.3.1.1.10      24 months                        Yes          Yes SR 3.3.1.1.14  SR 3.3.1.1.13      24 months                        Yes          Yes SR 3.3.1.1.15  SR 3.3.1.1.15      24 months on Staggered Test Basis Yes          Yes SR 3.3.1.1.16  covered by SR      184 days                          Yes          Yes (Post-PRNM      3.3.1.1.9 since Implementation) SR 3.3.1.1.9 Channel Cal includes CFT SR 3.3.1.1.17  NA                24 months                        NA          Yes (Post-PRNM Implmentation)
SR 3.3.1.2.1    SR 3.3.1.2.1      12 hours                          Yes          Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 7 of 33 Columbia        Equivalent        Columbia Surveillance Frequency  Surveillance Surveillance Surveillance    NUREG-1434                                          Frequency    Frequency Requirement    Revision 4                                          modified by  modified in Number          Surveillance                                        TSTF-425    Columbia Requirement                                        (Yes/No/NA)  License Number                                                          Amendment SR 3.3.1.2.2    SR 3.3.1.2.2      12 hours                        Yes          Yes SR 3.3.1.2.3    SR 3.3.1.2.3      24 hours                        Yes          Yes SR 3.3.1.2.4    SR 3.3.1.2.4      12 hours during Core Alterations Yes (both    Yes (both Frequencies) Frequencies)
AND 24 hours SR 3.3.1.2.5    SR 3.3.1.2.5      7 days                          Yes          Yes SR 3.3.1.2.6    SR 3.3.1.2.6      31 days                          Yes          Yes SR 3.3.1.2.7    SR 3.3.1.2.7      18 months                        Yes          Yes SR 3.3.1.3.1    NA                184 days                        NA          Yes (Pre-PRNM Implementation)
SR 3.3.1.3.2    NA                1130 MWD/T average core exposure NA          Yes (Pre-PRNM Implementation)
SR 3.3.1.3.3    NA                24 months                        NA          Yes (Pre-PRNM Implementation)
SR 3.3.1.3.4    NA                24 months                        NA          Yes (Pre-PRNM Implementation)
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 8 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance Surveillance Surveillance    NUREG-1434                                            Frequency    Frequency Requirement    Revision 4                                            modified by  modified in Number          Surveillance                                          TSTF-425    Columbia Requirement                                            (Yes/No/NA)  License Number                                                              Amendment SR 3.3.1.3.5    NA                24 months                          NA          Yes (Pre-PRNM Implementation)
SR 3.3.1.3.6    NA                24 months on a Staggered Test Basis NA          Yes (Pre-PRNM Implementation)
Note that SR    NA                NA                                  NA          NA 3.3.1.3.1 through SR 3.3.1.3.6 deleted post-PRNM Implementation)
SR 3.3.2.1.1    SR 3.3.2.1.1      92 days                            Yes          Yes (Pre-PRNM      (NUREG-1433)
Implementation)
SR 3.3.2.1.1    SR 3.3.2.1.1      184 days                            Yes          Yes (Post-PRNM      (NUREG-1433)
Implementation)
SR 3.3.2.1.2    SR 3.3.2.1.2      92 days                            Yes          Yes (NUREG-1433)
SR 3.3.2.1.3    SR 3.3.2.1.3      92 days                            Yes          Yes (NUREG-1433)
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 9 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance Surveillance Surveillance    NUREG-1434                                            Frequency    Frequency Requirement    Revision 4                                            modified by  modified in Number          Surveillance                                          TSTF-425    Columbia Requirement                                          (Yes/No/NA)  License Number                                                            Amendment SR 3.3.2.1.4    SR 3.3.2.1.4      92 days                            Yes          Yes (Pre-PRNM      (NUREG-1433)
Implementation)
SR 3.3.2.1.4    SR 3.3.2.1.4      24 months                          Yes          Yes (Post-PRNM      (NUREG-1433)
Implementation)
SR 3.3.2.1.5    SR 3.3.1.2.7      92 days                            Yes          Yes (Pre-PRNM      (NUREG-1433)
Implementation)
SR 3.3.2.1.5    SR 3.3.1.2.7      24 months                          Yes          Yes (Post-PRNM      (NUREG-1433)
Implementation)
SR 3.3.2.1.6    SR 3.3.2.1.5      24 months                          Yes          Yes (NUREG-1433)
SR 3.3.2.1.7    SR 3.3.2.1.6      24 months                          Yes          Yes (NUREG-1433)
SR 3.3.2.1.8    SR 3.3.2.1.8      Prior to declaring RWM Operable... No          No (NUREG-1433)
SR 3.3.2.2.1    SR 3.3.2.2.1      24 hours                          Yes          Yes (NUREG-1433)
SR 3.3.2.2.2    SR 3.3.2.2.2      92 days                            Yes          Yes (NUREG-1433)
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 10 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance Surveillance Surveillance    NUREG-1434                                            Frequency    Frequency Requirement    Revision 4                                            modified by  modified in Number          Surveillance                                          TSTF-425    Columbia Requirement                                            (Yes/No/NA)  License Number                                                              Amendment SR 3.3.2.2.3    SR 3.3.2.2.3      24 months                          Yes          Yes (NUREG-1433)
SR 3.3.2.2.4    SR 3.3.2.2.4      24 months                          Yes          Yes (NUREG-1433)
SR 3.3.3.1.1    SR 3.3.3.1.1      31 days                            Yes          Yes SR 3.3.3.1.2    NA                Deleted                            NA          NA SR 3.3.3.1.3    SR 3.3.3.1.2      18 months                          Yes          Yes SR 3.3.3.1.4    SR 3.3.3.1.2      24 months                          Yes          Yes SR 3.3.3.2.1    SR 3.3.3.2.1      31 days                            Yes          Yes SR 3.3.3.2.2    SR 3.3.3.2.3      18 months                          Yes          Yes SR 3.3.3.2.3    SR 3.3.3.2.3      24 months                          Yes          Yes SR 3.3.3.2.4    SR 3.3.3.2.2      24 months                          Yes          Yes SR 3.3.4.1.1    SR 3.3.4.1.1      92 days                            Yes          Yes NA              SR 3.3.4.1.2      NA                                  Yes          NA SR 3.3.4.1.2.a  SR 3.3.4.1.3      24 months                          Yes          Yes SR 3.3.4.1.2.b  SR 3.3.4.1.3      18 months                          Yes          Yes SR 3.3.4.1.3    SR 3.3.4.1.5      18 months                          Yes          Yes SR 3.3.4.1.4    SR 3.3.4.1.4      24 months                          Yes          Yes SR 3.3.4.1.5    SR 3.3.4.1.6      24 months on a Staggered Test Basis Yes          Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 11 of 33 Columbia        Equivalent        Columbia Surveillance Frequency Surveillance Surveillance Surveillance    NUREG-1434                                        Frequency    Frequency Requirement    Revision 4                                        modified by  modified in Number          Surveillance                                      TSTF-425    Columbia Requirement                                        (Yes/No/NA)  License Number                                                          Amendment SR 3.3.4.1.6    SR 3.3.4.1.7      60 months                      Yes          Yes SR 3.3.4.2.1    SR 3.3.4.2.1      12 hours                        Yes          Yes SR 3.3.4.2.2    SR 3.3.4.2.2      92 days                        Yes          Yes NA              SR 3.3.4.2.3      NA                              Yes          NA SR 3.3.4.2.3    SR 3.3.4.2.4      18 months                      Yes          Yes SR 3.3.4.2.4    SR 3.3.4.2.5      24 months                      Yes          Yes SR 3.3.5.1.1    SR 3.3.5.1.1      12 hours                        Yes          Yes SR 3.3.5.1.2    SR 3.3.5.1.2      92 days                        Yes          Yes NA              SR 3.3.5.1.3      NA                              Yes          NA SR 3.3.5.1.3    SR 3.3.5.1.4      92 days                        Yes          Yes SR 3.3.5.1.4    SR 3.3.5.1.5      18 months                      Yes          Yes SR 3.3.5.1.5    SR 3.3.5.1.5      24 months                      Yes          Yes SR 3.3.5.1.6    SR 3.3.5.1.6      24 months                      Yes          Yes SR 3.3.5.2.1    SR 3.3.5.2.1      12 hours                        Yes          Yes SR 3.3.5.2.2    SR 3.3.5.2.2      92 days                        Yes          Yes NA              SR 3.3.5.2.3      NA                              Yes          NA SR 3.3.5.2.3    SR 3.3.5.2.4      18 months                      Yes          Yes SR 3.3.5.2.4    SR 3.3.5.2.5      24 months                      Yes          Yes SR 3.3.6.1.1    SR 3.3.6.1.1      12 hours                        Yes          Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 12 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance Surveillance Surveillance    NUREG-1434                                            Frequency    Frequency Requirement    Revision 4                                            modified by  modified in Number          Surveillance                                          TSTF-425    Columbia Requirement                                            (Yes/No/NA)  License Number                                                              Amendment SR 3.3.6.1.2    SR 3.3.6.1.2 (Also 92 days                            Yes          Yes NUREG-1433 for CGS Function 6)
NA              SR 3.3.6.1.3      NA                                  Yes          NA SR 3.3.6.1.3    SR 3.3.6.1.2      184 days                            Yes          Yes NA              SR 3.3.6.1.4      NA                                  Yes          NA SR 3.3.6.1.4    SR 3.3.6.1.5 (Also 18 months                          Yes          Yes NUREG-1433 for CGS Function 6)
SR 3.3.6.1.5    SR 3.3.6.1.5      24 months                          Yes          Yes SR 3.3.6.1.6    SR 3.3.6.1.6 (Also 24 months                          Yes          Yes NUREG-1433 for CGS Function 6)
SR 3.3.6.1.7    SR 3.3.6.1.7      24 months on a Staggered Test Basis Yes          Yes SR 3.3.6.2.1    SR 3.3.6.2.1      12 hours                            Yes          Yes SR 3.3.6.2.2    SR 3.3.6.2.2      92 days                            Yes          Yes NA              SR 3.3.6.2.3      NA                                  Yes          NA SR 3.3.6.2.3    SR 3.3.6.2.4      18 months                          Yes          Yes SR 3.3.6.2.4    SR 3.3.6.2.5      24 months                          Yes          Yes NA              SR 3.3.6.2.6      NA                                  Yes          NA NA              SR 3.3.6.3.1      NA                                  Yes          NA
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 13 of 33 Columbia        Equivalent        Columbia Surveillance Frequency Surveillance Surveillance Surveillance    NUREG-1434                                        Frequency    Frequency Requirement    Revision 4                                        modified by  modified in Number          Surveillance                                      TSTF-425    Columbia Requirement                                        (Yes/No/NA)  License Number                                                          Amendment NA              SR 3.3.6.3.2      NA                              Yes          NA NA              SR 3.3.6.3.3      NA                              Yes          NA NA              SR 3.3.6.3.4      NA                              Yes          NA NA              SR 3.3.6.3.5      NA                              Yes          NA NA              SR 3.3.6.3.6      NA                              Yes          NA NA              SR 3.3.6.4.1      NA                              Yes          NA NA              SR 3.3.6.4.2      NA                              Yes          NA NA              SR 3.3.6.4.3      NA                              Yes          NA NA              SR 3.3.6.4.4      NA                              Yes          NA NA              SR 3.3.6.4.5      NA                              Yes          NA NA              SR 3.3.6.4.6      NA                              Yes          NA NA              SR 3.3.6.5.1      NA                              Yes          NA NA              SR 3.3.6.5.2      NA                              Yes          NA NA              SR 3.3.6.5.3      NA                              Yes          NA NA              SR 3.3.6.5.4      NA                              Yes          NA SR 3.3.7.1.1    SR 3.3.7.1.1      12 hours                        Yes          Yes SR 3.3.7.1.2    SR 3.3.7.1.2      92 days                        Yes          Yes NA              SR 3.3.7.1.3      NA                              Yes          NA SR 3.3.7.1.3    SR 3.3.7.1.4      18 months                      Yes          Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 14 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance    Surveillance Surveillance    NUREG-1434                                            Frequency        Frequency Requirement    Revision 4                                            modified by      modified in Number          Surveillance                                          TSTF-425        Columbia Requirement                                          (Yes/No/NA)      License Number                                                                Amendment SR 3.3.7.1.4    SR 3.3.7.1.5      24 months                          Yes              Yes NA              SR 3.3.8.1.1      NA                                Yes              NA SR 3.3.8.1.1    SR 3.3.8.1.2      31 days                            Yes              Yes SR 3.3.8.1.2    SR 3.3.8.1.3      18 months                          Yes              Yes SR 3.3.8.1.3    SR 3.3.8.1.3      24 months                          Yes              Yes SR 3.3.8.1.4    SR 3.3.8.1.4      24 months                          Yes              Yes SR 3.3.8.2.1    SR 3.3.8.2.1      184 days                          Yes              Yes SR 3.3.8.2.2    SR 3.3.8.2.2      24 months                          Yes              Yes SR 3.3.8.2.3    SR 3.3.8.2.3      24 months                          Yes              Yes SR 3.4.1.1      SR 3.4.1.1        24 hours                          Yes              Yes NA              SR 3.4.2.1        NA                                Yes              NA NA              SR 3.4.2.2        NA                                Yes              NA SR 3.4.2.1      SR 3.4.3.1        24 hours                          Yes              Yes SR 3.4.3.1      SR 3.4.4.1        In accordance with the IST Program Yes (18 month    No Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
NA              SR 3.4.4.2        NA                                Yes              No
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 15 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance    Surveillance Surveillance    NUREG-1434                                            Frequency        Frequency Requirement    Revision 4                                            modified by      modified in Number          Surveillance                                          TSTF-425        Columbia Requirement                                          (Yes/No/NA)      License Number                                                                Amendment SR 3.4.3.2      SR 3.4.4.3        24 months                          Yes              Yes SR 3.4.4.1      SR 3.4.4.1        In accordance with the IST Program Yes (18 month    No Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
SR 3.4.4.2      SR 3.4.4.3        24 months                          Yes              Yes SR 3.4.5.1      SR 3.4.5.1        12 hours                          Yes              Yes SR 3.4.6.1      SR 3.4.6.1        In accordance with the IST Program Yes (18 month    No Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
SR 3.4.7.1      SR 3.4.7.1        12 hours                          Yes              Yes SR 3.4.7.2      SR 3.4.7.2        31 days                            Yes              Yes SR 3.4.7.3      SR 3.4.7.3        18 months                          Yes              Yes SR 3.4.8.1      SR 3.4.8.1        7 days                            Yes              Yes SR 3.4.9.1      SR 3.4.9.1        12 hours                          Yes              Yes SR 3.4.10.1    SR 3.4.10.1        12 hours                          Yes              Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 16 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance    Surveillance Surveillance    NUREG-1434                                            Frequency        Frequency Requirement    Revision 4                                            modified by      modified in Number          Surveillance                                          TSTF-425        Columbia Requirement                                          (Yes/No/NA)      License Number                                                                Amendment SR 3.4.11.1    SR 3.4.11.1        30 minutes                        Yes              Yes SR 3.4.11.2    SR 3.4.11.2        Once within 15 minutes prior to... No              No SR 3.4.11.3    SR 3.4.11.3        Once within 15 minutes prior to... No              No SR 3.4.11.4    SR 3.4.11.4        Once within 15 minutes prior to... No              No SR 3.4.11.5    SR 3.4.11.5        Once within 15 minutes prior to... No              No SR 3.4.11.6    SR 3.4.11.6        Once within 15 minutes prior to... No              No SR 3.4.11.7    SR 3.4.11.7        30 minutes                        Yes              Yes SR 3.4.11.8    SR 3.4.11.8        30 minutes                        Yes              Yes SR 3.4.11.9    SR 3.4.11.9        12 hours                          Yes              Yes SR 3.4.12.1    SR 3.4.12.1        12 hours                          Yes              Yes SR 3.5.1.1      SR 3.5.1.1        31 days                            Yes              Yes SR 3.5.1.2      SR 3.5.1.2        31 days                            Yes              Yes SR 3.5.1.3      SR 3.5.1.3        31 days                            Yes              Yes SR 3.5.1.4      SR 3.5.1.4        In accordance with the IST Program Yes (92 day      No Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
SR 3.5.1.5      SR 3.5.1.5        24 months                          Yes              Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 17 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance    Surveillance Surveillance    NUREG-1434                                            Frequency        Frequency Requirement    Revision 4                                            modified by      modified in Number          Surveillance                                          TSTF-425        Columbia Requirement                                            (Yes/No/NA)      License Number                                                                  Amendment SR 3.5.1.6      SR 3.5.1.6        24 months                          Yes              Yes SR 3.5.1.7      SR 3.5.1.7        24 months on a Staggered Test Basis Yes              Yes SR 3.5.1.8      SR 3.3.5.1.7      24 months                          Yes              Yes SR 3.5.2.1      SR 3.5.2.1        12 hours                            Yes              Yes SR 3.5.2.2      SR 3.5.2.2        12 hours                            Yes              Yes SR 3.5.2.3      SR 3.5.2.3        31 days                            Yes              Yes SR 3.5.2.4      SR 3.5.2.4        31 days                            Yes              Yes SR 3.5.2.5      SR 3.5.2.5        In accordance with the IST Program  Yes (92 day      No Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
SR 3.5.2.6      SR 3.5.2.6        24 months                          Yes              Yes SR 3.5.3.1      SR 3.5.3.1        31 days                            Yes              Yes SR 3.5.3.2      SR 3.5.3.2        31 days                            Yes              Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 18 of 33 Columbia        Equivalent        Columbia Surveillance Frequency Surveillance    Surveillance Surveillance    NUREG-1434                                        Frequency        Frequency Requirement    Revision 4                                        modified by      modified in Number          Surveillance                                      TSTF-425        Columbia Requirement                                        (Yes/No/NA)      License Number                                                              Amendment SR 3.5.3.3      SR 3.5.3.3        92 days                        Yes (92 day      Yes Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
SR 3.5.3.4      SR 3.5.3.4        24 months                      Yes (18/24 month Yes Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
SR 3.5.3.5      SR 3.5.3.5        24 months                      Yes              Yes SR 3.6.1.1.1    SR 3.6.1.1.1      In accordance with the Primary  No              No Containment Leakage Rate...
NA              SR 3.6.1.1.2      NA                              No              NA
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 19 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance    Surveillance Surveillance    NUREG-1434                                            Frequency      Frequency Requirement    Revision 4                                            modified by    modified in Number          Surveillance                                          TSTF-425        Columbia Requirement                                            (Yes/No/NA)    License Number                                                                Amendment SR 3.6.1.1.2    SR 3.6.1.1.2      120 months                          Yes (18        Yes (120 month (NUREG-1433)                                          month/120 month Frequency only)
AND                                Frequency only) 48 months following a test...
AND 24 months following two consecutive tests...
SR 3.6.1.1.3    NA                24 months                          NA              Yes SR 3.6.1.1.4    NA                24 months                          NA              Yes SR 3.6.1.2.1    SR 3.6.1.2.1      In accordance with the Primary      No              No Containment Leakage Rate...
NA              SR 3.6.1.2.2      NA                                  Yes            NA SR 3.6.1.2.2    SR 3.6.1.2.3      24 months                          Yes            Yes NA              SR 3.6.1.2.4      NA                                  Yes            NA NA              SR 3.6.1.3.1      NA                                  Yes            NA SR 3.6.1.3.1    SR 3.6.1.3.2      31 days                            Yes            Yes SR 3.6.1.3.2    SR 3.6.1.3.3      31 days                            Yes            Yes (NUREG-1433)
SR 3.6.1.3.3    SR 3.6.1.3.4      Prior to entering MODE 2 or 3... No              No (NUREG-1433)
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 20 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance    Surveillance Surveillance    NUREG-1434                                            Frequency        Frequency Requirement    Revision 4                                            modified by      modified in Number          Surveillance                                          TSTF-425        Columbia Requirement                                          (Yes/No/NA)      License Number                                                                Amendment SR 3.6.1.3.4    SR 3.6.1.3.5      31 days                            Yes              Yes (NUREG-1433)
SR 3.6.1.3.5    SR 3.6.1.3.5      In accordance with the IST Program Yes (92 day      No Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
NA              SR 3.6.1.3.6      NA                                Yes (184 day    NA Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
SR 3.6.1.3.6    SR 3.6.1.3.7      In accordance with the IST Program Yes (18 month    No Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
SR 3.6.1.3.7    SR 3.6.1.3.8      24 months                          Yes              Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 21 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance Surveillance Surveillance    NUREG-1434                                            Frequency    Frequency Requirement    Revision 4                                            modified by  modified in Number          Surveillance                                          TSTF-425    Columbia Requirement                                            (Yes/No/NA)  License Number                                                              Amendment SR 3.6.1.3.8    SR 3.6.1.3.10      24 months                          Yes          Yes (NUREG-1433)
SR 3.6.1.3.9    SR 3.6.1.3.11      24 months on a Staggered Test Basis Yes          Yes (NUREG-1433)
SR 3.6.1.3.10  SR 3.6.1.3.9      In accordance with the Primary      No          No Containment Leakage...
SR 3.6.1.3.11  SR 3.6.1.3.10      In accordance with the Primary      No          No Containment Leakage...
SR 3.6.1.3.12  SR 3.6.1.3.11      In accordance with the Primary      No          No Containment Leakage...
NA              SR 3.6.1.3.12      NA                                  Yes          NA NA              SR 3.6.1.4.1      NA                                  Yes          NA SR 3.6.1.4.1    SR 3.6.1.5.1      24 hours                            Yes          Yes (NUREG-1433)
NA              SR 3.6.1.6.1      NA                                  Yes          NA NA              SR 3.6.1.6.2      NA                                  Yes          NA SR 3.6.1.5.1    SR 3.6.1.7.1      31 days                            Yes          Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 22 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance    Surveillance Surveillance    NUREG-1434                                            Frequency        Frequency Requirement    Revision 4                                            modified by      modified in Number          Surveillance                                          TSTF-425        Columbia Requirement                                          (Yes/No/NA)      License Number                                                                Amendment NA              SR 3.7.1.7.2      NA                                Yes (92 day      NA Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
NA              SR 3.6.1.7.3      NA                                Yes              NA SR 3.6.1.5.2    SR 3.6.1.7.4      10 years                          Yes              Yes SR 3.6.1.6.1    SR 3.6.1.7.1      14 days                            Yes              Yes (NUREG-1433)
SR 3.6.1.6.2    SR 3.6.1.7.2      In accordance with the IST Program Yes (but NUREG-  No (NUREG-1433)                                          1433 only has a 92 day Frequency)
SR 3.6.1.6.3    SR 3.6.1.7.3      24 months                          Yes              Yes (NUREG-1433)
SR 3.6.1.7.1    SR 3.6.1.8.1      14 days                            Yes (14 day      Yes (NUREG-1433)                                          Frequency only -
NUREG-1433 has one additional Frequency not in CGS)
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 23 of 33 Columbia        Equivalent        Columbia Surveillance Frequency        Surveillance    Surveillance Surveillance    NUREG-1434                                                Frequency      Frequency Requirement    Revision 4                                                modified by    modified in Number          Surveillance                                              TSTF-425        Columbia Requirement                                              (Yes/No/NA)    License Number                                                                    Amendment SR 3.6.1.7.2    SR 3.6.1.8.2      31 days                                Yes (31 day    Yes (31 day (NUREG-1433)                                              Frequency only) Frequency only)
AND Within 12 hours after any discharge...
SR 3.6.1.7.3    SR 3.6.1.8.3      24 months                              Yes            Yes (NUREG-1433)
NA              SR 3.6.1.8.1      NA                                    Yes            NA NA              SR 3.6.1.8.2      NA                                    Yes            NA NA              SR 3.6.1.9.1      NA                                    Yes            NA NA              SR 3.6.1.9.2      NA                                    Yes            NA NA              SR 3.6.1.9.3      NA                                    Yes            NA SR 3.6.2.1.1    SR 3.6.2.1.1      24 hours                              Yes (24 hour    Yes (24 hour Frequency only) Frequency only)
AND 5 minutes when performing testing...
SR 3.6.2.2.1    SR 3.6.2.2.1      24 hours                              Yes            Yes SR 3.6.2.3.1    SR 3.6.2.3.1      31 days                                Yes            Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 24 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance    Surveillance Surveillance    NUREG-1434                                            Frequency        Frequency Requirement    Revision 4                                            modified by      modified in Number          Surveillance                                          TSTF-425        Columbia Requirement                                          (Yes/No/NA)      License Number                                                                Amendment SR 3.6.2.3.2    SR 3.6.2.3.2      In accordance with the IST Program Yes (92 day      No Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
NA              SR 3.6.2.4.1      NA                                Yes              NA NA              SR 3.6.2.4.2      NA                                Yes              NA NA              SR 3.6.2.4.3      NA                                Yes              NA NA              SR 3.6.2.4.4      NA                                Yes              NA NA              SR 3.6.2.4.5      NA                                Yes              NA NA              SR 3.6.3.1.1      NA                                Yes              NA NA              SR 3.6.3.1.2      NA                                Yes              NA NA              SR 3.6.3.1.3      NA                                Yes              NA NA              SR 3.6.3.1.4      NA                                Yes              NA NA              SR 3.6.3.2.1      NA                                Yes              NA NA              SR 3.6.3.2.2      NA                                Yes              NA SR 3.6.3.2.1    SR 3.6.3.1.1      92 days                            Yes              Yes (NUREG-1433)
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 25 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance    Surveillance Surveillance    NUREG-1434                                            Frequency        Frequency Requirement    Revision 4                                            modified by      modified in Number          Surveillance                                          TSTF-425        Columbia Requirement                                            (Yes/No/NA)      License Number                                                                  Amendment NA              SR 3.6.3.1.2      NA                                  Yes              NA (NUREG-1433)
SR 3.6.3.3.1    SR 3.6.3.2.1      7 days                              Yes              Yes (NUREG-1433)
SR 3.6.4.1.1    SR 3.6.4.1.1      24 hours                            Yes              Yes SR 3.6.4.1.2    SR 3.6.4.1.2      31 days                            Yes              Yes SR 3.6.4.1.3    SR 3.6.4.1.3      31 days                            Yes              Yes SR 3.6.4.1.4    SR 3.6.4.1.4      24 months on a Staggered Test Basis Yes              Yes SR 3.6.4.1.5    SR 3.6.4.1.5      24 months on a Staggered Test Basis Yes              Yes SR 3.6.4.2.1    SR 3.6.4.2.1      31 days                            Yes              Yes SR 3.6.4.2.2    SR 3.6.4.2.2      In accordance with the IST Program  Yes (92 day      No Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
SR 3.6.4.2.3    SR 3.6.4.2.3      24 months                          Yes              Yes SR 3.6.4.3.1    SR 3.6.4.3.1      31 days                            Yes              Yes SR 3.6.4.3.2    SR 3.6.4.3.2      In accordance with the VFTP        No              No SR 3.6.4.3.3    SR 3.6.4.3.3      24 months                          Yes              Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 26 of 33 Columbia        Equivalent        Columbia Surveillance Frequency Surveillance    Surveillance Surveillance    NUREG-1434                                        Frequency        Frequency Requirement    Revision 4                                        modified by      modified in Number          Surveillance                                      TSTF-425        Columbia Requirement                                        (Yes/No/NA)      License Number                                                              Amendment SR 3.6.4.3.4    SR 3.6.4.3.4      24 months                      Yes              Yes NA              SR 3.6.5.1.1      NA                              Yes              NA NA              SR 3.6.5.1.2      NA                              Yes              NA NA              SR 3.6.5.2.1      NA                              Yes              NA NA              SR 3.6.5.2.2      NA                              Yes              NA NA              SR 3.6.5.2.3      NA                              Yes              NA NA              SR 3.6.5.2.4      NA                              Yes              NA NA              SR 3.6.5.2.5      NA                              Yes              NA NA              SR 3.6.5.3.1      NA                              Yes              NA NA              SR 3.6.5.3.2      NA                              Yes              NA NA              SR 3.6.5.3.3      NA                              No              NA NA              SR 3.6.5.3.4      NA                              Yes (92 day      NA Frequency only -
i.e., does not apply if the Frequency being used is the IST Program)
NA              SR 3.6.5.3.5      NA                              Yes              NA NA              SR 3.6.5.3.6      NA                              Yes              NA NA              SR 3.6.5.4.1      NA                              Yes              NA
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 27 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance Surveillance Surveillance    NUREG-1434                                            Frequency    Frequency Requirement    Revision 4                                            modified by  modified in Number          Surveillance                                          TSTF-425    Columbia Requirement                                            (Yes/No/NA)  License Number                                                              Amendment NA              SR 3.6.5.5.1      NA                                  Yes          NA NA              SR 3.6.5.6.1      NA                                  Yes          NA NA              SR 3.6.5.6.2      NA                                  Yes          NA NA              SR 3.6.5.6.3      NA                                  Yes          NA SR 3.7.1.1      SR 3.7.1.1        24 hours                            Yes          Yes NA              SR 3.7.1.2        NA                                  Yes          NA SR 3.7.1.2      SR 3.7.1.3        24 hours                            Yes          Yes NA              SR 3.7.1.4        NA                                  Yes          NA SR 3.7.1.3      SR 3.7.1.5        31 days                            Yes          Yes SR 3.7.1.4      NA                92 days                            NA          Yes SR 3.7.1.5      SR 3.7.1.6        24 months                          Yes          Yes NA              SR 3.7.2.1        NA                                  Yes          NA SR 3.7.2.1      SR 3.7.2.2        31 days                            Yes          Yes SR 3.7.2.2      SR 3.7.2.3        24 months                          Yes          Yes SR 3.7.3.1      SR 3.7.3.1        31 days                            Yes          Yes SR 3.7.3.2      SR 3.7.3.2        In accordance with the VFTP        No          No SR 3.7.3.3      SR 3.7.3.3        24 months                          Yes          Yes SR 3.7.3.4      SR 3.7.3.4        In accordance with the Control Room No          No Envelope...
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 28 of 33 Columbia        Equivalent        Columbia Surveillance Frequency Surveillance    Surveillance Surveillance    NUREG-1434                                        Frequency      Frequency Requirement    Revision 4                                        modified by    modified in Number          Surveillance                                      TSTF-425        Columbia Requirement                                        (Yes/No/NA)    License Number                                                            Amendment SR 3.7.4.1      SR 3.7.4.1        24 months                      Yes            Yes SR 3.7.5.1      SR 3.7.5.1        31 days                        Yes (31 day    Yes (31 day Frequency only) Frequency only)
AND Once within 4 hours after...
SR 3.7.6.1      SR 3.7.6.1        31 days                        Yes            Yes SR 3.7.6.2      SR 3.7.6.2        24 months                      Yes            Yes SR 3.7.6.3      SR 3.7.6.3        24 months                      Yes            Yes SR 3.7.7.1      SR 3.7.7.1        7 days                          Yes            Yes SR 3.8.1.1      SR 3.8.1.1        7 days                          Yes            Yes SR 3.8.1.2      SR 3.8.1.2        31 days                        Yes            Yes SR 3.8.1.3      SR 3.8.1.3        31 days                        Yes            Yes SR 3.8.1.4      SR 3.8.1.4        31 days                        Yes            Yes SR 3.8.1.5      SR 3.8.1.5        31 days                        Yes            Yes SR 3.8.1.6      SR 3.8.1.6        92 days                        Yes            Yes SR 3.8.1.7      SR 3.8.1.7        184 days                        Yes            Yes SR 3.8.1.8      SR 3.8.1.8        24 months                      Yes            Yes SR 3.8.1.9      SR 3.8.1.9        24 months                      Yes            Yes SR 3.8.1.10    SR 3.8.1.10        24 months                      Yes            Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 29 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance Surveillance Surveillance    NUREG-1434                                            Frequency    Frequency Requirement    Revision 4                                            modified by  modified in Number          Surveillance                                          TSTF-425    Columbia Requirement                                          (Yes/No/NA)  License Number                                                            Amendment SR 3.8.1.11    SR 3.8.1.11        24 months                          Yes          Yes SR 3.8.1.12    SR 3.8.1.12        24 months                          Yes          Yes SR 3.8.1.13    SR 3.8.1.13        24 months                          Yes          Yes SR 3.8.1.14    SR 3.8.1.14        24 months                          Yes          Yes SR 3.8.1.15    SR 3.8.1.15        24 months                          Yes          Yes SR 3.8.1.16    SR 3.8.1.16        24 months                          Yes          Yes SR 3.8.1.17    SR 3.8.1.17        24 months                          Yes          Yes SR 3.8.1.18    SR 3.8.1.18        24 months                          Yes          Yes SR 3.8.1.19    SR 3.8.1.19        24 months                          Yes          Yes SR 3.8.1.20    SR 3.8.1.20        10 years                          Yes          Yes SR 3.8.2.1      SR 3.8.2.1        In accordance with applicable SRs  No          No SR 3.8.3.1      SR 3.8.3.1        31 days                            Yes          Yes SR 3.8.3.2      SR 3.8.3.2        31 days                            Yes          Yes SR 3.8.3.3      SR 3.8.3.3        In accordance with the Diesel Fuel No          No Oil...
SR 3.8.3.4      SR 3.8.3.4        31 days                            Yes          Yes SR 3.8.3.5      SR 3.8.3.5        92 days                            Yes          Yes SR 3.8.4.1      SR 3.8.4.1        7 days                            Yes          Yes SR 3.8.4.2      SR 3.8.4.2        24 months                          Yes          Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 30 of 33 Columbia        Equivalent        Columbia Surveillance Frequency  Surveillance    Surveillance Surveillance    NUREG-1434                                          Frequency      Frequency Requirement    Revision 4                                          modified by    modified in Number          Surveillance                                        TSTF-425        Columbia Requirement                                          (Yes/No/NA)    License Number                                                              Amendment SR 3.8.4.3      SR 3.8.4.3        24 months                        Yes            Yes SR 3.8.5.1      SR 3.8.5.1        In accordance with applicable SRs No              No SR 3.8.6.1      SR 3.8.6.1        7 days                            Yes            Yes SR 3.8.6.2      SR 3.8.6.2        31 days                          Yes            Yes SR 3.8.6.3      SR 3.8.6.3        31 days                          Yes            Yes SR 3.8.6.4      SR 3.8.6.4        31 days                          Yes            Yes SR 3.8.6.5      SR 3.8.6.5        92 days                          Yes            Yes SR 3.8.6.6      SR 3.8.6.6        60 months                        Yes (60 month  Yes (60 month Frequency only) Frequency only)
AND 12 months when battery shows...
AND 24 months when battery has reached...
NA              SR 3.8.7.1        NA                                Yes            NA NA              SR 3.8.8.1        NA                                Yes            NA SR 3.8.7.1      SR 3.8.9.1        7 days                            Yes            Yes SR 3.8.8.1      SR 3.8.10.1        7 days                            Yes            Yes SR 3.9.1.1      SR 3.9.1.1        7 days                            Yes            Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 31 of 33 Columbia        Equivalent        Columbia Surveillance Frequency  Surveillance Surveillance Surveillance    NUREG-1434                                          Frequency    Frequency Requirement    Revision 4                                          modified by  modified in Number          Surveillance                                        TSTF-425    Columbia Requirement                                        (Yes/No/NA)  License Number                                                          Amendment SR 3.9.2.1      SR 3.9.2.1        12 hours                        Yes          Yes SR 3.9.2.2      SR 3.9.2.2        7 days                          Yes          Yes SR 3.9.3.1      SR 3.9.3.1        12 hours                        Yes          Yes SR 3.9.4.1      SR 3.9.4.1        Each time the control rod is    No          No withdrawn...
SR 3.9.5.1      SR 3.9.5.1        7 days                          Yes          Yes SR 3.9.5.2      SR 3.9.5.2        7 days                          Yes          Yes SR 3.9.6.1      SR 3.9.6.1        24 hours                        Yes          Yes SR 3.9.7.1      SR 3.9.7.1        24 hours                        Yes          Yes SR 3.9.8.1      SR 3.9.8.1        12 hours                        Yes          Yes SR 3.9.9.1      SR 3.9.9.1        12 hours                        Yes          Yes SR 3.9.10.1    NA                Once prior to the movement of... NA          No SR 3.10.1.1    SR 3.10.1.1        According to the applicable SRs  No          No SR 3.10.2.1    SR 3.10.2.1        12 hours                        Yes          Yes SR 3.10.2.2    SR 3.10.2.2        24 hours                        Yes          Yes SR 3.10.3.1    SR 3.10.3.1        According to the applicable SRs  No          No SR 3.10.3.2    SR 3.10.3.2        24 hours                        Yes          Yes SR 3.10.3.3    SR 3.10.3.3        24 hours                        Yes          Yes SR 3.10.4.1    SR 3.10.4.1        According to the applicable SRs  No          No
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 32 of 33 Columbia        Equivalent        Columbia Surveillance Frequency Surveillance Surveillance Surveillance    NUREG-1434                                        Frequency    Frequency Requirement    Revision 4                                        modified by  modified in Number          Surveillance                                      TSTF-425    Columbia Requirement                                        (Yes/No/NA)  License Number                                                          Amendment SR 3.10.4.2    SR 3.10.4.2        24 hours                        Yes          Yes SR 3.10.4.3    SR 3.10.4.3        24 hours                        Yes          Yes SR 3.10.4.4    SR 3.10.4.4        24 hours                        Yes          Yes SR 3.10.5.1    SR 3.10.5.1        24 hours                        Yes          Yes SR 3.10.5.2    SR 3.10.5.2        24 hours                        Yes          Yes SR 3.10.5.3    SR 3.10.5.3        24 hours                        Yes          Yes SR 3.10.5.4    SR 3.10.5.4        According to SR 3.1.1.1        No          No SR 3.10.5.5    SR 3.10.5.5        24 hours                        Yes          Yes SR 3.10.6.1    SR 3.10.6.1        24 hours                        Yes          Yes SR 3.10.6.2    SR 3.10.6.2        24 hours                        Yes          Yes SR 3.10.6.3    SR 3.10.6.3        24 hours                        Yes          Yes SR 3.10.7.1    SR 3.10.7.1        During control rod movement    No          No SR 3.10.7.2    SR 3.10.7.2        Prior to control rod movement  No          No (NUREG-1433)
SR 3.10.8.1    SR 3.10.8.1        According to the applicable SRs No          No SR 3.10.8.2    SR 3.10.8.2        According to the applicable SRs No          No SR 3.10.8.3    SR 3.10.8.3        During control rod movement    No          No SR 3.10.8.4    SR 3.10.8.4        12 hours                        Yes          Yes
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Columbia SRs versus TSTF-425 SRs Cross-Reference Page 33 of 33 Columbia        Equivalent        Columbia Surveillance Frequency    Surveillance Surveillance Surveillance    NUREG-1434                                            Frequency    Frequency Requirement    Revision 4                                            modified by  modified in Number          Surveillance                                          TSTF-425    Columbia Requirement                                            (Yes/No/NA)  License Number                                                              Amendment SR 3.10.8.5    SR 3.10.8.5        Each time the control rod is        No          No withdrawn...
AND Prior to satisfying LCO 3.10.8.c...
SR 3.10.8.6    SR 3.10.8.6        7 days                              Yes          Yes NA              SR 3.10.9.1        NA                                  Yes          NA NA              SR 3.10.9.2        NA                                  Yes          NA NA              SR 3.10.10.1      NA                                  Yes          NA NA              SR 3.10.10.2      NA                                  Yes          NA
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Proposed No Significant Hazards Consideration Page 1 of 2 Description of Amendment Request: This amendment request involves the adoption of approved changes to the standard technical specifications (STS) for General Electric Plants, BWR/4 (NUREG-1433) and BWR/6 (NUREG-1434), to allow relocation of specific TS surveillance frequencies to a licensee-controlled program. The proposed changes are described in Technical Specification Task Force (TSTF) Traveler, TSTF-425, Revision 3 (ADAMS Accession No. ML090850642) related to the Relocation of Surveillance Frequencies to Licensee Control - RITSTF Initiative 5b and are described in the Notice of Availability published in the Federal Register on July 6, 2009 (74 FR 31996).
The proposed changes are consistent with NRC-approved Industry/ TSTF Traveler, TSTF-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control -
RITSTF Initiative 5b.'' The proposed changes relocate surveillance frequencies to a licensee-controlled program, the Surveillance Frequency Control Program. The changes are applicable to licensees using probabilistic risk guidelines contained in NRC-approved NEI 04-10, Revision 1, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies,'' dated April 2007 (ADAMS Accession No. 071360456).
Basis for proposed no significant hazards consideration: As required by 10 CFR 50.91(a), the Energy Northwest analysis of the issue of no significant hazards consideration is presented below:
: 1. Does 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 accident 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.
 
LICENSE AMENDMENT REQUEST FOR ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE TRAVELER (TSTF)-425, REVISION 3  - Proposed No Significant Hazards Consideration Page 2 of 2
: 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 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 the Technical Specifications (TS)), because 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, Energy Northwest will perform a probabilistic risk evaluation using the guidance contained in NRC approved NEI 04-10, Revision 1 in accordance with the TS Surveillance Frequency Control Program. NEI 04-10, Revision 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, Energy Northwest concludes that the requested change does not involve a significant hazards consideration as set forth in 10 CFR 50.92(c), "Issuance of amendment."}}

Latest revision as of 13:29, 10 January 2025

License Amendment Request for Adoption of Technical Specification Task Force Traveler-425, Revision 3
ML15093A178
Person / Time
Site: Columbia Energy Northwest icon.png
Issue date: 03/17/2015
From: Hettel W
Energy Northwest
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
GO2-15-007, TSTF-425, Rev. 3
Download: ML15093A178 (544)
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