ML11103A053: Difference between revisions
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==1.0 DESCRIPTION== | ==1.0 DESCRIPTION== | ||
2.0 ASSESSMENT 2.1 Applicability of Published Safety Evaluation 2.2 Optional Changes and Variations 3.0 REGULATORY ANALYSIS 3.1 Applicable Regulatory Requirements/Criteria 3.2 Precedent 3.3 No Significant Hazards Consideration Determination 3.4 Conclusions 4.0 ENVIRONMENTAL CONSIDERATION 5.0 REFERENCE Attachment 1 Description and Assessment Request for Adoption of TSTF 425, Rev. 3 Page 1 | |||
of Published Safety Evaluation | |||
Changes and Variations | |||
ANALYSIS 3.1 Applicable Regulatory Requirements/Criteria | |||
3.3 No Significant Hazards Consideration Determination | |||
4.0 ENVIRONMENTAL CONSIDERATION | |||
Attachment 1 Description and Assessment Request for Adoption of TSTF 425, Rev. 3 Page 1 | |||
==1.0 DESCRIPTION== | ==1.0 DESCRIPTION== | ||
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The existing TS Bases information describing the basis for the Surveillance Frequency will be relocated to the licensee-controlled Surveillance Frequency Control Program.The changes are consistent with NRC approved Industry/TSTF STS change TSTF-425, Revision 3, (ADAMS Accession No. ML090850642). | The existing TS Bases information describing the basis for the Surveillance Frequency will be relocated to the licensee-controlled Surveillance Frequency Control Program.The changes are consistent with NRC approved Industry/TSTF STS change TSTF-425, Revision 3, (ADAMS Accession No. ML090850642). | ||
The Federal Register Notice published on July 6, 2009 (74 FR 31996) announced the availability of this TS improvement. | The Federal Register Notice published on July 6, 2009 (74 FR 31996) announced the availability of this TS improvement. | ||
Included in the Federal Register Notice was a generic Safety Evaluation intended to be used for processing/approving license amendment requests submitted by licensees choosing to adopt TSTF-425.2.0 ASSESSMENT | Included in the Federal Register Notice was a generic Safety Evaluation intended to be used for processing/approving license amendment requests submitted by licensees choosing to adopt TSTF-425.2.0 ASSESSMENT 2.1 Applicability of Published Safety Evaluation Arizona Public Service Company (APS) has reviewed the generic safety evaluation included in the Federal Register Notice published on July 6, 2009 (74 FR 31996) for implementation of TSTF-425, Revision 3, and the requirements specified in NEI 04-10, Rev. 1, (ADAMS Accession No.ML071360456). | ||
of Published Safety Evaluation Arizona Public Service Company (APS) has reviewed the generic safety evaluation included in the Federal Register Notice published on July 6, 2009 (74 FR 31996) for implementation of TSTF-425, Revision 3, and the requirements specified in NEI 04-10, Rev. 1, (ADAMS Accession No.ML071360456). | |||
Attachment 2 includes APS documentation of the technical adequacy of the current PVNGS probabilistic risk assessment (PRA) with regards to the requirements of Regulatory Guide 1.200, Revision 2 (ADAMS Accession No.ML090410014) | Attachment 2 includes APS documentation of the technical adequacy of the current PVNGS probabilistic risk assessment (PRA) with regards to the requirements of Regulatory Guide 1.200, Revision 2 (ADAMS Accession No.ML090410014) | ||
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.APS has concluded that the justifications presented in the TSTF proposal and the safety evaluation prepared by the NRC staff are applicable to PVNGS and justify the requested license amendment to incorporate the changes to the PVNGS TS. | 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.APS has concluded that the justifications presented in the TSTF proposal and the safety evaluation prepared by the NRC staff are applicable to PVNGS and justify the requested license amendment to incorporate the changes to the PVNGS TS. | ||
Attachment I Description and Assessment Request for Adoption of TSTF 425, Rev. 3 Page 2 2.2 Optional Changes and Variations The proposed amendment is consistent with the NUREG 1432 Standard Technical Specifications (STS) changes described in TSTF-425, Revision 3;but, APS proposes variations or deviations from TSTF-425, as identified below. The proposed variations or deviations may include differing TS surveillance numbers." The definition of STAGGERED TEST BASIS is being retained in PVNGS TS Definition Section 1.1 since this terminology is mentioned in Administrative TS Section 5.5.17, "Control Room Envelope Habitability Program," which is not the 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 (74 FR 31996)." NRC letter dated April 14, 2010 (Reference | Attachment I Description and Assessment Request for Adoption of TSTF 425, Rev. 3 Page 2 2.2 Optional Changes and Variations The proposed amendment is consistent with the NUREG 1432 Standard Technical Specifications (STS) changes described in TSTF-425, Revision 3;but, APS proposes variations or deviations from TSTF-425, as identified below. The proposed variations or deviations may include differing TS surveillance numbers." The definition of STAGGERED TEST BASIS is being retained in PVNGS TS Definition Section 1.1 since this terminology is mentioned in Administrative TS Section 5.5.17, "Control Room Envelope Habitability Program," which is not the 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 (74 FR 31996)." NRC letter dated April 14, 2010 (Reference | ||
: 1) provides a change to an optional insert (INSERT #2) to the existing TS Bases to facilitate adoption of the TSTF while retaining the existing NUREG 1432 TS surveillance frequency (SF) Bases considerations for licensees not choosing to adopt TSTF-425. | : 1) provides a change to an optional insert (INSERT #2) to the existing TS Bases to facilitate adoption of the TSTF while retaining the existing NUREG 1432 TS surveillance frequency (SF) Bases considerations for licensees not choosing to adopt TSTF-425. | ||
The TSTF-425 TS Bases insert states as follows: The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program.Recently several licensees submitting license amendment requests for adoption of TSTF-425 have identified a need to deviate from this statement because it only applies to frequencies that have been changed in accordance with the Surveillance Frequency Control Program (SFCP) and does not apply to frequencies that are relocated but not changed.The NRC staff agreed that the TSTF-425 TS Bases insert applies to SFs that are relocated and subsequently evaluated and changed, in accordance with the SFCP in NRC letter dated April 14, 2010 (Reference 1). The TSTF-425 TS Bases does not apply to SFs relocated to the SFCP but not changed. Therefore, for SFs relocated to the SFCP but not changed, the existing TS Bases description remains a valid description of the TS SF Bases for the unchanged SF. | The TSTF-425 TS Bases insert states as follows: The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program.Recently several licensees submitting license amendment requests for adoption of TSTF-425 have identified a need to deviate from this statement because it only applies to frequencies that have been changed in accordance with the Surveillance Frequency Control Program (SFCP) and does not apply to frequencies that are relocated but not changed.The NRC staff agreed that the TSTF-425 TS Bases insert applies to SFs that are relocated and subsequently evaluated and changed, in accordance with the SFCP in NRC letter dated April 14, 2010 (Reference 1). The TSTF-425 TS Bases does not apply to SFs relocated to the SFCP but not changed. Therefore, for SFs relocated to the SFCP but not changed, the existing TS Bases description remains a valid description of the TS SF Bases for the unchanged SF. | ||
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Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed amendment. | Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed amendment. | ||
Attachment 1 Description and Assessment Request for Adoption of TSTF 425, Rev. 3 Page 5 5.0 REFERENCE 1. NRC Letter, "Notification of Issue with NRC-Approved Technical Specification Task Force (TSTF) Traveler 425, Revision 3, 'Relocate Surveillance Frequencies to Licensee Control -RITSTF Initiative 5b,"' dated April 14, 2010 (ADAMS Accession No ML100990099). | Attachment 1 Description and Assessment Request for Adoption of TSTF 425, Rev. 3 Page 5 5.0 REFERENCE 1. NRC Letter, "Notification of Issue with NRC-Approved Technical Specification Task Force (TSTF) Traveler 425, Revision 3, 'Relocate Surveillance Frequencies to Licensee Control -RITSTF Initiative 5b,"' dated April 14, 2010 (ADAMS Accession No ML100990099). | ||
Attachment 2 Documentation of Probabilistic Risk Assessment Technical Adequacy 1.0 OVERVIEW 2.0 BASIS TO CONCLUDE THAT THE PRA MODEL REPRESENTS THE AS-BUILT, AS-OPERATED PLANT 3.0 PEER REVIEW FINDINGS AND OBSERVATIONS FOR INTERNAL EVENTS AND INTERNAL FLOOD PRA MODEL 4.0 METHODOLOGY TO BE USED TO ASSESS STI CHANGES 5.0 KEY ASSUMPTIONS AND APPROXIMATIONS | Attachment 2 Documentation of Probabilistic Risk Assessment Technical Adequacy 1.0 OVERVIEW 2.0 BASIS TO CONCLUDE THAT THE PRA MODEL REPRESENTS THE AS-BUILT, AS-OPERATED PLANT 3.0 PEER REVIEW FINDINGS AND OBSERVATIONS FOR INTERNAL EVENTS AND INTERNAL FLOOD PRA MODEL 4.0 METHODOLOGY TO BE USED TO ASSESS STI CHANGES 5.0 KEY ASSUMPTIONS AND APPROXIMATIONS 6.0 EXTERNAL EVENTS RISK | ||
EVENTS RISK | |||
==7.0 CONCLUSION== | ==7.0 CONCLUSION== | ||
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==8.0 REFERENCES== | ==8.0 REFERENCES== | ||
TABLE 1 OPEN CEOG INTERNAL EVENT PRA PEER REVIEW F&Os TABLE 2 RG 1.200 CATEGORY II SUPPORTING REQUIREMENTS NOT MET EVALUATION Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 1 1.0 OVERVIEW Palo Verde Nuclear Generating Station (PVNGS) will follow the methodology provided in NEI 04-10 (Reference | TABLE 1 OPEN CEOG INTERNAL EVENT PRA PEER REVIEW F&Os TABLE 2 RG 1.200 CATEGORY II SUPPORTING REQUIREMENTS NOT MET EVALUATION Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 1 1.0 OVERVIEW Palo Verde Nuclear Generating Station (PVNGS) will follow the methodology provided in NEI 04-10 (Reference | ||
: 1) for Risk-Informed Technical Specifications (RITS) Initiative 5b. NEI 04-10 endorses Regulatory Guide (RG) 1.200 (Reference | : 1) for Risk-Informed Technical Specifications (RITS) Initiative 5b. NEI 04-10 endorses Regulatory Guide (RG) 1.200 (Reference | ||
: 2) for determining the technical adequacy of a plant Probabilistic Risk Assessment (PRA). Consistent with the requirements of RG 1.200 Section 4.2, the technical adequacy of the PVNGS PRA model used as the basis for risk-informed applications is established by the following: " Identifying plant changes that have been incorporated at the site, but are not yet in the PRA model and justify why the changes do not impact the PRA results used to support the amendment request.* Documenting that the parts of the current PRA used in support of the amendment request are consistent with applicable standards endorsed by RG 1.200 (Reference | : 2) for determining the technical adequacy of a plant Probabilistic Risk Assessment (PRA). Consistent with the requirements of RG 1.200 Section 4.2, the technical adequacy of the PVNGS PRA model used as the basis for risk-informed applications is established by the following: " Identifying plant changes that have been incorporated at the site, but are not yet in the PRA model and justify why the changes do not impact the PRA results used to support the amendment request.* Documenting that the parts of the current PRA used in support of the amendment request are consistent with applicable standards endorsed by RG 1.200 (Reference | ||
: 2) and, where specific requirements in the Regulatory Guide are not adequately met, justifying why the recommendations not met will not unduly impact the results.* Identifying key assumptions and approximations relevant to the results used in the decision-making process including the peer reviewers' assessment of those assumptions. | : 2) and, where specific requirements in the Regulatory Guide are not adequately met, justifying why the recommendations not met will not unduly impact the results.* Identifying key assumptions and approximations relevant to the results used in the decision-making process including the peer reviewers' assessment of those assumptions. | ||
* Documenting 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, justifying why the significant contributors would not be impacted.2.0 BASIS TO CONCLUDE THAT THE PRA MODEL REPRESENTS THE AS-BUILT, AS-OPERATED PLANT To ensure the technical adequacy of the PVNGS PRA model and documentation, PVNGS administrative procedure 70DP-ORA03, "Probabilistic Risk Assessment Model Control," provides guidelines for updating the PRA model and documentation. | * Documenting 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, justifying why the significant contributors would not be impacted.2.0 BASIS TO CONCLUDE THAT THE PRA MODEL REPRESENTS THE AS-BUILT, AS-OPERATED PLANT To ensure the technical adequacy of the PVNGS PRA model and documentation, PVNGS administrative procedure 70DP-ORA03, "Probabilistic Risk Assessment Model Control," provides guidelines for updating the PRA model and documentation. | ||
In accordance with 70DP-ORA03 and related procedures, plant changes that could impact the PRA model are screened and evaluated. | In accordance with 70DP-ORA03 and related procedures, plant changes that could impact the PRA model are screened and evaluated. | ||
Plant changes that are screened and evaluated are: plant modifications, error corrections, procedure changes, plant data update, and improved methods.Procedure 70DP-ORA03 defines the process and the minimum frequency for updating the PRA model and associated documentation that may be impacted by plant changes. The objective of the above-described procedural guidance is to assure that the PRA model is an accurate reflection of the as-built and as-operated plants. At the present time, the Internal Events and Flood PRA model reflects the as-built, as-operated plant. | Plant changes that are screened and evaluated are: plant modifications, error corrections, procedure changes, plant data update, and improved methods.Procedure 70DP-ORA03 defines the process and the minimum frequency for updating the PRA model and associated documentation that may be impacted by plant changes. The objective of the above-described procedural guidance is to assure that the PRA model is an accurate reflection of the as-built and as-operated plants. At the present time, the Internal Events and Flood PRA model reflects the as-built, as-operated plant. | ||
Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 2 3.0 PEER REVIEW FINDINGS AND OBSERVATIONS FOR INTERNAL EVENTS AND INTERNAL FLOOD PRA MODEL The PVNGS Internal Events and Internal Flood PRA model received several assessments to establish the technical quality of the PRA. These assessments are identified and discussed in the paragraphs below.* In 1999, a PRA peer review was conducted by the Combustion Engineering Owners Group (CEOG) on the Internal Events PRA model.This peer review included an assessment of the PRA model maintenance and update process using the CEOG established peer review process based on the Boiling Water Reactor Owners Group peer review process." In 2010, a PVNGS self-assessment was performed on the Internal Events PRA model to assess the gaps between the CEOG peer review scope/detail for the PVNGS peer review results and the American Society of Mechanical Engineers (ASME)/American Nuclear Society (ANS) PRA Standard (Reference | Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 2 3.0 PEER REVIEW FINDINGS AND OBSERVATIONS FOR INTERNAL EVENTS AND INTERNAL FLOOD PRA MODEL The PVNGS Internal Events and Internal Flood PRA model received several assessments to establish the technical quality of the PRA. These assessments are identified and discussed in the paragraphs below.* In 1999, a PRA peer review was conducted by the Combustion Engineering Owners Group (CEOG) on the Internal Events PRA model.This peer review included an assessment of the PRA model maintenance and update process using the CEOG established peer review process based on the Boiling Water Reactor Owners Group peer review process." In 2010, a PVNGS self-assessment was performed on the Internal Events PRA model to assess the gaps between the CEOG peer review scope/detail for the PVNGS peer review results and the American Society of Mechanical Engineers (ASME)/American Nuclear Society (ANS) PRA Standard (Reference | ||
: 3) and RG 1.200 (Reference | : 3) and RG 1.200 (Reference | ||
: 2) guidance." In 2010, Westinghouse performed a peer review of the PVNGS PRA Internal Flood model against the requirements of the ASME/ANS PRA Standard (Reference | : 2) guidance." In 2010, Westinghouse performed a peer review of the PVNGS PRA Internal Flood model against the requirements of the ASME/ANS PRA Standard (Reference | ||
: 3) and any Clarifications and Qualifications provided in RG 1.200 (Reference 2).A peer review was conducted in 1999 by the CEOG on the PVNGS Internal Events PRA model resulting in 77 Fact & Observations (F&Os). The levels of significance of the F&Os are as follows: A -Extremely important and necessary to address to assure the technical adequacy of the Probabilistic Safety Assessment (PSA) or the quality of the PSA or the quality of the PSA update process.(Contingent Item for Certification) | : 3) and any Clarifications and Qualifications provided in RG 1.200 (Reference 2).A peer review was conducted in 1999 by the CEOG on the PVNGS Internal Events PRA model resulting in 77 Fact & Observations (F&Os). The levels of significance of the F&Os are as follows: A -Extremely important and necessary to address to assure the technical adequacy of the Probabilistic Safety Assessment (PSA) or the quality of the PSA or the quality of the PSA update process.(Contingent Item for Certification) | ||
B -Important and necessary to address, but may be deferred until the next PSA update. (Contingent Item for Certification) | B -Important and necessary to address, but may be deferred until the next PSA update. (Contingent Item for Certification) | ||
C -Considered desirable to maintain maximum flexibility in PSA Applications and consistency in the Industry but not likely to significantly affect the results or insights.D -Editorial or Minor Technical Item, left to the discretion of the host utility.O -Observation. | C -Considered desirable to maintain maximum flexibility in PSA Applications and consistency in the Industry but not likely to significantly affect the results or insights.D -Editorial or Minor Technical Item, left to the discretion of the host utility.O -Observation. | ||
S -Superior treatment exceeding requirements and exceeding what would be found in most PRAs.There were 8 'A', 27 'B', 20 'C', and 11 'D' level F&Os identified during the review. Additionally, there were 2 'S' F&Os denoting a strength and 9 '0' F&Os Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 3 which are observations used to define a scope of review. There are three remaining open level 'A' or 'B' F&Os. All three are level 'B' F&Os and are listed in Table 1.A PVNGS self-assessment performed on the Internal Events PRA model was completed in 2010. The self-assessment was performed based on the PRA ASME/ANS RA-Sa-2009 Standard (Reference | S -Superior treatment exceeding requirements and exceeding what would be found in most PRAs.There were 8 'A', 27 'B', 20 'C', and 11 'D' level F&Os identified during the review. Additionally, there were 2 'S' F&Os denoting a strength and 9 '0' F&Os Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 3 which are observations used to define a scope of review. There are three remaining open level 'A' or 'B' F&Os. All three are level 'B' F&Os and are listed in Table 1.A PVNGS self-assessment performed on the Internal Events PRA model was completed in 2010. The self-assessment was performed based on the PRA ASME/ANS RA-Sa-2009 Standard (Reference | ||
: 3) and RG 1.200 (Reference 2).The results of the self-assessment identified four supporting requirements (SRs)from the ASME/ANS RA-Sa -2009 Standard (Reference | : 3) and RG 1.200 (Reference 2).The results of the self-assessment identified four supporting requirements (SRs)from the ASME/ANS RA-Sa -2009 Standard (Reference | ||
: 3) for which there were potential gaps to Capability Category II of the Standard. | : 3) for which there were potential gaps to Capability Category II of the Standard. | ||
As part of this amendment request, the four SRs not meeting Capability Category II in the self-assessment were reviewed to evaluate their potential impact on the surveillance test interval (STI) assessments. | As part of this amendment request, the four SRs not meeting Capability Category II in the self-assessment were reviewed to evaluate their potential impact on the surveillance test interval (STI) assessments. | ||
A summary of the "not met" SRs for Capability Category II is provided in Table 2. An assessment is provided for each "not met" SR that indicates the impact on the application of the current PRA for this amendment request.In 2010, a peer review of the Internal Flood PRA model was performed by Westinghouse covering a total of sixty-two (62) SRs associated with internal flood in the ASME/ANS PRA Standard (Reference 3). The peer review identified seven priority 'A' and no priority 'B' F&Os. All of the priority 'A' F&Os have been resolved. | A summary of the "not met" SRs for Capability Category II is provided in Table 2. An assessment is provided for each "not met" SR that indicates the impact on the application of the current PRA for this amendment request.In 2010, a peer review of the Internal Flood PRA model was performed by Westinghouse covering a total of sixty-two (62) SRs associated with internal flood in the ASME/ANS PRA Standard (Reference 3). The peer review identified seven priority 'A' and no priority 'B' F&Os. All of the priority 'A' F&Os have been resolved. | ||
Therefore, all findings of "not met" Capability Category II SRs have been resolved.4.0 METHODOLOGY TO BE USED TO ASSESS STI CHANGES The methodology/guidance of NEI 04-10 (Reference | Therefore, all findings of "not met" Capability Category II SRs have been resolved.4.0 METHODOLOGY TO BE USED TO ASSESS STI CHANGES The methodology/guidance of NEI 04-10 (Reference | ||
: 1) will be used to assess STI changes.5.0 KEY ASSUMPTIONS AND APPROXIMATIONS The following definitions from the RG 1.200, Section 4.2 (Reference 2), are used to clarify the nature of the "key assumptions." A "key assumption" is one that is made in response to a key source of model uncertainty in the knowledge that a different reasonable alternative assumption would produce different results, or an assumption that results in an approximation made for modeling convenience in the knowledge that a more detailed model would produce different results. For the base PRA, the term"different results" refers to a change in the risk profile [e.g., total core damage frequency (CDF) and total large early release frequency (LERF), the set of initiating events and accident sequences that contribute most to CDF and to LERF, and the associated changes in insights derived from the changes in the risk profile]. | : 1) will be used to assess STI changes.5.0 KEY ASSUMPTIONS AND APPROXIMATIONS The following definitions from the RG 1.200, Section 4.2 (Reference 2), are used to clarify the nature of the "key assumptions." A "key assumption" is one that is made in response to a key source of model uncertainty in the knowledge that a different reasonable alternative assumption would produce different results, or an assumption that results in an approximation made for modeling convenience in the knowledge that a more detailed model would produce different results. For the base PRA, the term"different results" refers to a change in the risk profile [e.g., total core damage frequency (CDF) and total large early release frequency (LERF), the set of initiating events and accident sequences that contribute most to CDF and to LERF, and the associated changes in insights derived from the changes in the risk profile]. | ||
A "reasonable alternative" assumption is one that has broad acceptance within the technical community and for which the technical basis for Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 4 consideration is at least as sound as that of the assumption being challenged. | A "reasonable alternative" assumption is one that has broad acceptance within the technical community and for which the technical basis for Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 4 consideration is at least as sound as that of the assumption being challenged. | ||
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* Loss of Off-site Power (LOOP) Frequency* Loss of Off-site Power at Switchyard (LOSP) Associated Non-Recovery Probabilities | * Loss of Off-site Power (LOOP) Frequency* Loss of Off-site Power at Switchyard (LOSP) Associated Non-Recovery Probabilities | ||
* Battery Life Assumptions RCP Seal Leak or Rupture RCP Seal Leak or Rupture is not modeled as a loss of RCS Inventory safety function. | * Battery Life Assumptions RCP Seal Leak or Rupture RCP Seal Leak or Rupture is not modeled as a loss of RCS Inventory safety function. | ||
Based on Westinghouse WCAP-1 5749 (Reference | Based on Westinghouse WCAP-1 5749 (Reference | ||
: 8) and pump seal vendor information, it was concluded that because of the very tight clearances, leakage into the seal package from the RCS is limited to about 17 gallons per minute per pump. Each of the four RCPs has a seal package which consists of three seals. As a result, even if the seal package on all four RCPs failed, the total leak rate would be within the capacity of two charging pumps and does not qualify as a LOCA. An analysis was performed showing that continuing to model RCP seal leakage and requiring charging pumps to mitigate the leakage represented an insignificant contribution to CDF or LERF, even assuming one of the three seals on each pump failed. The analysis also showed that modeling catastrophic failure due to operator failure to secure the pumps upon loss of cooling and seal injection was an insignificant contributor to CDF or LERF.LOCA Frequencies NUREG/CR-6928 "Industry-Average Performance for Components and Initiating Events at U.S. Commercial Nuclear Power Plants" (Reference | : 8) and pump seal vendor information, it was concluded that because of the very tight clearances, leakage into the seal package from the RCS is limited to about 17 gallons per minute per pump. Each of the four RCPs has a seal package which consists of three seals. As a result, even if the seal package on all four RCPs failed, the total leak rate would be within the capacity of two charging pumps and does not qualify as a LOCA. An analysis was performed showing that continuing to model RCP seal leakage and requiring charging pumps to mitigate the leakage represented an insignificant contribution to CDF or LERF, even assuming one of the three seals on each pump failed. The analysis also showed that modeling catastrophic failure due to operator failure to secure the pumps upon loss of cooling and seal injection was an insignificant contributor to CDF or LERF.LOCA Frequencies NUREG/CR-6928 "Industry-Average Performance for Components and Initiating Events at U.S. Commercial Nuclear Power Plants" (Reference | ||
: 9) restated the results from NUREG-1 829 "Estimating Loss-of-Coolant Accident (LOCA)Frequencies through the Elicitation Process" (Reference 10). The LOCA frequencies are based upon expert elicitations. | : 9) restated the results from NUREG-1 829 "Estimating Loss-of-Coolant Accident (LOCA)Frequencies through the Elicitation Process" (Reference 10). The LOCA frequencies are based upon expert elicitations. | ||
The LOCA sizes identified by the NRC are different from those estimated for PVNGS. For PVNGS, a small LOCA Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 5 is that of an equivalent flow area <0.03 sq ft; a medium LOCA equivalent diameter is between 0.03 and 0.3 sq ft; and a large LOCA is one of >0.3 sq ft.LOOP Frequency The national LOOP data presented in the latest EPRI events report 1002987 (Reference | The LOCA sizes identified by the NRC are different from those estimated for PVNGS. For PVNGS, a small LOCA Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 5 is that of an equivalent flow area <0.03 sq ft; a medium LOCA equivalent diameter is between 0.03 and 0.3 sq ft; and a large LOCA is one of >0.3 sq ft.LOOP Frequency The national LOOP data presented in the latest EPRI events report 1002987 (Reference | ||
: 5) and 100980 (Reference | : 5) and 100980 (Reference | ||
: 6) was used to obtain point-estimates for switchyard centered and severe weather related LOOP frequencies. | : 6) was used to obtain point-estimates for switchyard centered and severe weather related LOOP frequencies. | ||
The EPRI Reports provide that the generic LOOP data is subject to user modifications and screenings to fit the local plant designs and environmental conditions. | The EPRI Reports provide that the generic LOOP data is subject to user modifications and screenings to fit the local plant designs and environmental conditions. | ||
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Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 6 (a) EPRI's Seismic Margins Analysis (0.3g Review Level Earthquake) to identify vulnerabilities to seismic events;(b) Fire Induced Vulnerability Evaluation (FIVE) (including NRC prescribed enhancements) to identify vulnerabilities due to internal fires; and (c) Utilization of the screening approach described in NUREG-1407 (Reference | Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 6 (a) EPRI's Seismic Margins Analysis (0.3g Review Level Earthquake) to identify vulnerabilities to seismic events;(b) Fire Induced Vulnerability Evaluation (FIVE) (including NRC prescribed enhancements) to identify vulnerabilities due to internal fires; and (c) Utilization of the screening approach described in NUREG-1407 (Reference | ||
: 4) to identify potential vulnerabilities due to high winds, external floods, and transportation and nearby facility accidents. | : 4) to identify potential vulnerabilities due to high winds, external floods, and transportation and nearby facility accidents. | ||
The NEI 04-10 (Reference | The NEI 04-10 (Reference | ||
: 1) guidance takes these methodologies into account.In cases where these methodologies cannot be used for an STI change evaluation, qualitative or bounding analysis will be utilized to provide justification for the acceptability of the proposed STI change. PVNGS will follow the NEI 04-10 (Reference | : 1) guidance takes these methodologies into account.In cases where these methodologies cannot be used for an STI change evaluation, qualitative or bounding analysis will be utilized to provide justification for the acceptability of the proposed STI change. PVNGS will follow the NEI 04-10 (Reference | ||
: 1) guidance to assess the fire and seismic risk associated with STI changes. | : 1) guidance to assess the fire and seismic risk associated with STI changes. | ||
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NOTE--------------- | NOTE--------------- | ||
: 1. Only applicable when COLSS is out of service. With COLSS in service, LHR is continuously monitored. | : 1. Only applicable when COLSS is out of service. With COLSS in service, LHR is continuously monitored. | ||
: 2. Not required to be performed until 2 hours after MODE 1 with THERMAL POWER> 20% RTP.Verify LHR, local power limits.as indicated on any OPERABLE density channel, is within its 2 h-hei- <- Isr 31 days <-ýý1 SR 3.2.1.2 Verify the COLSS margin alarm actuates at a THERMAL POWER equal to or less than the core power operating limit based on LHR.PALO VERDE UNITS 1,2,3 3.2.1-2 AMENDMENT NO. 44-7 | : 2. Not required to be performed until 2 hours after MODE 1 with THERMAL POWER> 20% RTP.Verify LHR, local power limits.as indicated on any OPERABLE density channel, is within its 2 h-hei- <- Isr 31 days <-ýý1 SR 3.2.1.2 Verify the COLSS margin alarm actuates at a THERMAL POWER equal to or less than the core power operating limit based on LHR.PALO VERDE UNITS 1,2,3 3.2.1-2 AMENDMENT NO. 44-7 3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify measured Fy obtained using the Incore Detector System is equal to or less than the value of F' used in the COLSS and CPCs.Once after each fuel loading with THERMAL POWER > 40% RTP but prior to operations above 70% RTP AND 3!eF-PDa r Inser 1 PALO VERDE UNITS 1,2,3 3.2.2-2 AMENDMENT NO. 4-1.7 Tq 3.2.3ýSURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 ----------------- | ||
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify measured Fy obtained using the Incore Detector System is equal to or less than the value of F' used in the COLSS and CPCs.Once after each fuel loading with THERMAL POWER > 40% RTP but prior to operations above 70% RTP AND 3!eF-PDa r Inser 1 PALO VERDE UNITS 1,2,3 3.2.2-2 AMENDMENT NO. 4-1.7 Tq 3.2.3ýSURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 ----------------- | |||
NOTES-------------- | NOTES-------------- | ||
: 1. Only applicable when COLSS is out of service. With COLSS in service, this parameter is continuously monitored. | : 1. Only applicable when COLSS is out of service. With COLSS in service, this parameter is continuously monitored. | ||
| Line 261: | Line 229: | ||
-Shutdown 3.3.2 SURVEILLANCE REQUIREMENTS (continued) | -Shutdown 3.3.2 SURVEILLANCE REQUIREMENTS (continued) | ||
SURVEILLANCE FREQUENCY-NOTE---------------4 SR 3.3.2.5---------------N O T E ----------Neutron detectors are excluded.Verify RPS RESPONSE TIME is within limits.18 months ona STA-DERED TOST R A -S I S In s ~e rt1 J.PALO VERDE UNITS 1,2,3 3.3.2-4 AMENDMENT NO. 414 CEACs 3.3.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY+SR 3.3.3.1 Perform a CHANNEL CHECK.42-hei~& *- Insert I SR 3.3.3.2 Deletedf SR 3.3.3.3 Perform a CHANNEL FUNCTIONAL TEST.92 ays<&SR 3.3.3.4 Perform a CHANNEL CALIBRATION. | SURVEILLANCE FREQUENCY-NOTE---------------4 SR 3.3.2.5---------------N O T E ----------Neutron detectors are excluded.Verify RPS RESPONSE TIME is within limits.18 months ona STA-DERED TOST R A -S I S In s ~e rt1 J.PALO VERDE UNITS 1,2,3 3.3.2-4 AMENDMENT NO. 414 CEACs 3.3.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY+SR 3.3.3.1 Perform a CHANNEL CHECK.42-hei~& *- Insert I SR 3.3.3.2 Deletedf SR 3.3.3.3 Perform a CHANNEL FUNCTIONAL TEST.92 ays<&SR 3.3.3.4 Perform a CHANNEL CALIBRATION. | ||
18 Ronths SR 3.3.3.5 Perform a CHANNEL FUNCTIONAL TEST.1 8 menl'h&PALO VERDE UNITS 1,2,3 3.3.3-4 AMENDMENT NO. 159, 179 RPS Logic and Trip Initiation | 18 Ronths SR 3.3.3.5 Perform a CHANNEL FUNCTIONAL TEST.1 8 menl'h&PALO VERDE UNITS 1,2,3 3.3.3-4 AMENDMENT NO. 159, 179 RPS Logic and Trip Initiation 3.3.4 ACTIONS (continued) | ||
CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Be in MODE 3. 6 hours associated Completion Time of Condition A, AND B, or D not met.E.2 Open all RTCBs. 6 hours OR One or more Functions with more than one Manual Trip, Matrix Logic, Initiation Logic, or RTCB channel inoperable for reasons other than Condition A or D.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform a CHANNEL FUNCTIONAL TEST on each RPS Logic channel and Manual Trip channel.92--- Insert 11 SR 3.3.4.2 Perform a CHANNEL FUNCTIONAL TEST, including separate verification of the undervoltage and shunt trips, on each RTCB.~1*SR 3.3.4.3 Perform RTCB.a CHANNEL FUNCTIONAL TEST on each 1 ..Insert 11 PALO VERDE UNITS 1,2,3 3.3.4-3 AMENDMENT NO. -14W ESFAS Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 Perform a CHANNEL CHECK of each ESFAS channel.12 dha's <--InsertlI 9<dy -- Insert 11-1~SR 3.3.5.2 Perform a CHANNEL FUNCTIONAL TEST of each ESFAS channel..1.SR 3.3.5.3 Perform a CHANNEL CALIBRATION of each ESFAS channel, including bypass removal functions. | |||
(continued) | |||
CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Be in MODE 3. 6 hours associated Completion Time of Condition A, AND B, or D not met.E.2 Open all RTCBs. 6 hours OR One or more Functions with more than one Manual Trip, Matrix Logic, Initiation Logic, or RTCB channel inoperable for reasons other than Condition A or D.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform a CHANNEL FUNCTIONAL TEST on each RPS Logic channel and Manual Trip channel.92--- Insert 11 SR 3.3.4.2 Perform a CHANNEL FUNCTIONAL TEST, including separate verification of the undervoltage and shunt trips, on each RTCB.~1*SR 3.3.4.3 Perform RTCB.a CHANNEL FUNCTIONAL TEST on each 1 ..Insert 11 PALO VERDE UNITS 1,2,3 3.3.4-3 AMENDMENT NO. -14W ESFAS Instrumentation | |||
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 Perform a CHANNEL CHECK of each ESFAS channel.12 dha's <--InsertlI 9<dy -- Insert 11-1~SR 3.3.5.2 Perform a CHANNEL FUNCTIONAL TEST of each ESFAS channel..1.SR 3.3.5.3 Perform a CHANNEL CALIBRATION of each ESFAS channel, including bypass removal functions. | |||
Ig-MeRthq 1-SR 3.3.5.4 Verify ESF RESPONSE TIME is within limits.STAEREDE TEST SR 3.3.5.5 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal channel. 92 days prior to each reactor startup PALO VERDE UNITS 1,2,3 3.3.5-3 AMENDMENT NO. 44-7 ESFAS Logic and Manual Trip 3.3.6 ACTIONS (continued) | Ig-MeRthq 1-SR 3.3.5.4 Verify ESF RESPONSE TIME is within limits.STAEREDE TEST SR 3.3.5.5 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal channel. 92 days prior to each reactor startup PALO VERDE UNITS 1,2,3 3.3.5-3 AMENDMENT NO. 44-7 ESFAS Logic and Manual Trip 3.3.6 ACTIONS (continued) | ||
CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 Be in MODE 3. 6 hours associated Completion Time of Conditions for AND Safety Injection Actuation Signal, F.2 Be in MODE 5. 36 hours Containment Isolation Actuation Signal, or Reci rcul ati on Actuation Signal not met..SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.6.1 ----------------- | CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 Be in MODE 3. 6 hours associated Completion Time of Conditions for AND Safety Injection Actuation Signal, F.2 Be in MODE 5. 36 hours Containment Isolation Actuation Signal, or Reci rcul ati on Actuation Signal not met..SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.6.1 ----------------- | ||
| Line 348: | Line 309: | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one SDC train is in operation. | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one SDC train is in operation. | ||
4.12-hewmg 7-4aY&SR 3.4.8.2 Verify correct breaker alignment and indicated power available to the required SDC pump that is not in operation. | 4.12-hewmg 7-4aY&SR 3.4.8.2 Verify correct breaker alignment and indicated power available to the required SDC pump that is not in operation. | ||
PALO VERDE UNITS 1,2,3 3.4.8-2 AMENDMENT NO. 114 Pressurizer | PALO VERDE UNITS 1,2,3 3.4.8-2 AMENDMENT NO. 114 Pressurizer 3.4.9 ACTIONS (continued) | ||
(continued) | |||
CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time of Condition B AND not met.C.2 Be in MODE 4. 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water< 56%level is _> 27% and 92-days <-1 SR 3.4.9.2 Verify capacity of each required group of pressurizer heaters 125 kW.PALO VERDE UNITS 1,2,3 3.4.9-2 AMENDMENT NO. 44 Pressurizer Safety Valves-MODE 4 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 Verify the required pressurizer safety In accordance valve is OPERABLE in accordance with the with the Inservice Testing Program. Following Inservice testing, lift settings shall be within Testing Program+/- 1%.SR 3.4.11.2----------------- | CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time of Condition B AND not met.C.2 Be in MODE 4. 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water< 56%level is _> 27% and 92-days <-1 SR 3.4.9.2 Verify capacity of each required group of pressurizer heaters 125 kW.PALO VERDE UNITS 1,2,3 3.4.9-2 AMENDMENT NO. 44 Pressurizer Safety Valves-MODE 4 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 Verify the required pressurizer safety In accordance valve is OPERABLE in accordance with the with the Inservice Testing Program. Following Inservice testing, lift settings shall be within Testing Program+/- 1%.SR 3.4.11.2----------------- | ||
NOTE-------------- | NOTE-------------- | ||
| Line 385: | Line 343: | ||
PALO VERDE UNITS 1,2,3 3.4.17-2 AMENDMENT NO. 444 RCS Specific Activity 3.4.17 SURVEILLANCE REQUIREMENTS (continued) | PALO VERDE UNITS 1,2,3 3.4.17-2 AMENDMENT NO. 444 RCS Specific Activity 3.4.17 SURVEILLANCE REQUIREMENTS (continued) | ||
SURVEILLANCE I FREQUENCY SR 3.4.17.2 Verify reactor coolant DOSE EQUIVALENT 1-131 specific activity< 1.0 pCi/gm.------ NOTE ------Only required to be performed in MODE 1.AND Between 2 and 6 hours after THERMAL POWER change of 15% RTP within a 1 hour period SR 3.4.17.3-------- -------NOTE------------- | SURVEILLANCE I FREQUENCY SR 3.4.17.2 Verify reactor coolant DOSE EQUIVALENT 1-131 specific activity< 1.0 pCi/gm.------ NOTE ------Only required to be performed in MODE 1.AND Between 2 and 6 hours after THERMAL POWER change of 15% RTP within a 1 hour period SR 3.4.17.3-------- -------NOTE------------- | ||
Not required to be performed until 31 days after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours.Determine E from a sample taken in MODE 1 after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours.184 days <-ýý1 PALO VERDE UNITS 1,2,3 3.4.17-3 AMENDMENT NO. 1-1,1 SITs-Operating | Not required to be performed until 31 days after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours.Determine E from a sample taken in MODE 1 after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours.184 days <-ýý1 PALO VERDE UNITS 1,2,3 3.4.17-3 AMENDMENT NO. 1-1,1 SITs-Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each SIT isolation valve is fully open.SR 3.5.1.2 Verify borated water volume in each SIT is> 28% narrow range and 72% narrow range.SR 3.5.1.3 Verify nitrogen cover pressure in each SIT is 600 psig and 625 psig.SR 3.5.1.4 Verify boron concentration | ||
> 2300 ppm and 4400 ppm.in each SIT is 12 ho'r-r, 12 hm'-rs --- Is r AND----- NOTE ------Only required to be performed for affected SIT Once within 6 hours, whenever a SIT is drained to maintain the contained borated water level within the limits of SR 3.5.1.2.SR 3.5.1.5 Verify power is removed from each SIT isolation valve operator.31-day& -PALO VERDE UNITS 1,2,3 3.5.1-2 AMENDMENT NO. -14W SITs-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify each required SIT isolation valve is fully open when pressurizer pressure is> 430 psia.12 hours+SR 3.5.2.2 Verify borated water volume in each required SIT is: a. For four OPERABLE SITs, > 39% wide range indication and < 83% wide range indication. | |||
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each SIT isolation valve is fully open.SR 3.5.1.2 Verify borated water volume in each SIT is> 28% narrow range and 72% narrow range.SR 3.5.1.3 Verify nitrogen cover pressure in each SIT is 600 psig and 625 psig.SR 3.5.1.4 Verify boron concentration | |||
> 2300 ppm and 4400 ppm.in each SIT is 12 ho'r-r, 12 hm'-rs --- Is r AND----- NOTE ------Only required to be performed for affected SIT Once within 6 hours, whenever a SIT is drained to maintain the contained borated water level within the limits of SR 3.5.1.2.SR 3.5.1.5 Verify power is removed from each SIT isolation valve operator.31-day& -PALO VERDE UNITS 1,2,3 3.5.1-2 AMENDMENT NO. -14W SITs-Shutdown | |||
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify each required SIT isolation valve is fully open when pressurizer pressure is> 430 psia.12 hours+SR 3.5.2.2 Verify borated water volume in each required SIT is: a. For four OPERABLE SITs, > 39% wide range indication and < 83% wide range indication. | |||
OR b. For three OPERABLE SITs, >range indication and < 83%indication. | OR b. For three OPERABLE SITs, >range indication and < 83%indication. | ||
60% wide wide range!.2 he'-rs <-1 Insert 1 ai dayrs <---nsrI AND. -Insert 1 AND SR 3.5.2.3 Verify nitrogen cover pressure in each required SIT is 260 psig and 625 psig.SR 3.5.2.4 Verify boron concentration in each required SIT is 2300 ppm and ! 4400 ppm.----- NOTE ------Only required to be performed for affected SIT Once within 6 hours, whenever a required SIT is drained to maintain the contai ned borated water level within the limits of SR 3.5.2.2.(continued) | 60% wide wide range!.2 he'-rs <-1 Insert 1 ai dayrs <---nsrI AND. -Insert 1 AND SR 3.5.2.3 Verify nitrogen cover pressure in each required SIT is 260 psig and 625 psig.SR 3.5.2.4 Verify boron concentration in each required SIT is 2300 ppm and ! 4400 ppm.----- NOTE ------Only required to be performed for affected SIT Once within 6 hours, whenever a required SIT is drained to maintain the contai ned borated water level within the limits of SR 3.5.2.2.(continued) | ||
PALO VERDE UNITS 1,2,3 3.5.2-2 AMENDMENT NO. 4-14 SITs-Shutdown | PALO VERDE UNITS 1,2,3 3.5.2-2 AMENDMENT NO. 4-14 SITs-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued) | ||
REQUIREMENTS (continued) | |||
SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify power is removed from each required SIT isolation valve operator when pressurizer pressure is 1500 psia.PALO VERDE UNITS 1,2,3 3.5.2-3 AMENDMENT NO. 4ý- | SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify power is removed from each required SIT isolation valve operator when pressurizer pressure is 1500 psia.PALO VERDE UNITS 1,2,3 3.5.2-3 AMENDMENT NO. 4ý- | ||
ECCS -Operating 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify each ECCS 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.,4 da... <- Insert I i SR 3.5.3.2 Verify ECCS piping is full of water.31 ays<&SR 3.5.3.3 Verify each ECCS pump develops the required In accordance differential pressure at the flow test with the point. Inservice Testing Program SR 3.5.3.4 Verify each ECCS automatic valve that is not locked, sealed, or otherwise secured in position, in the flow path actuates to the correct position on an actual or simulated actuation signal.8AmoRths, SR 3.5.3.5 Verify each ECCS pump starts automatically on an actual or simulated actuation signal 8-months 4- Insert 1]SR 3.5.3.6 Verify each LPSI pump stops simulated actuation signal.on an actual or 19 months (continued) | ECCS -Operating 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify each ECCS 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.,4 da... <- Insert I i SR 3.5.3.2 Verify ECCS piping is full of water.31 ays<&SR 3.5.3.3 Verify each ECCS pump develops the required In accordance differential pressure at the flow test with the point. Inservice Testing Program SR 3.5.3.4 Verify each ECCS automatic valve that is not locked, sealed, or otherwise secured in position, in the flow path actuates to the correct position on an actual or simulated actuation signal.8AmoRths, SR 3.5.3.5 Verify each ECCS pump starts automatically on an actual or simulated actuation signal 8-months 4- Insert 1]SR 3.5.3.6 Verify each LPSI pump stops simulated actuation signal.on an actual or 19 months (continued) | ||
| Line 533: | Line 479: | ||
SURVEILLANCE FREQUENCY SR 3.8.4.8---------------- | SURVEILLANCE FREQUENCY SR 3.8.4.8---------------- | ||
NOTE--------------- | NOTE--------------- | ||
This Surveillance shall not be performed in MODE 1, 2, 3, or 4.Verify battery capacity is 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test.69 menths AND 12 months when battery shows degradation or has reached 85%of the expected life with capacity< 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected life with capacity 100% of manufacturer's rating PALO VERDE UNITS 1,2,3 3.8.4-4 AMENDMENT NO. 196, 159 Battery Cell Parameters | This Surveillance shall not be performed in MODE 1, 2, 3, or 4.Verify battery capacity is 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test.69 menths AND 12 months when battery shows degradation or has reached 85%of the expected life with capacity< 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected life with capacity 100% of manufacturer's rating PALO VERDE UNITS 1,2,3 3.8.4-4 AMENDMENT NO. 196, 159 Battery Cell Parameters 3.8.6 ACTIONS (continued) | ||
(continued) | |||
CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Declare associated Immediately associated Completion battery inoperable. | CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Declare associated Immediately associated Completion battery inoperable. | ||
Time of Condition A not met.OR One or more batteries with average electrolyte temperature of the representative cells< 60 0 F.OR One or more batteries with one or more battery cell parameters not within Category C limits.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet Table 3.8.6-1 Category A limits.7 days <(continued) | Time of Condition A not met.OR One or more batteries with average electrolyte temperature of the representative cells< 60 0 F.OR One or more batteries with one or more battery cell parameters not within Category C limits.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet Table 3.8.6-1 Category A limits.7 days <(continued) | ||
PALO VERDE UNITS 1,2,3 3.8.6-2 AMENDMENT NO. 447 Battery Cell Parameters | PALO VERDE UNITS 1,2,3 3.8.6-2 AMENDMENT NO. 447 Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued) | ||
REQUIREMENTS (continued) | |||
SURVEILLANCE FREQUENCY-t SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6-1 Category B limits.92sdays AND Once within 7 days after battery discharge< 105 V AND Once within 7 days after battery overcharge | SURVEILLANCE FREQUENCY-t SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6-1 Category B limits.92sdays AND Once within 7 days after battery discharge< 105 V AND Once within 7 days after battery overcharge | ||
> 150 V SR 3.8.6.3 Verify average electrolyte temperature of representative cells is 60 0 F.92 days,<-PALO VERDE UNITS 1,2,3 3.8.6-3 AMENDMENT NO. 11-7 Inverters | > 150 V SR 3.8.6.3 Verify average electrolyte temperature of representative cells is 60 0 F.92 days,<-PALO VERDE UNITS 1,2,3 3.8.6-3 AMENDMENT NO. 11-7 Inverters | ||
| Line 554: | Line 493: | ||
A.2.4 Initiate actions to Immediately restore required AC, DC, and AC vital instrument bus electrical power distribution subsystems to OPERABLE status.AND A.2.5 Declare associated Immediately required shutdown cooling subsystem(s) inoperable and not in operation. | A.2.4 Initiate actions to Immediately restore required AC, DC, and AC vital instrument bus electrical power distribution subsystems to OPERABLE status.AND A.2.5 Declare associated Immediately required shutdown cooling subsystem(s) inoperable and not in operation. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to required AC, DC, and AC vital instrument bus electrical power distribution subsystems. | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to required AC, DC, and AC vital instrument bus electrical power distribution subsystems. | ||
7-days <-ý1 PALO VERDE UNITS 1,2,3 3.8.10-2 AMENDMENT NO. 44-7 Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS | 7-days <-ý1 PALO VERDE UNITS 1,2,3 3.8.10-2 AMENDMENT NO. 44-7 Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentrations of the Reactor Coolant System and the refueling canal shall be maintained within the limit specified in the COLR.APPLICABILITY: | ||
Concentration LCO 3.9.1 Boron concentrations of the Reactor Coolant System and the refueling canal shall be maintained within the limit specified in the COLR.APPLICABILITY: | |||
MODE 6.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration A.1 Suspend CORE Immediately not within limit. ALTERATIONS. | MODE 6.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration A.1 Suspend CORE Immediately not within limit. ALTERATIONS. | ||
AND A.2 Suspend positive Immediately reactivity additions. | AND A.2 Suspend positive Immediately reactivity additions. | ||
AND A.3 Initiate action to Immediately restore boron concentration to within limit.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit specified in the COLR.72 h--he-PALO VERDE UNITS 1,2,3 3.9.1-1 AMENDMENT NO. 44 Nuclear Instrumentation | AND A.3 Initiate action to Immediately restore boron concentration to within limit.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit specified in the COLR.72 h--he-PALO VERDE UNITS 1,2,3 3.9.1-1 AMENDMENT NO. 44 Nuclear Instrumentation 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Perform CHANNEL CHECK.4.SR 3.9.2.2------------------- | ||
NOTE--------------- | |||
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Perform CHANNEL CHECK.4.SR 3.9.2.2------------------- | |||
NOTE--------------- | |||
Neutron detectors are excluded from CHANNEL CALIBRATION. | Neutron detectors are excluded from CHANNEL CALIBRATION. | ||
Perform CHANNEL CALIBRATION. | Perform CHANNEL CALIBRATION. | ||
12 h--he. <PALO VERDE UNITS 1,2,3 3.9.2-2 AMENDMENT NO. 1-14 Containment Penetrations | 12 h--he. <PALO VERDE UNITS 1,2,3 3.9.2-2 AMENDMENT NO. 1-14 Containment Penetrations 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify each required containment penetration is in the required status.4 SR 3.9.3.2 Verify each required containment purge and exhaust valve actuates to the isolation position on an actual or simulated actuation signal.SR 3.9.3.3 Verify the capability to close the equipment hatch, if open PALO VERDE UNITS 1,2,3 3.9.3-2 AMENDMENT NO. 443 SDC and Cool ant Circulation | ||
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify each required containment penetration is in the required status.4 SR 3.9.3.2 Verify each required containment purge and exhaust valve actuates to the isolation position on an actual or simulated actuation signal.SR 3.9.3.3 Verify the capability to close the equipment hatch, if open PALO VERDE UNITS 1,2,3 3.9.3-2 AMENDMENT NO. 443 SDC and Cool ant Circulation | |||
-High Water Level 3.9.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) | -High Water Level 3.9.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) | ||
A.4 Close all containment 4 hours penetrations providing direct access from containment atmosphere to outside atmosphere. | A.4 Close all containment 4 hours penetrations providing direct access from containment atmosphere to outside atmosphere. | ||
| Line 583: | Line 511: | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify required SDC loops are OPERABLE and one SDC loop is in operation. | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify required SDC loops are OPERABLE and one SDC loop is in operation. | ||
12 heurs 7 daY6 SR 3.9.5.2 Verify correct breaker alignment and indicated power available to the required SDC pump that is not in operation. | 12 heurs 7 daY6 SR 3.9.5.2 Verify correct breaker alignment and indicated power available to the required SDC pump that is not in operation. | ||
PALO VERDE UNITS 1,2,3 3.9.5-2 AMENDMENT NO. 4-14 Refueling Water Level-Fuel Assemblies 3.9.6 3.9 REFUELING OPERATIONS | PALO VERDE UNITS 1,2,3 3.9.5-2 AMENDMENT NO. 4-14 Refueling Water Level-Fuel Assemblies 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Refueling Water Level-Fuel Assemblies LCO 3.9.6 APPLICABILITY: | ||
Water Level-Fuel Assemblies LCO 3.9.6 APPLICABILITY: | |||
Refueling water level shall be maintained 23 ft above the top of the reactor vessel flange.During movement of fuel assemblies within containment when either the fuel assemblies being moved or the fuel assemblies seated within the reactor vessel are irradiated. | Refueling water level shall be maintained 23 ft above the top of the reactor vessel flange.During movement of fuel assemblies within containment when either the fuel assemblies being moved or the fuel assemblies seated within the reactor vessel are irradiated. | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling water level A.1 Suspend movement of Immediately not within limit, fuel assemblies within containment. | ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling water level A.1 Suspend movement of Immediately not within limit, fuel assemblies within containment. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify refueling above the top of water level is 23 ft reactor vessel flange.24 he~wr-;<& | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify refueling above the top of water level is 23 ft reactor vessel flange.24 he~wr-;<& | ||
_PALO VERDE UNITS 1,2,3 3.9.6-1 AMENDMENT NO. 44-7 Refueling Water Level-CEAs 3.9.7 3.9 REFUELING OPERATIONS | _PALO VERDE UNITS 1,2,3 3.9.6-1 AMENDMENT NO. 44-7 Refueling Water Level-CEAs 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Refueling Water Level-CEAs LCO 3.9.7 APPLICABILITY: | ||
Water Level-CEAs LCO 3.9.7 APPLICABILITY: | |||
Refueling water level shall be maintained 23 ft above the top of irradiated fuel assemblies seated within the reactor vessel.During movement of CEAs within the reactor vessel, when the fuel assemblies seated within the reactor vessel are irradiated. | Refueling water level shall be maintained 23 ft above the top of irradiated fuel assemblies seated within the reactor vessel.During movement of CEAs within the reactor vessel, when the fuel assemblies seated within the reactor vessel are irradiated. | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETIONTIME A. Refueling water level A.1 Suspend movement of Immediately not within limit. CEAs within the reactor vessel.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling above the top of seated within the water level is 23 ft irradiated fuel assemblies reactor vessel.24 hour, ----PALO VERDE UNITS 1,2,3 3.9.7-1 AMENDMENT NO. 144 Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.17 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 Essential Filtration System (CREFS), 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. | ACTIONS CONDITION REQUIRED ACTION COMPLETIONTIME A. Refueling water level A.1 Suspend movement of Immediately not within limit. CEAs within the reactor vessel.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling above the top of seated within the water level is 23 ft irradiated fuel assemblies reactor vessel.24 hour, ----PALO VERDE UNITS 1,2,3 3.9.7-1 AMENDMENT NO. 144 Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.17 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 Essential Filtration System (CREFS), 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 whole body or its equivalent to any part of the body for the duration of the accident. | 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 whole body or its equivalent to any part of the body 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. | 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 in accordance with the testing methods and the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Determining Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.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 of one train of the CREFS, operating at the flow rate required by the VFTP, at a Frequency of 18 months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the periodic assessment of the CRE boundary.e. The quantitative limits on unfiltered air inleakage into the CRE shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph | : c. Requirements for (i) determining the unfiltered air inleakage past the CRE boundary in accordance with the testing methods and the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Determining Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.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 of one train of the CREFS, operating at the flow rate required by the VFTP, at a Frequency of 18 months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the periodic assessment of the CRE boundary.e. The quantitative limits on unfiltered air inleakage into the CRE shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph | ||
: c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences. | : c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences. | ||
: 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. | : 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. | ||
| Line 628: | Line 548: | ||
: 1. Only applicable when COLSS is out of*service. | : 1. Only applicable when COLSS is out of*service. | ||
With COLSS in service, LHR is continuously monitored. | With COLSS in service, LHR is continuously monitored. | ||
: 2. Not required to be performed until 2 hours after MODE 1 with THERMAL POWER> 20% RTP.Verify LHR, as indicated on any OPERABLE local power density channel, is within its limits.In accordance with the Surveillance Frequency Control Program SR 3.2.1.2 Verify the COLSS margin alarm actuates at a In accordance THERMAL POWER equal to or less than the with the core power operating limit based on LHR. Surveillance Frequency Control Program PALO VERDE UNITS 1.2,3 3.2.1-2 AMENDMENT NO. ý, | : 2. Not required to be performed until 2 hours after MODE 1 with THERMAL POWER> 20% RTP.Verify LHR, as indicated on any OPERABLE local power density channel, is within its limits.In accordance with the Surveillance Frequency Control Program SR 3.2.1.2 Verify the COLSS margin alarm actuates at a In accordance THERMAL POWER equal to or less than the with the core power operating limit based on LHR. Surveillance Frequency Control Program PALO VERDE UNITS 1.2,3 3.2.1-2 AMENDMENT NO. ý, | ||
3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify measured Fy obtained using the Incore Detector System is equal to or less than the value of F' used in the COLSS and CPCs.Once after each fuel loading with THERMAL POWER > 40% RTP but prior to operations above 70% RTP AND In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.2.2-2 AMENDMENT NO. ;4-ý, | |||
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify measured Fy obtained using the Incore Detector System is equal to or less than the value of F' used in the COLSS and CPCs.Once after each fuel loading with THERMAL POWER > 40% RTP but prior to operations above 70% RTP AND In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.2.2-2 AMENDMENT NO. ;4-ý, | |||
Tq 3. 2.3ýSURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 ----------------- | Tq 3. 2.3ýSURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 ----------------- | ||
NOTES-------------- | NOTES-------------- | ||
| Line 698: | Line 615: | ||
NOTE--------------- | NOTE--------------- | ||
Neutron detectors are excluded.Verify RPS RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.2-4 AMENDMENT NO. 144, CEACs 3.3.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform a CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.3.2 Deleted SR 3.3.3.3 Perform a CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.3.4 Perform a CHANNEL CALIBRATION. | Neutron detectors are excluded.Verify RPS RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.2-4 AMENDMENT NO. 144, CEACs 3.3.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform a CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.3.2 Deleted SR 3.3.3.3 Perform a CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.3.4 Perform a CHANNEL CALIBRATION. | ||
In accordance with the Surveillance Frequency Control Program SR 3.3.3.5 Perform a CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.3-4 AMENDMENT NO. ;;-9, RPS Logic and Trip Initiation | In accordance with the Surveillance Frequency Control Program SR 3.3.3.5 Perform a CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.3-4 AMENDMENT NO. ;;-9, RPS Logic and Trip Initiation 3.3.4 ACTIONS (continued) | ||
CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Be in MODE 3. 6 hours associated Completion AND Time of Condition A, B. or D not met. E.2 Open all RTCBs. 6 hours OR One or more Functions with more than one Manual Trip, Matrix Logic, Initiation Logic, or RTCB channel inoperable for reasons other than Condition A or D.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform a CHANNEL FUNCTIONAL TEST on each In accordance RPS Logic channel and Manual Trip channel. with the Surveillance Frequency Control Program SR 3.3.4.2 Perform a CHANNEL FUNCTIONAL TEST, In accordance including separate verification of the with the undervoltage and shunt trips, on each RTCB. Surveillance Frequency Control Program SR 3.3.4.3 Perform a CHANNEL FUNCTIONAL TEST on each In accordance RTCB. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.4-3 AMENDMENT NO. 14, ESFAS Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 Perform a CHANNEL CHECK of each ESFAS In accordance channel. with the Surveillance Frequency Control Program SR 3.3.5.2 Perform a CHANNEL FUNCTIONAL TEST of each In accordance ESFAS channel. with the Surveillance Frequency Control Program SR 3.3.5.3 Perform a CHANNEL CALIBRATION of each ESFAS In accordance channel, including bypass removal with the functions. | |||
(continued) | |||
CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Be in MODE 3. 6 hours associated Completion AND Time of Condition A, B. or D not met. E.2 Open all RTCBs. 6 hours OR One or more Functions with more than one Manual Trip, Matrix Logic, Initiation Logic, or RTCB channel inoperable for reasons other than Condition A or D.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform a CHANNEL FUNCTIONAL TEST on each In accordance RPS Logic channel and Manual Trip channel. with the Surveillance Frequency Control Program SR 3.3.4.2 Perform a CHANNEL FUNCTIONAL TEST, In accordance including separate verification of the with the undervoltage and shunt trips, on each RTCB. Surveillance Frequency Control Program SR 3.3.4.3 Perform a CHANNEL FUNCTIONAL TEST on each In accordance RTCB. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.4-3 AMENDMENT NO. 14, ESFAS Instrumentation | |||
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 Perform a CHANNEL CHECK of each ESFAS In accordance channel. with the Surveillance Frequency Control Program SR 3.3.5.2 Perform a CHANNEL FUNCTIONAL TEST of each In accordance ESFAS channel. with the Surveillance Frequency Control Program SR 3.3.5.3 Perform a CHANNEL CALIBRATION of each ESFAS In accordance channel, including bypass removal with the functions. | |||
Surveillance Frequency Control Program SR 3.3.5.4 Verify ESF RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program SR 3.3.5.5 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal channel. 92 days prior to each reactor startup PALO VERDE UNITS 1,2,3 3.3.5-3 AMENDMENT NO. ý44, ESFAS Logic and Manual Trip 3.3.6 ACTIONS (continued) | Surveillance Frequency Control Program SR 3.3.5.4 Verify ESF RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program SR 3.3.5.5 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal channel. 92 days prior to each reactor startup PALO VERDE UNITS 1,2,3 3.3.5-3 AMENDMENT NO. ý44, ESFAS Logic and Manual Trip 3.3.6 ACTIONS (continued) | ||
CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 Be in MODE 3. 6 hours associated Completion AND Time of Conditions for Safety Injection Actuation Signal, F.2 Be in MODE 5. 36 hours Containment Isolation Actuation Signal, or Reci rcul ati on Actuation Signal not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.6.1 ----------------- | CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 Be in MODE 3. 6 hours associated Completion AND Time of Conditions for Safety Injection Actuation Signal, F.2 Be in MODE 5. 36 hours Containment Isolation Actuation Signal, or Reci rcul ati on Actuation Signal not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.6.1 ----------------- | ||
| Line 798: | Line 708: | ||
In accordance with the Surveillance Frequency Control Program SR 3.4.8.2 Verify correct breaker alignment and In accordance indicated power available to the required with the SDC pump that is not in operation. | In accordance with the Surveillance Frequency Control Program SR 3.4.8.2 Verify correct breaker alignment and In accordance indicated power available to the required with the SDC pump that is not in operation. | ||
Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.8-2 AMENDMENT NO. | Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.8-2 AMENDMENT NO. | ||
Pressurizer | Pressurizer 3.4.9 ACTIONS (continued) | ||
(continued) | |||
CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion AND Time of Condition B not met. C.2 Be in MODE 4. 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is 27% and In accordance 56% with the Surveillance Frequency Control Program SR 3.4.9.2 Verify capacity of each required group of In accordance pressurizer heaters 125 kW. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.9-2 AMENDMENT NO. | CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion AND Time of Condition B not met. C.2 Be in MODE 4. 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is 27% and In accordance 56% with the Surveillance Frequency Control Program SR 3.4.9.2 Verify capacity of each required group of In accordance pressurizer heaters 125 kW. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.9-2 AMENDMENT NO. | ||
Pressurizer Safety Valves-MODE 4 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 Verify the required pressurizer safety In accordance valve is OPERABLE in accordance with the with the Inservice Testing Program. Following Inservice testing, lift settings shall be within Testing Program+/- 1%.SR 3.4.11.2 ------------------ | Pressurizer Safety Valves-MODE 4 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 Verify the required pressurizer safety In accordance valve is OPERABLE in accordance with the with the Inservice Testing Program. Following Inservice testing, lift settings shall be within Testing Program+/- 1%.SR 3.4.11.2 ------------------ | ||
| Line 840: | Line 747: | ||
SURVEILLANCE FREQUENCY SR 3.4.17.2 Verify reactor coolant DOSE EQUIVALENT 1-131 specific activity< 1.0 pCi/gm.-NOTE ------Only required to be performed in MODE 1.In accordance with the Surveillance Frequency Control Program AND Between 2 and 6 hours after THERMAL POWER change of 15% RTP within a 1 hour period SR 3.4.17.3-------- -------NOTE------------- | SURVEILLANCE FREQUENCY SR 3.4.17.2 Verify reactor coolant DOSE EQUIVALENT 1-131 specific activity< 1.0 pCi/gm.-NOTE ------Only required to be performed in MODE 1.In accordance with the Surveillance Frequency Control Program AND Between 2 and 6 hours after THERMAL POWER change of 15% RTP within a 1 hour period SR 3.4.17.3-------- -------NOTE------------- | ||
Not required to be performed until 31 days after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours.Determine E from a sample taken in MODE 1 after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours.In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.17-3 AMENDMENT NO. ý, | Not required to be performed until 31 days after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours.Determine E from a sample taken in MODE 1 after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours.In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.17-3 AMENDMENT NO. ý, | ||
SITs-Operating | SITs-Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each SIT isolation valve is fully In accordance open. with the Surveillance Frequency Control Program SR 3.5.1.2 Verify borated water volume in each SIT is In accordance 28% narrow range and 72% narrow range. with the Surveillance Frequency Control Program SR 3.5.1.3 Verify nitrogen cover pressure in each SIT In accordance is 600 psig and 625 psig. with the Surveillance Frequency Control Program (continued) | ||
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each SIT isolation valve is fully In accordance open. with the Surveillance Frequency Control Program SR 3.5.1.2 Verify borated water volume in each SIT is In accordance 28% narrow range and 72% narrow range. with the Surveillance Frequency Control Program SR 3.5.1.3 Verify nitrogen cover pressure in each SIT In accordance is 600 psig and 625 psig. with the Surveillance Frequency Control Program (continued) | |||
PALO VERDE UNITS 1,2,3 3.5.1-2 AMENDMENT NO. | PALO VERDE UNITS 1,2,3 3.5.1-2 AMENDMENT NO. | ||
SITs-Operating | SITs-Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued) | ||
REQUIREMENTS (continued) | |||
SURVEILLANCE FREQUENCY SR 3.5.1.4 Verify boron concentration in each SIT is> 2300 ppm and 4400 ppm.In accordance with the Surveillance Frequency Control Program AND----- NOTE ------Only required to be performed for affected SIT Once within 6 hours, whenever a SIT is drained to maintain the contai ned borated water level within the limits of SR 3.5.1.2.SR 3.5.1.5 Verify power is removed from each SIT In accordance isolation valve operator. | SURVEILLANCE FREQUENCY SR 3.5.1.4 Verify boron concentration in each SIT is> 2300 ppm and 4400 ppm.In accordance with the Surveillance Frequency Control Program AND----- NOTE ------Only required to be performed for affected SIT Once within 6 hours, whenever a SIT is drained to maintain the contai ned borated water level within the limits of SR 3.5.1.2.SR 3.5.1.5 Verify power is removed from each SIT In accordance isolation valve operator. | ||
with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.5.1-3 AMENDMENT NO. | with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.5.1-3 AMENDMENT NO. | ||
SITs-Shutdown | SITs-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify each required SIT isolation valve is In accordance fully open when pressurizer pressure is with the> 430 psia. Surveillance Frequency Control Program SR 3.5.2.2 Verify borated water volume in each In accordance required SIT is: with the a. For four OPERABLE SITs, > 39% wide Surveillance range indication and < 83% wide range Frequency indication. | ||
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify each required SIT isolation valve is In accordance fully open when pressurizer pressure is with the> 430 psia. Surveillance Frequency Control Program SR 3.5.2.2 Verify borated water volume in each In accordance required SIT is: with the a. For four OPERABLE SITs, > 39% wide Surveillance range indication and < 83% wide range Frequency indication. | |||
Control Program OR b. For three OPERABLE SITs, > 60% wide range indication and < 83% wide range indication. | Control Program OR b. For three OPERABLE SITs, > 60% wide range indication and < 83% wide range indication. | ||
SR 3.5.2.3 Verify nitrogen cover pressure in each In accordance required SIT is 260 psig and 625 psig. with the Surveillance Frequency Control Program (continued) | SR 3.5.2.3 Verify nitrogen cover pressure in each In accordance required SIT is 260 psig and 625 psig. with the Surveillance Frequency Control Program (continued) | ||
PALO VERDE UNITS 1,2,3 3.5.2-2 AMENDMENT NO. | PALO VERDE UNITS 1,2,3 3.5.2-2 AMENDMENT NO. | ||
SITs-Shutdown | SITs-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued) | ||
REQUIREMENTS (continued) | |||
SURVEILLANCE FREQUENCY SR 3.5.2.4 Verify boron concentration in each required SIT is 2300 ppm and 4400 ppm.In accordance with the Survei 1 lance Frequency Control Program AND----- NOTE ------Only required to be performed for affected SIT Once within 6 hours, whenever a required SIT is drained to maintain the contai ned borated water level within the limits of SR 3.5.2.2.SR 3.5.2.5 Verify power is removed from each required In accordance SIT isolation valve operator when with the pressurizer pressure is 1500 psia. Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.5.2-3 AMENDMENT NO. | SURVEILLANCE FREQUENCY SR 3.5.2.4 Verify boron concentration in each required SIT is 2300 ppm and 4400 ppm.In accordance with the Survei 1 lance Frequency Control Program AND----- NOTE ------Only required to be performed for affected SIT Once within 6 hours, whenever a required SIT is drained to maintain the contai ned borated water level within the limits of SR 3.5.2.2.SR 3.5.2.5 Verify power is removed from each required In accordance SIT isolation valve operator when with the pressurizer pressure is 1500 psia. Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.5.2-3 AMENDMENT NO. | ||
ECCS -Operating 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify each ECCS manual, power operated, In accordance and automatic valve in the flow path, that with the is not locked, sealed, or otherwise secured Surveillance in position, is in the correct position. | ECCS -Operating 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify each ECCS manual, power operated, In accordance and automatic valve in the flow path, that with the is not locked, sealed, or otherwise secured Surveillance in position, is in the correct position. | ||
| Line 1,022: | Line 913: | ||
PALO VERDE UNITS 1,2,3 3.8.4-3 AMENDMENT NO. 4-56, DC Sources -Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued) | PALO VERDE UNITS 1,2,3 3.8.4-3 AMENDMENT NO. 4-56, DC Sources -Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued) | ||
SURVEILLANCE I FREQUENCY SR 3.8.4.8 ----------------- | SURVEILLANCE I FREQUENCY SR 3.8.4.8 ----------------- | ||
NOTE-This Surveillance shall not be performed in MODE 1, 2, 3, or 4.Verify battery capacity is 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test.In accordance with the Surveillance Frequency Control Program AND 12 months when battery shows degradation or has reached 85%of the expected life with capacity< 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected life with capacity 100% of manufacturer's rating PALO VERDE UNITS 1,2,3 3.8.4-4 AMENDMENT NO. 4-59, Battery Cell Parameters | NOTE-This Surveillance shall not be performed in MODE 1, 2, 3, or 4.Verify battery capacity is 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test.In accordance with the Surveillance Frequency Control Program AND 12 months when battery shows degradation or has reached 85%of the expected life with capacity< 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected life with capacity 100% of manufacturer's rating PALO VERDE UNITS 1,2,3 3.8.4-4 AMENDMENT NO. 4-59, Battery Cell Parameters 3.8.6 ACTIONS (continued) | ||
(continued) | |||
CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Declare associated Immediately associated Completion battery inoperable. | CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Declare associated Immediately associated Completion battery inoperable. | ||
Time of Condition A not met.OR One or more batteries with average electrolyte temperature of the representative cells< 60 0 F.OR One or more batteries with one or more battery cell parameters not within Category C limits.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet In accordance Table 3.8.6-1 Category A limits, with the Surveillance Frequency Control Program (continued) | Time of Condition A not met.OR One or more batteries with average electrolyte temperature of the representative cells< 60 0 F.OR One or more batteries with one or more battery cell parameters not within Category C limits.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet In accordance Table 3.8.6-1 Category A limits, with the Surveillance Frequency Control Program (continued) | ||
PALO VERDE UNITS 1,2,3 3.8.6-2 AMENDMENT NO. ý44, Battery Cell Parameters | PALO VERDE UNITS 1,2,3 3.8.6-2 AMENDMENT NO. ý44, Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued) | ||
REQUIREMENTS (continued) | |||
SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify battery cell parameters meet In accordance with Table 3.8.6-1 Category B limits, the Surveillance Frequency Control Program AND Once within 7 days after battery discharge< 105 V AND Once within 7 days after battery overcharge | SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify battery cell parameters meet In accordance with Table 3.8.6-1 Category B limits, the Surveillance Frequency Control Program AND Once within 7 days after battery discharge< 105 V AND Once within 7 days after battery overcharge | ||
> 150 V SR 3.8.6.3 Verify average electrolyte temperature of In accordance representative cells is 60'F. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.8.6-3 AMENDMENT NO. 4-1-;, | > 150 V SR 3.8.6.3 Verify average electrolyte temperature of In accordance representative cells is 60'F. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.8.6-3 AMENDMENT NO. 4-1-;, | ||
| Line 1,047: | Line 931: | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and In accordance voltage to required AC, DC, and AC vital with the instrument bus electrical power Surveillance distribution subsystems. | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and In accordance voltage to required AC, DC, and AC vital with the instrument bus electrical power Surveillance distribution subsystems. | ||
Frequency Control Program PALO VERDE UNITS 1,2,3 3.8.10-2 AMENDMENT NO. 44--ý. | Frequency Control Program PALO VERDE UNITS 1,2,3 3.8.10-2 AMENDMENT NO. 44--ý. | ||
Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS | Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 APPLICABILITY: | ||
Concentration LCO 3.9.1 APPLICABILITY: | |||
Boron concentrations of the Reactor Coolant System and the refueling canal shall be maintained within the limit specified in the COLR.MODE 6.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration A.1 Suspend CORE Immediately not within limit. ALTERATIONS. | Boron concentrations of the Reactor Coolant System and the refueling canal shall be maintained within the limit specified in the COLR.MODE 6.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration A.1 Suspend CORE Immediately not within limit. ALTERATIONS. | ||
AND A.2 Suspend positive Immediately reactivity additions. | AND A.2 Suspend positive Immediately reactivity additions. | ||
AND A.3 Initiate action to Immediately restore boron concentration to within limit.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the In accordance limit specified in the COLR. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.1-1 AMENDMENT NO. ;4--ý, | AND A.3 Initiate action to Immediately restore boron concentration to within limit.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the In accordance limit specified in the COLR. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.1-1 AMENDMENT NO. ;4--ý, | ||
Nuclear Instrumentation | Nuclear Instrumentation 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.9.2.2 ----------------- | ||
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.9.2.2 ----------------- | |||
NOTE---------------- | NOTE---------------- | ||
Neutron detectors are excluded from CHANNEL CALIBRATION. | Neutron detectors are excluded from CHANNEL CALIBRATION. | ||
Perform CHANNEL CALIBRATION. | Perform CHANNEL CALIBRATION. | ||
In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2,3 3.9.2-2 AMENDMENT NO. ;4-ý, | In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2,3 3.9.2-2 AMENDMENT NO. ;4-ý, | ||
Containment Penetrations | Containment Penetrations 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify each required containment In accordance penetration is in the required status. with the Surveillance Frequency Control Program SR 3.9.3.2 Verify each required containment purge and In accordance exhaust valve actuates to the isolation with the position on an actual or simulated Surveillance actuation signal. Frequency Control Program SR 3.9.3.3 Verify the capability to close the In accordance equipment hatch, if open with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.3-2 AMENDMENT NO. 44ý, | ||
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify each required containment In accordance penetration is in the required status. with the Surveillance Frequency Control Program SR 3.9.3.2 Verify each required containment purge and In accordance exhaust valve actuates to the isolation with the position on an actual or simulated Surveillance actuation signal. Frequency Control Program SR 3.9.3.3 Verify the capability to close the In accordance equipment hatch, if open with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.3-2 AMENDMENT NO. 44ý, | |||
SDC and Coolant Circulation -High Water Level 3.9.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) | SDC and Coolant Circulation -High Water Level 3.9.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) | ||
A.4 Close all containment 4 hours penetrations providing direct access from containment atmosphere to outside atmosphere. | A.4 Close all containment 4 hours penetrations providing direct access from containment atmosphere to outside atmosphere. | ||
| Line 1,081: | Line 954: | ||
with the Surveillance Frequency Control Program SR 3.9.5.2 Verify correct breaker alignment and In accordance indicated power available to the required with the SDC pump that is not in operation. | with the Surveillance Frequency Control Program SR 3.9.5.2 Verify correct breaker alignment and In accordance indicated power available to the required with the SDC pump that is not in operation. | ||
Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.5-2 AMENDMENT NO. | Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.5-2 AMENDMENT NO. | ||
Refueling Water Level-Fuel Assemblies 3.9.6 3.9 REFUELING OPERATIONS | Refueling Water Level-Fuel Assemblies 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Refueling Water Level-Fuel Assemblies LCO 3.9.6 APPLICABILITY: | ||
Water Level-Fuel Assemblies LCO 3.9.6 APPLICABILITY: | |||
Refueling water level shall be maintained 23 ft above the top of the reactor vessel flange.During movement of fuel assemblies within containment when either the fuel assemblies being moved or the fuel assemblies seated within the reactor vessel are irradiated. | Refueling water level shall be maintained 23 ft above the top of the reactor vessel flange.During movement of fuel assemblies within containment when either the fuel assemblies being moved or the fuel assemblies seated within the reactor vessel are irradiated. | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling water level A.1 Suspend movement of Immediately not within limit, fuel assemblies within containment. | ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling water level A.1 Suspend movement of Immediately not within limit, fuel assemblies within containment. | ||
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify refueling water level is 23 ft In accordance above the top of reactor vessel flange. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.6-1 AMENDMENT NO. 44;, | SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify refueling water level is 23 ft In accordance above the top of reactor vessel flange. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.6-1 AMENDMENT NO. 44;, | ||
Refueling Water Level-CEAs 3.9.7 3.9 REFUELING OPERATIONS | Refueling Water Level-CEAs 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Refueling Water Level-CEAs LCO 3.9.7 APPLICABILITY: | ||
Water Level-CEAs LCO 3.9.7 APPLICABILITY: | |||
Refueling water level shall be maintained 23 ft above the top of irradiated fuel assemblies seated within the reactor vessel.During movement of CEAs within the reactor vessel, when the fuel assemblies seated within the reactor vessel are irradiated. | Refueling water level shall be maintained 23 ft above the top of irradiated fuel assemblies seated within the reactor vessel.During movement of CEAs within the reactor vessel, when the fuel assemblies seated within the reactor vessel are irradiated. | ||
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling water level A.1 Suspend movement of Immediately not within limit. CEAs within the reactor vessel.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling water level is 23 ft In accordance above the top of irradiated fuel assemblies with the seated within the reactor vessel. Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.7-1 AMENDMENT NO. | ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling water level A.1 Suspend movement of Immediately not within limit. CEAs within the reactor vessel.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling water level is 23 ft In accordance above the top of irradiated fuel assemblies with the seated within the reactor vessel. Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.7-1 AMENDMENT NO. | ||
| Line 1,099: | Line 964: | ||
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 whole body or its equivalent to any part of the body for the duration of the accident. | 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 whole body or its equivalent to any part of the body 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. | 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 in accordance with the testing methods and the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Determining Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.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 of one train of the CREFS, operating at the flow rate required by the VFTP, at a Frequency of 18 months on a-STAGGERED TEST BASIS. The results shall be trended and used as part of the periodic assessment of the CRE boundary.e. The quantitative limits on unfiltered air inleakage into the CRE shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph | : c. Requirements for (i) determining the unfiltered air inleakage past the CRE boundary in accordance with the testing methods and the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Determining Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.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 of one train of the CREFS, operating at the flow rate required by the VFTP, at a Frequency of 18 months on a-STAGGERED TEST BASIS. The results shall be trended and used as part of the periodic assessment of the CRE boundary.e. The quantitative limits on unfiltered air inleakage into the CRE shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph | ||
: c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences. | : c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences. | ||
: 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.(continued) | : 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.(continued) | ||
| Line 1,108: | Line 973: | ||
SURVEILLANCE The Fr.qucn.y of 21 hours is based on the g.n..ally slo-REQUIREMENTS change in requir. d boron c.nccntration, and also allows (continued) sufficicnt time for the operator to co.l. et the requ data, Which includcs perfoming a boron concentratio analysis, and complete the calculation. | SURVEILLANCE The Fr.qucn.y of 21 hours is based on the g.n..ally slo-REQUIREMENTS change in requir. d boron c.nccntration, and also allows (continued) sufficicnt time for the operator to co.l. et the requ data, Which includcs perfoming a boron concentratio analysis, and complete the calculation. | ||
When taking credit Insert 1 for on concentrton.. | When taking credit Insert 1 for on concentrton.. | ||
.in the reactivity balance calclatonthe frequency may have to be administrat?*i;el controlled to ensure th-at SDM does not go below theli t due to Xenon decay REFERENCES | .in the reactivity balance calclatonthe frequency may have to be administrat?*i;el controlled to ensure th-at SDM does not go below theli t due to Xenon decay REFERENCES | ||
: 1. 10 CFR 50. Appendix A, GDC 26.2. UPSAR. Section 15.1.3. UFSAR, Section 15.4.4. 10 CFR 100.PALO VERDE UNITS 1,2,3 B 3.1.1-6 REVISION 31 SDM -Reactor Trip Breakers Closed B 3.1.2 BASES SURVEILLANCE REQUIREMENTS SR 3.1.2.1, 3.1.2.2 and 3.1.2.3 (continued) | : 1. 10 CFR 50. Appendix A, GDC 26.2. UPSAR. Section 15.1.3. UFSAR, Section 15.4.4. 10 CFR 100.PALO VERDE UNITS 1,2,3 B 3.1.1-6 REVISION 31 SDM -Reactor Trip Breakers Closed B 3.1.2 BASES SURVEILLANCE REQUIREMENTS SR 3.1.2.1, 3.1.2.2 and 3.1.2.3 (continued) | ||
The --,Fru of hr-enc of 21" "ho ibaed-A the gc-erraly slew change in required boPrn concentration, And it A1l9WS suifficient time for the operator. | The --,Fru of hr-enc of 21" "ho ibaed-A the gc-erraly slew change in required boPrn concentration, And it A1l9WS suifficient time for the operator. | ||
to co-llect thereqird data,.... | to co-llect thereqird data,.... | ||
-.h incd per-for.ming a boron .onentr.ation Inset ~ anaysis an co Plt the calculation. | -.h incd per-for.ming a boron .onentr.ation Inset ~ anaysis an co Plt the calculation. | ||
When taking cr-edit forp xenon conccntration in the r-eactivity bal-ance cailculation, the frequency may have to hc administratively contrlld to cnsurc that SONI does notgobl:thlit du---c to X-eno decay.-REFERENCES | When taking cr-edit forp xenon conccntration in the r-eactivity bal-ance cailculation, the frequency may have to hc administratively contrlld to cnsurc that SONI does notgobl:thlit du---c to X-eno decay.-REFERENCES | ||
: 1. 10 CFR 50, Appendix A, GDC 26.2. UFSAR, Section 15.1.3. UFSAR, Section 15.4.4. 10 CFR 100 PAL-9 VERDE UNITS 1,2,3 B 3.1.2-9 REVISION 4 Reactivity Balance B 3.1.3 BASES SURVEILLANCE REQUIREMENTS SR 3.1.3.1 (continued) is performed prior to entering MODE 1 as an initial check on core conditions and design calculations at BOC. The SR is modified by three Notes. The first Note indicates that the normalization of predicted core reactivity to the measured value may take place within the first 60 effective full power days (EFPD) after each fuel loading. This allows sufficient time for core conditions to reach steady state, but prevents operation for a large fraction of the fuel cycle without establishing a benchmark for the design calculati The required subsequcnt Frcuenecy ef 31 EFPD, iii.. 50 -._ EFPD I- ftePr- enter-ing MODE !, is insert 1 aceptablc. | : 1. 10 CFR 50, Appendix A, GDC 26.2. UFSAR, Section 15.1.3. UFSAR, Section 15.4.4. 10 CFR 100 PAL-9 VERDE UNITS 1,2,3 B 3.1.2-9 REVISION 4 Reactivity Balance B 3.1.3 BASES SURVEILLANCE REQUIREMENTS SR 3.1.3.1 (continued) is performed prior to entering MODE 1 as an initial check on core conditions and design calculations at BOC. The SR is modified by three Notes. The first Note indicates that the normalization of predicted core reactivity to the measured value may take place within the first 60 effective full power days (EFPD) after each fuel loading. This allows sufficient time for core conditions to reach steady state, but prevents operation for a large fraction of the fuel cycle without establishing a benchmark for the design calculati The required subsequcnt Frcuenecy ef 31 EFPD, iii.. 50 -._ EFPD I- ftePr- enter-ing MODE !, is insert 1 aceptablc. | ||
bhascd on the slew: Pate of corc Ghangcs duct fiir'1A drn Rtin~d thr' ppqnrrpcr nF nth indieater" (C'ra uthl Tilt) for pronmpt indiction of-an anomaly.Note, "only required after 60 EFPD," is added to the Frequency column to allow this.A REFERENCES | bhascd on the slew: Pate of corc Ghangcs duct fiir'1A drn Rtin~d thr' ppqnrrpcr nF nth indieater" (C'ra uthl Tilt) for pronmpt indiction of-an anomaly.Note, "only required after 60 EFPD," is added to the Frequency column to allow this.A REFERENCES | ||
: 1. 10 CFR 50, Appendix A, GDC 26, GDC 28, and GDC 29.2. UFSAR, Section 15.PALO VERDE UNITS 1,2,3 B 3.1.3-6 REVISION 4 CEA Alignment B 3.1.5 BASES ACTIONS D.1 (continued) could result in a situation outside the design basis and immediate action would be required to prevent any potential fuel damage. Immediately opening the reactor trip breakers minimizes these effects.SURVEILLANCE REQUIREMENTS SR 3.1.5.1 Verification that individual CEA positions are within 6.6 inches (indicated reed switch positions) of all other CEAs in the group -at -a 1-2 hour-allows the operator to detect a CEA that is beginning to deviate from its expected positi The specified F.que..Y takes into during actual CEA mtAion, dep:at, n than igmm pediatly, be SR 3.1.5.2 OPERABILITY of at least two CEA position indicator channels is required to determine CEA positions, and thereby ensure compliance with the CEA alignment and insertion limits. The CEA full in and full out limits provide an additional independent means for determining the CEA positions when the CEAs are at either their fully inserted or fully withdrawn position Insertilj" -"SR 3.1.5.3 Verifying each full strength CEA is trippable would require that each CEA be tripped. In MODES 1 and 2 tripping each full strength CEA would result in radial or axial power tilts, or oscillations. | : 1. 10 CFR 50, Appendix A, GDC 26, GDC 28, and GDC 29.2. UFSAR, Section 15.PALO VERDE UNITS 1,2,3 B 3.1.3-6 REVISION 4 CEA Alignment B 3.1.5 BASES ACTIONS D.1 (continued) could result in a situation outside the design basis and immediate action would be required to prevent any potential fuel damage. Immediately opening the reactor trip breakers minimizes these effects.SURVEILLANCE REQUIREMENTS SR 3.1.5.1 Verification that individual CEA positions are within 6.6 inches (indicated reed switch positions) of all other CEAs in the group -at -a 1-2 hour-allows the operator to detect a CEA that is beginning to deviate from its expected positi The specified F.que..Y takes into during actual CEA mtAion, dep:at, n than igmm pediatly, be SR 3.1.5.2 OPERABILITY of at least two CEA position indicator channels is required to determine CEA positions, and thereby ensure compliance with the CEA alignment and insertion limits. The CEA full in and full out limits provide an additional independent means for determining the CEA positions when the CEAs are at either their fully inserted or fully withdrawn position Insertilj" -"SR 3.1.5.3 Verifying each full strength CEA is trippable would require that each CEA be tripped. In MODES 1 and 2 tripping each full strength CEA would result in radial or axial power tilts, or oscillations. | ||
Therefore individual full strength CEAs are exercised ee-y- 9-2-dys to provide increased confidence that all full strength CEAs continue to be trippable, even if they are not regularly tripped. A movement of 5 inches is adequate to demonstrate motion without exceeding the alignment limit when only one full strength CEA is in Th 92 day Fr.qUe..Y operato in thecontrol room and oterva''ilalenc bi tein pterformC mor frqently......ad to the d.t.rmination. | Therefore individual full strength CEAs are exercised ee-y- 9-2-dys to provide increased confidence that all full strength CEAs continue to be trippable, even if they are not regularly tripped. A movement of 5 inches is adequate to demonstrate motion without exceeding the alignment limit when only one full strength CEA is in Th 92 day Fr.qUe..Y operato in thecontrol room and oterva''ilalenc bi tein pterformC mor frqently......ad to the d.t.rmination. | ||
| Line 1,135: | Line 1,000: | ||
PALO VERDE UNITS 1,2,3 B 3.1.7-8 REVISION &I Regulating CEA Insertion Limits B 3.1.7 BASES SURVEILLANCE REQUIREMENTS SR 3.1.7.2 Verification of the accumulated time of CEA group insertion between the long term steady state insertion limits and the transient insertion limits ensures the cumulative time limits are not exce The 21 hu ... c. .....the SR 3.1.7.3 Demonstrating the PDIL alarm circuit OPERABLE verifies that the PDIL alarm circuit is func | PALO VERDE UNITS 1,2,3 B 3.1.7-8 REVISION &I Regulating CEA Insertion Limits B 3.1.7 BASES SURVEILLANCE REQUIREMENTS SR 3.1.7.2 Verification of the accumulated time of CEA group insertion between the long term steady state insertion limits and the transient insertion limits ensures the cumulative time limits are not exce The 21 hu ... c. .....the SR 3.1.7.3 Demonstrating the PDIL alarm circuit OPERABLE verifies that the PDIL alarm circuit is func | ||
* The 31 day Frequen. YiJAI'' a-Q,,, --. ." n, ill an bei,.ng p'erf"opmed | * The 31 day Frequen. YiJAI'' a-Q,,, --. ." n, ill an bei,.ng p'erf"opmed | ||
.REFERENCES | .REFERENCES | ||
: 1. 10 CFR 50, Appendix A, GDC 10 and GDC 26.2. 10 CFR 50.46.3. Regulatory Guide 1.77, Rev. 0, May 1974.4. UFSAR, Section 15.4.PALO VERDE UNITS 1,2,3 B 3.1.7-9 REVISION Part Strength CEA Insertion Limits B 3.1.8 BASES (continued) | : 1. 10 CFR 50, Appendix A, GDC 10 and GDC 26.2. 10 CFR 50.46.3. Regulatory Guide 1.77, Rev. 0, May 1974.4. UFSAR, Section 15.4.PALO VERDE UNITS 1,2,3 B 3.1.7-9 REVISION Part Strength CEA Insertion Limits B 3.1.8 BASES (continued) | ||
SURVEILLANCE REQUIREMENTS SR 3.1.8.1 Verification of each part strength CEA group position evepy-12 hou-rs is sufficient to detect CEA positions that may approach the limits, and provide the operator with time to undertake the Required Action(s), should insertion limits be found to be exceed The 32 hour frequency al. o takco into ilnserrtion limit aarm circuit and other information abou-t LCEA group pitinz . | SURVEILLANCE REQUIREMENTS SR 3.1.8.1 Verification of each part strength CEA group position evepy-12 hou-rs is sufficient to detect CEA positions that may approach the limits, and provide the operator with time to undertake the Required Action(s), should insertion limits be found to be exceed The 32 hour frequency al. o takco into ilnserrtion limit aarm circuit and other information abou-t LCEA group pitinz . | ||
to the in the control REFERENCES | to the in the control REFERENCES | ||
: 1. 10 CFR 50. Appendix A, GDC 10 and GDC 26.2. 10 CFR 50.46.3. Regulatory Guide 1.77, Rev. 0, May 1974.4. UFSAR, Section 15.4.PALO VERDE UNITS 1,2,3 B 3.1.8-5 REVISION & | : 1. 10 CFR 50. Appendix A, GDC 10 and GDC 26.2. 10 CFR 50.46.3. Regulatory Guide 1.77, Rev. 0, May 1974.4. UFSAR, Section 15.4.PALO VERDE UNITS 1,2,3 B 3.1.8-5 REVISION & | ||
STE-SDM B 3.1.9 BASES (continued) | STE-SDM B 3.1.9 BASES (continued) | ||
| Line 1,153: | Line 1,018: | ||
: e. Xenon concentration; and f. Samarium concentration. | : e. Xenon concentration; and f. Samarium concentration. | ||
The Frequency 9f 2 hoursP- 4A ba-sed- on the generally slew change in rcquired b9oro concentration. | The Frequency 9f 2 hoursP- 4A ba-sed- on the generally slew change in rcquired b9oro concentration. | ||
and- it a]]oe:s time for- the opcrato-r-to collect the rcquired Insert 1 REFERENCES | and- it a]]oe:s time for- the opcrato-r-to collect the rcquired Insert 1 REFERENCES | ||
: 1. 10 CFR 50, Appendix B, Section XI.2. 10 CFR 50.59.3. Regulatory Guide 1.68, Revision 2, August 1978.4. ANSI/ANS-19.6.1-1985, December 13, 1985.5. UFSAR, Chapter 14.6. 10 CFR 50.46.7. UFSAR, Chapter 15.PALO VERDE UNITS 1,2,3 B 3.1.9-6 REVISION - | : 1. 10 CFR 50, Appendix B, Section XI.2. 10 CFR 50.59.3. Regulatory Guide 1.68, Revision 2, August 1978.4. ANSI/ANS-19.6.1-1985, December 13, 1985.5. UFSAR, Chapter 14.6. 10 CFR 50.46.7. UFSAR, Chapter 15.PALO VERDE UNITS 1,2,3 B 3.1.9-6 REVISION - | ||
STE-MODES 1 and 2 B 3.1.10 BASES (continued) | STE-MODES 1 and 2 B 3.1.10 BASES (continued) | ||
| Line 1,167: | Line 1,032: | ||
testing frcqUency of r-eactor-protection And- monit-oring sySte-ms. | testing frcqUency of r-eactor-protection And- monit-oring sySte-ms. | ||
The uvilac Frequency for testing systems .. exten.ded to 92 days by CEN 327. Mo-nitoing system r:ere-not ,ddrese Insert 1 .-1--IdR>REFERENCES | The uvilac Frequency for testing systems .. exten.ded to 92 days by CEN 327. Mo-nitoing system r:ere-not ,ddrese Insert 1 .-1--IdR>REFERENCES | ||
: 1. UFSAR, Section 15.2. UFSAR, Section 6.3. CE-1 Correlation for DNBR.4. 10 CFR 50, Appendix A, GDC 10.5. 10 CFR 50.46.6. Regulatory Guide 1.77, Rev. 0, May 1974.7. 10 CFR 50, Appendix A, GDC 26.PALO VERDE UNITS 1,2,3 B 3.2.1-8 REVISION 0 F B 3.2.BASES SURVEILLANCE SR 3.2.2.1 REQUIREMENTS This periodic Surveillance is for determining, using the Incore Detector System, that FxY values are Fxy values used in the COLSS and CPCs. It ensures that the Fxy values used the Fy values after each fuel loading when THERMAL POWER is> 40% RTP, but prior to its exceeding 70% RTP, ensures that the core is properly loaded.REFERENCES | : 1. UFSAR, Section 15.2. UFSAR, Section 6.3. CE-1 Correlation for DNBR.4. 10 CFR 50, Appendix A, GDC 10.5. 10 CFR 50.46.6. Regulatory Guide 1.77, Rev. 0, May 1974.7. 10 CFR 50, Appendix A, GDC 26.PALO VERDE UNITS 1,2,3 B 3.2.1-8 REVISION 0 F B 3.2.BASES SURVEILLANCE SR 3.2.2.1 REQUIREMENTS This periodic Surveillance is for determining, using the Incore Detector System, that FxY values are Fxy values used in the COLSS and CPCs. It ensures that the Fxy values used the Fy values after each fuel loading when THERMAL POWER is> 40% RTP, but prior to its exceeding 70% RTP, ensures that the core is properly loaded.REFERENCES | ||
: 1. UFSAR, Section 15.2. UFSAR, Section 6.3. CE-1 Correlation for DNBR.4. 10 CFR 50, Appendix A, GDC 10.5. 10 CFR 50.46.6. Regulatory Guide 1.77, Rev. 0, May 1974.7. 10 CFR 50, Appendix A, GDC 26.PALO VERDE UNITS 1,2,3 B 3.2.2-7 REVISION 0 Tq B 3.2.BASES ACTIONS B.1, B.2, B.3, B.4, and B.5 (continued) | : 1. UFSAR, Section 15.2. UFSAR, Section 6.3. CE-1 Correlation for DNBR.4. 10 CFR 50, Appendix A, GDC 10.5. 10 CFR 50.46.6. Regulatory Guide 1.77, Rev. 0, May 1974.7. 10 CFR 50, Appendix A, GDC 26.PALO VERDE UNITS 1,2,3 B 3.2.2-7 REVISION 0 Tq B 3.2.BASES ACTIONS B.1, B.2, B.3, B.4, and B.5 (continued) | ||
If Tq is restored prior to identifying and correcting the cause, the plant corrective action program will continue to evaluate the cause of the out of limit condition. | If Tq is restored prior to identifying and correcting the cause, the plant corrective action program will continue to evaluate the cause of the out of limit condition. | ||
| Line 1,306: | Line 1,171: | ||
PALO VERDE UNITS 1,2,3 B 3.3.3-11 REVISION 63 CEACs B 3.3.3 BASES SURVEILLANCE REQUIREMENTS SR 3.3.3.5 (continued) | PALO VERDE UNITS 1,2,3 B 3.3.3-11 REVISION 63 CEACs B 3.3.3 BASES SURVEILLANCE REQUIREMENTS SR 3.3.3.5 (continued) | ||
Thc b--asis, for the 18 month Frequenc 4.. that thc CEACZ perform acntinuou; relf- monitoring function that eliinaes hc eedfor fr-equent CHANNEL FUNCTIONAL TESTS.This CHANEL FUNCTIONAL TEST essentially validates the self functio a. crheks for a s.mal. se of failure mod-es that arPe undetectable b)y the sel~f monRitoring fu~nction. | Thc b--asis, for the 18 month Frequenc 4.. that thc CEACZ perform acntinuou; relf- monitoring function that eliinaes hc eedfor fr-equent CHANNEL FUNCTIONAL TESTS.This CHANEL FUNCTIONAL TEST essentially validates the self functio a. crheks for a s.mal. se of failure mod-es that arPe undetectable b)y the sel~f monRitoring fu~nction. | ||
n xper has shown that. undteted CPC or CEAC REFERENCES | n xper has shown that. undteted CPC or CEAC REFERENCES | ||
: 1. 10 CFR 50.2. 10 CFR 100.3. UFSAR, Section 7.2.4. NRC Safety Evaluation Report, July 15, 1994 5. CEN-327, June 2, 1986, including Supplement 1, March 3, 1989, and Calculation 13-JC-SB-200. | : 1. 10 CFR 50.2. 10 CFR 100.3. UFSAR, Section 7.2.4. NRC Safety Evaluation Report, July 15, 1994 5. CEN-327, June 2, 1986, including Supplement 1, March 3, 1989, and Calculation 13-JC-SB-200. | ||
PALO VERDE UNITS 1,2,3 B 3.3.3-12 REVISION 63 RPS Logic and Trip Initiation B 3.3.4 BASES ACTIONS E.1 and E.2 (continued) | PALO VERDE UNITS 1,2,3 B 3.3.3-12 REVISION 63 RPS Logic and Trip Initiation B 3.3.4 BASES ACTIONS E.1 and E.2 (continued) | ||
If the RTCB associated with the inoperable channel, or the redundant RTCB in the affected Trip Leg cannot be opened, the reactor must be shut down within 6 hours and all the RTCBs opened. A Completion Time of 6 hours is reasonable, based on operating experience, for reaching the required plant conditions from full power conditions in an orderly manner and without challenging plant systems and for opening RTCBs. All RTCBs should then be opened, placing the plant in a MODE where the LCO does not apply and ensuring no CEA withdrawal occurs.SURVEILLANCE SR 3.3.4.1 REQUIREMENTS A CHANNEL FUNCTIONAL TEST on each RPS Logic channel and Manual Trip channel is performed every-92-4ay6 to ensure the entire channel will perform its intended function when needed.The RPS CHANNEL FUNCTIONAL TEST consists of three overlapping tests as described in Reference | If the RTCB associated with the inoperable channel, or the redundant RTCB in the affected Trip Leg cannot be opened, the reactor must be shut down within 6 hours and all the RTCBs opened. A Completion Time of 6 hours is reasonable, based on operating experience, for reaching the required plant conditions from full power conditions in an orderly manner and without challenging plant systems and for opening RTCBs. All RTCBs should then be opened, placing the plant in a MODE where the LCO does not apply and ensuring no CEA withdrawal occurs.SURVEILLANCE SR 3.3.4.1 REQUIREMENTS A CHANNEL FUNCTIONAL TEST on each RPS Logic channel and Manual Trip channel is performed every-92-4ay6 to ensure the entire channel will perform its intended function when needed.The RPS CHANNEL FUNCTIONAL TEST consists of three overlapping tests as described in Reference | ||
: 3. These tests verify that the RPS is capable of performing its intended function, from bistable input through the RTCBs. The first test, the bistable test, is addressed by SR 3.3.1.7 in LCO 3.3.1.This SR addresses the two tests associated with the RPS Logic: Matrix Logic and Trip Path.Matrix Logic Tests These tests are performed one matrix at a time. They verify that a coincidence in the two input channels for each Function removes power from the matrix relays. During testing, power is applied to the matrix relay test coils and prevents the matrix relay contacts from assuming their de-energized state. The Matrix Logic tests will detect any short circuits around the bistable contacts in the coincidence logic such as may be caused by faulty bistable relay or trip channel bypass contacts.(continued) | : 3. These tests verify that the RPS is capable of performing its intended function, from bistable input through the RTCBs. The first test, the bistable test, is addressed by SR 3.3.1.7 in LCO 3.3.1.This SR addresses the two tests associated with the RPS Logic: Matrix Logic and Trip Path.Matrix Logic Tests These tests are performed one matrix at a time. They verify that a coincidence in the two input channels for each Function removes power from the matrix relays. During testing, power is applied to the matrix relay test coils and prevents the matrix relay contacts from assuming their de-energized state. The Matrix Logic tests will detect any short circuits around the bistable contacts in the coincidence logic such as may be caused by faulty bistable relay or trip channel bypass contacts.(continued) | ||
PALO VERDE UNITS 1,2,3 B 3.3.4-13 REVISION .9 RPS Logic and Trip Initiation B 3.3.4 BASES SURVEILLANCE Trip Path Tests REQUIREMENTS (continued) | PALO VERDE UNITS 1,2,3 B 3.3.4-13 REVISION .9 RPS Logic and Trip Initiation B 3.3.4 BASES SURVEILLANCE Trip Path Tests REQUIREMENTS (continued) | ||
| Line 1,317: | Line 1,182: | ||
Conversely, during shunt trip coil testing, the undervoltage coils must remain energized, preventing their operation.(continued) | Conversely, during shunt trip coil testing, the undervoltage coils must remain energized, preventing their operation.(continued) | ||
PALO VERDE UNITS 1,2,3 B 3.3.4-14 REVISION 4 RPS Logic and Trip Initiation B 3.3.4 BASES SURVEILLANCE REQUIREMENTS SR 3.3.4.2 (continued) | PALO VERDE UNITS 1,2,3 B 3.3.4-14 REVISION 4 RPS Logic and Trip Initiation B 3.3.4 BASES SURVEILLANCE REQUIREMENTS SR 3.3.4.2 (continued) | ||
This Surveillance ensures that every undervoltage coil and every shunt trip coil is capable of performing its intended function and that no single active failure of any RTCB component will prevent a r " e 1 " on operating experience that 1ha shown these ope s ...ally pass the Surpo.ilLancc when pcr'formcd at the Frcgucency of once evcry 18 moneths.SR 3.3.4.3 toverifv A CHANNEL FUNCTIONAL TEST on each RTCB is performed evepyay .... Thi-s verife proper operation of each RTCB. The RTCB must then be closed prior to testing the other three initiation circuits, or a Reactor T "T.he.-[Insert 1 F ....e. I Reep .... -32,,_ "Rpý 4PU^S Exten'ded T~÷ valuation" (Ref.- &).REFERENCES | This Surveillance ensures that every undervoltage coil and every shunt trip coil is capable of performing its intended function and that no single active failure of any RTCB component will prevent a r " e 1 " on operating experience that 1ha shown these ope s ...ally pass the Surpo.ilLancc when pcr'formcd at the Frcgucency of once evcry 18 moneths.SR 3.3.4.3 toverifv A CHANNEL FUNCTIONAL TEST on each RTCB is performed evepyay .... Thi-s verife proper operation of each RTCB. The RTCB must then be closed prior to testing the other three initiation circuits, or a Reactor T "T.he.-[Insert 1 F ....e. I Reep .... -32,,_ "Rpý 4PU^S Exten'ded T~÷ valuation" (Ref.- &).REFERENCES | ||
: 1. 10 CFR 50, Appendix A.2. 10 CFR 100.3. UFSAR, Section 7.2.4. NRC Safety Evaluation Report, July 15, 1994.5. CEN-327, June 2, 1986, including Supplement 1, March 3, 1989, and Calculation 13-JC-SB-200. | : 1. 10 CFR 50, Appendix A.2. 10 CFR 100.3. UFSAR, Section 7.2.4. NRC Safety Evaluation Report, July 15, 1994.5. CEN-327, June 2, 1986, including Supplement 1, March 3, 1989, and Calculation 13-JC-SB-200. | ||
PALO VERDE UNITS 1,2,3 B 3.3.4-15 REVISION 4 ESFAS Instrumentation B 3.3.5 BASES ACTIONS (continued) | PALO VERDE UNITS 1,2,3 B 3.3.4-15 REVISION 4 ESFAS Instrumentation B 3.3.5 BASES ACTIONS (continued) | ||
| Line 1,375: | Line 1,240: | ||
CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis. | CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis. | ||
Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency. | Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency. | ||
The setpoints, as well as the response to a Loss of Voltage and Degraded Voltage test, shall include a single point verification that the trip occurs within the required delay time, as shown in Ref The Frequency is bascd upon th ýf~ 8 ýmceth calibration interviial fo-r- t-he Insert 1 ......e magnitude of equi pment d.r.i.ft-i.n the sctpein~t analysis.REFERENCES | The setpoints, as well as the response to a Loss of Voltage and Degraded Voltage test, shall include a single point verification that the trip occurs within the required delay time, as shown in Ref The Frequency is bascd upon th ýf~ 8 ýmceth calibration interviial fo-r- t-he Insert 1 ......e magnitude of equi pment d.r.i.ft-i.n the sctpein~t analysis.REFERENCES | ||
: 1. UFSAR, Section 8.3 2. UFSAR, Chapter 15.3. Controlled Dwg. Relay Setpoint Sheets.4. 10 CFR 50, Appendix A, GDC 21.5. Calculation 13-EC-PB-202 | : 1. UFSAR, Section 8.3 2. UFSAR, Chapter 15.3. Controlled Dwg. Relay Setpoint Sheets.4. 10 CFR 50, Appendix A, GDC 21.5. Calculation 13-EC-PB-202 | ||
: 6. Calculations 01, 02, 03-EC-MA-221 PALO VERDE UNITS 1,2,3 B 3.3.7-9 REVISION CPIAS B 3.3.8 BASES SURVEILLANCE SR 3.3.8.1 REQUIREMENTS Performance of the CHANNEL CHECK orce every 12 hours ensures that a gross failure of instrumentation has not occurred on the required radiation monitor channels used in the CPIAS.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. | : 6. Calculations 01, 02, 03-EC-MA-221 PALO VERDE UNITS 1,2,3 B 3.3.7-9 REVISION CPIAS B 3.3.8 BASES SURVEILLANCE SR 3.3.8.1 REQUIREMENTS Performance of the CHANNEL CHECK orce every 12 hours ensures that a gross failure of instrumentation has not occurred on the required radiation monitor channels used in the CPIAS.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. | ||
| Line 1,391: | Line 1,256: | ||
CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.Thp, 1R m h CD-aPy 4- b6e- en rplaRt experiece w-#1th r-egard to- chwanne! OPEPZRB!L!-TY4 t IInsert 1m (continued) | CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.Thp, 1R m h CD-aPy 4- b6e- en rplaRt experiece w-#1th r-egard to- chwanne! OPEPZRB!L!-TY4 t IInsert 1m (continued) | ||
PALO VERDE UNITS 1,2,3 B 3.3.8-7 REVISION 4 CPIAS B 3.3.8 BASES SURVEILLANCE REQUIREMENTS (continued) | PALO VERDE UNITS 1,2,3 B 3.3.8-7 REVISION 4 CPIAS B 3.3.8 BASES SURVEILLANCE REQUIREMENTS (continued) | ||
SR 3.3.8.5 A Every 18 menths, a CHANNEL FUNCTIONAL TEST is performed on the CPIAS Manual Trip channel.This test verifies that the trip handswitches are capable of opening contacts in the Actuation Logic as designed, de-energizing the initiation relays and providing manual actuation of the Funcuc The 18 m .nth Frequency | SR 3.3.8.5 A Every 18 menths, a CHANNEL FUNCTIONAL TEST is performed on the CPIAS Manual Trip channel.This test verifies that the trip handswitches are capable of opening contacts in the Actuation Logic as designed, de-energizing the initiation relays and providing manual actuation of the Funcuc The 18 m .nth Frequency | ||
: 4. ..d Insert .-_ .....the.. ..illane when p .f.r.med at a .qun.y t oc -er 18 rvei .-.... ..REFERENCES | : 4. ..d Insert .-_ .....the.. ..illane when p .f.r.med at a .qun.y t oc -er 18 rvei .-.... ..REFERENCES | ||
: 1. UFSAR, Chapter 15.2. 10 CFR 100.3. "Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants," NUREG-75/087, Revision 1, 1978, Section 6.2.4, Branch Technical Position CSB 6-4, "Containment Purging During Normal Plant Operation." PALO VERDE UNITS 1,2,3 B 3.3.8-8 REVISION 44 CREFAS B 3.3.9 BASES SURVEILLANCE SR 3.3.9.1 REQUIREMENTS Performance of the CHANNEL CHECK ence every 12 heurs ensures that a gross failure of instrumentation has not occurred. | : 1. UFSAR, Chapter 15.2. 10 CFR 100.3. "Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants," NUREG-75/087, Revision 1, 1978, Section 6.2.4, Branch Technical Position CSB 6-4, "Containment Purging During Normal Plant Operation." PALO VERDE UNITS 1,2,3 B 3.3.8-8 REVISION 44 CREFAS B 3.3.9 BASES SURVEILLANCE SR 3.3.9.1 REQUIREMENTS Performance of the CHANNEL CHECK ence every 12 heurs ensures that a gross failure of instrumentation has not occurred. | ||
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. | A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. | ||
| Line 1,411: | Line 1,276: | ||
This test verifies that the trip handswitches are capable of opening contacts in the Actuation Logic as designed, de-energizing the actuation relays and providing Manual Trip of the functio-Tk^ 10 mnn *k Crni-n-i 4 k kcA 4.. .L...r -f n- nn n-insert 1]-Insert-F_ -I --I I "'..r.,-fft -_ im... .ruwl flsCcRelonfts usually, pass the-v I Survepillance when per-formcd-at a Frcequcncy of once every SR 3.3.9.6 This Surveillance ensures that the train actuation respons times are less than the maximum times assumed in the analyses. | This test verifies that the trip handswitches are capable of opening contacts in the Actuation Logic as designed, de-energizing the actuation relays and providing Manual Trip of the functio-Tk^ 10 mnn *k Crni-n-i 4 k kcA 4.. .L...r -f n- nn n-insert 1]-Insert-F_ -I --I I "'..r.,-fft -_ im... .ruwl flsCcRelonfts usually, pass the-v I Survepillance when per-formcd-at a Frcequcncy of once every SR 3.3.9.6 This Surveillance ensures that the train actuation respons times are less than the maximum times assumed in the analyses. | ||
Response time testing criteria are included in Refe-ren. Response Time te.sts arc , A-endutd on a Tet asiS of once per 18 monthsR. The 18 month+Freqencyis based upon plant operating experience, wuhich Sh AWS thait rdmfRailures of. instrumentation components e causing serious response time degradation, but not channel failure, are infrequent occurnrenc-es. | Response time testing criteria are included in Refe-ren. Response Time te.sts arc , A-endutd on a Tet asiS of once per 18 monthsR. The 18 month+Freqencyis based upon plant operating experience, wuhich Sh AWS thait rdmfRailures of. instrumentation components e causing serious response time degradation, but not channel failure, are infrequent occurnrenc-es. | ||
Testing of the final actuating deices, hihmake up the bulk of the response time, is included inthSueilneesng REFERENCES | Testing of the final actuating deices, hihmake up the bulk of the response time, is included inthSueilneesng REFERENCES | ||
: 1. UFSAR, Chapter 15.2. 10 CFR 50, Appendix A, GDC 19.3. UFSAR, Chapter 7.PALO VERDE UNITS 1,2,3 B 3.3.9-7 REVISION 4 PAM Instrumentation B 3.3.10 BASES ACTIONS F.1 (continued) | : 1. UFSAR, Chapter 15.2. 10 CFR 50, Appendix A, GDC 19.3. UFSAR, Chapter 7.PALO VERDE UNITS 1,2,3 B 3.3.9-7 REVISION 4 PAM Instrumentation B 3.3.10 BASES ACTIONS F.1 (continued) | ||
Alternate means of monitoring Reactor Vessel Water Level, RCS Activity, and Containment Area Radiation have been developed and tested. These alternate means may be temporarily installed if the normal PAM channel cannot be restored to OPERABLE status within the allotted time. If these alternate means are used, the Required Action is not to shut down the plant, but rather to follow the directions of Specification 5.6.6. The report provided to the NRC should discuss whether 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 A Note at the beginning of the SR table specifies that REQUIREMENTS the following SRs apply to each PAM instrumentation Function found in Table 3.3.10-1.SR 3.3.10.1 Performance of the CHANNEL CHECK ne e.very 31 days, ensures that a gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. | Alternate means of monitoring Reactor Vessel Water Level, RCS Activity, and Containment Area Radiation have been developed and tested. These alternate means may be temporarily installed if the normal PAM channel cannot be restored to OPERABLE status within the allotted time. If these alternate means are used, the Required Action is not to shut down the plant, but rather to follow the directions of Specification 5.6.6. The report provided to the NRC should discuss whether 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 A Note at the beginning of the SR table specifies that REQUIREMENTS the following SRs apply to each PAM instrumentation Function found in Table 3.3.10-1.SR 3.3.10.1 Performance of the CHANNEL CHECK ne e.very 31 days, ensures that a gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. | ||
| Line 1,442: | Line 1,307: | ||
Operation of the equipment from the remote shutdown panel is not necessary. | Operation of the equipment from the remote shutdown panel is not necessary. | ||
The Surveillance can be satisfied by performance of a continuity check. This will ensure that if the control room becomes inaccessible, the plant can be brought to and maintained in MODE 3 from the remote shutdown panel and the local control statio The 18 month Frequn.c. | 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 brought to and maintained in MODE 3 from the remote shutdown panel and the local control statio The 18 month Frequn.c. | ||
is hbasd on Iar- wn-r t i'° .....d- ti A-..unplan ne tran.sient i.f the S.urvi]]...a nce we re performed with the reactrat powe. Operating experienc-e ddemo-nstrates that Remo Shutdoiw System cont Prl o -m-l l hannel s m fVal toi pass the Surveillance when performed -at a Frequency of once every 18 months.SR 3.3.11.3 CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor. The Surveillance verifies that the channel responds to the measured parameter within the necessary range and accuracy.The 18 month Frequency is based on the need to perform this Surveillance under.. t conditions that appy .during a plant od the potential for an unplanned transient if the IInsert 1_t REFERENCES | is hbasd on Iar- wn-r t i'° .....d- ti A-..unplan ne tran.sient i.f the S.urvi]]...a nce we re performed with the reactrat powe. Operating experienc-e ddemo-nstrates that Remo Shutdoiw System cont Prl o -m-l l hannel s m fVal toi pass the Surveillance when performed -at a Frequency of once every 18 months.SR 3.3.11.3 CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor. The Surveillance verifies that the channel responds to the measured parameter within the necessary range and accuracy.The 18 month Frequency is based on the need to perform this Surveillance under.. t conditions that appy .during a plant od the potential for an unplanned transient if the IInsert 1_t REFERENCES | ||
: 1. 10 CFR 50, Appendix A, GDC 19.2. 10 CFR 50, Appendix R.PALO VERDE UNITS 1,2,3 B 3.3.11-7 REVISION ,54 Boron Dilution Alarm System (BDAS)B 3.3.12 BASES (continued) | : 1. 10 CFR 50, Appendix A, GDC 19.2. 10 CFR 50, Appendix R.PALO VERDE UNITS 1,2,3 B 3.3.11-7 REVISION ,54 Boron Dilution Alarm System (BDAS)B 3.3.12 BASES (continued) | ||
SURVEILLANCE REQUIREMENTS SR 3.3.12.1 S-R 2.2.12.1 is the perf~forance Of a CHANNEL CHECK on eac-h..... hannel every 12 hour.. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. | SURVEILLANCE REQUIREMENTS SR 3.3.12.1 S-R 2.2.12.1 is the perf~forance Of a CHANNEL CHECK on eac-h..... hannel every 12 hour.. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. | ||
| Line 1,457: | Line 1,322: | ||
A-CANNIIEI C.ALIBRTATION is perfor.med every 18 mnths. The Surveillance is a complete check and readjustment of the excore startup channel from the input through to the BDAS.The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational. | A-CANNIIEI C.ALIBRTATION is perfor.med every 18 mnths. The Surveillance is a complete check and readjustment of the excore startup channel from the input through to the BDAS.The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational. | ||
This SR is modified by a Note to indicate that it is not necessary to test the detector, because generating a meaningful test signal is difficult: | This SR is modified by a Note to indicate that it is not necessary to test the detector, because generating a meaningful test signal is difficult: | ||
the detectors are of simple construction, and any failures in the detectors will be apparent as a change in channel out_ , Insert 1 REFERENCES | the detectors are of simple construction, and any failures in the detectors will be apparent as a change in channel out_ , Insert 1 REFERENCES | ||
: 1. UFSAR, Chapter 7 and Chapter 15.PALO VERDE UNITS 1,2,3 B 3.3.12-6 REVISION ra RCS Pressure, Temperature, and Flow DNB Limits B 3.4.1 BASES (continued) | : 1. UFSAR, Chapter 7 and Chapter 15.PALO VERDE UNITS 1,2,3 B 3.3.12-6 REVISION ra RCS Pressure, Temperature, and Flow DNB Limits B 3.4.1 BASES (continued) | ||
SURVEILLANCE SR 3.4.1.1 REQUIREMENTS Since Required Action G1 *all.ows a Completi"n Time of 2 hours to restore parameters that- ac not. within .limt, th 12 hour Sureilance Frequency for pressurizer pressure is uffcict t enurethat the pressure can be rctrdt a noral loperation, steady state condition changcs and other cxpcctcd transient operations. | SURVEILLANCE SR 3.4.1.1 REQUIREMENTS Since Required Action G1 *all.ows a Completi"n Time of 2 hours to restore parameters that- ac not. within .limt, th 12 hour Sureilance Frequency for pressurizer pressure is uffcict t enurethat the pressure can be rctrdt a noral loperation, steady state condition changcs and other cxpcctcd transient operations. | ||
The 12 hour interval has been shown by operating prac sufficient to regularly assess fo poetal degradation and i~nser 1t"S 3/1.Since Required -Action- 01 -allows a Completion Timeo 2nhours" to rsoe parameters that are net WASith limits,.the 12Shour Sureillance Frequency for cold leg temperature is uficintto cnsure that the WC coolant temperature can beastoremntof aS nlowrmal peration, steady state condition following load changes and other expected transient operations. | The 12 hour interval has been shown by operating prac sufficient to regularly assess fo poetal degradation and i~nser 1t"S 3/1.Since Required -Action- 01 -allows a Completion Timeo 2nhours" to rsoe parameters that are net WASith limits,.the 12Shour Sureillance Frequency for cold leg temperature is uficintto cnsure that the WC coolant temperature can beastoremntof aS nlowrmal peration, steady state condition following load changes and other expected transient operations. | ||
The 12 hour interval has been shown by operating practice to be sufficient to regularly asss o potential degradation and to verify operation is wi PALO RED UIS123. 4. 1.1- REIIO3 The 3122 hour SuvilneFrequency for RCS total flwrt is performed using the installed flow instrumentatin Th 12 hour Frequency has been shown by operating expeinet be sufficient to assess fo ptnial degradation and to mo! fied by a Note that only requires performance of this SR in MODE 1. The Note is necessary to allow measurement of RCS flow rate at normal operating conditions at power with all RCPs running.REFERENCES | The 12 hour interval has been shown by operating practice to be sufficient to regularly asss o potential degradation and to verify operation is wi PALO RED UIS123. 4. 1.1- REIIO3 The 3122 hour SuvilneFrequency for RCS total flwrt is performed using the installed flow instrumentatin Th 12 hour Frequency has been shown by operating expeinet be sufficient to assess fo ptnial degradation and to mo! fied by a Note that only requires performance of this SR in MODE 1. The Note is necessary to allow measurement of RCS flow rate at normal operating conditions at power with all RCPs running.REFERENCES | ||
: 1. UFSAR, Section 15.PALO VERDE UNITS 1,2,3 B 3.4.1-5 REVISION Q RCS Minimum Temperature for Criticality B 3.4.2 BASES (continued) | : 1. UFSAR, Section 15.PALO VERDE UNITS 1,2,3 B 3.4.1-5 REVISION Q RCS Minimum Temperature for Criticality B 3.4.2 BASES (continued) | ||
APPLICABILITY The reactor has been designed and analyzed to be critical in MODES 1 and 2 only and in accordance with this specification. | APPLICABILITY The reactor has been designed and analyzed to be critical in MODES 1 and 2 only and in accordance with this specification. | ||
Criticality is not permitted in any other MODE. Therefore, this LCO is applicable in MODE 1, and MODE 2 when Keff 1.0. Monitoring is required at or below a TCOld of 550 0 F. The no load temperature of 565°F is maintained by the Steam Bypass Control System.ACTIONS A.1 If Tcold is below 545 0 F, 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 30 minutes.Rapid reactor shutdown can be readily and practically achieved within a 30 minute period. The allowed time reflects the ability to perform this action and to maintain the plant within the analyzed range.S R URVEILLANCE SR 3.4.2.1 EQUIREMENTS | Criticality is not permitted in any other MODE. Therefore, this LCO is applicable in MODE 1, and MODE 2 when Keff 1.0. Monitoring is required at or below a TCOld of 550 0 F. The no load temperature of 565°F is maintained by the Steam Bypass Control System.ACTIONS A.1 If Tcold is below 545 0 F, 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 30 minutes.Rapid reactor shutdown can be readily and practically achieved within a 30 minute period. The allowed time reflects the ability to perform this action and to maintain the plant within the analyzed range.S R URVEILLANCE SR 3.4.2.1 EQUIREMENTS | ||
_ _eidica lly Tcold is required to be verified _> 545°F once within 30 minutes after any RCS loop Tcold < 550°F and every 30-minu"tes thereaft212.e, The 39 in,,t ti.m. pcried is reactor is critical and temperature is below 550 0 F. A second Frequency requires Tcold to be verified within 30 minutes of reaching criticality. | _ _eidica lly Tcold is required to be verified _> 545°F once within 30 minutes after any RCS loop Tcold < 550°F and every 30-minu"tes thereaft212.e, The 39 in,,t ti.m. pcried is reactor is critical and temperature is below 550 0 F. A second Frequency requires Tcold to be verified within 30 minutes of reaching criticality. | ||
This will require repeated performance of SR 3.4.2.1 since a reactor startup takes longer than 30 minutes. The 30 minute time period is frequent enough to prevent inadvertent violation of the LCO.REFERENCES | This will require repeated performance of SR 3.4.2.1 since a reactor startup takes longer than 30 minutes. The 30 minute time period is frequent enough to prevent inadvertent violation of the LCO.REFERENCES | ||
: 1. UFSAR, Section 15.PALO VERDE UNITS 1,2,3 B 3.4.2-2 REVISION - | : 1. UFSAR, Section 15.PALO VERDE UNITS 1,2,3 B 3.4.2-2 REVISION - | ||
RCS P/T Limits B 3.4.3 BASES ACTIONS C.1 and C.2 (continued) | RCS P/T Limits B 3.4.3 BASES ACTIONS C.1 and C.2 (continued) | ||
| Line 1,479: | Line 1,344: | ||
be plant (continued) | be plant (continued) | ||
PALO VERDE UNITS 1,2,3 B 3.4.3-7 REVISION 62 RCS Loops -MODES 1 and 2 B 3.4.4 BASES SURVEILLANCE REQUIREMENTS SR 3.4.4.1 This SR requires verification every !2 he,-rs that the required number of RCS loops are in operation and circulating reactor coolant. Verification includes flow rate, temperature, or pump status monitoring, which help to ensure that forced flow is providing heat removal while maintaining the margin The Fr..uc..y of 12 h.ur.JInsert I P-- "~r-uLI1 arl ses"s degraý--Ri" -and-. .....n wi-hi zafety analyscz assumptionz. | PALO VERDE UNITS 1,2,3 B 3.4.3-7 REVISION 62 RCS Loops -MODES 1 and 2 B 3.4.4 BASES SURVEILLANCE REQUIREMENTS SR 3.4.4.1 This SR requires verification every !2 he,-rs that the required number of RCS loops are in operation and circulating reactor coolant. Verification includes flow rate, temperature, or pump status monitoring, which help to ensure that forced flow is providing heat removal while maintaining the margin The Fr..uc..y of 12 h.ur.JInsert I P-- "~r-uLI1 arl ses"s degraý--Ri" -and-. .....n wi-hi zafety analyscz assumptionz. | ||
In addition, control roo indic4-atin and- all ar.m.. wi lly i"ndicatc loop "tat REFERENCES | In addition, control roo indic4-atin and- all ar.m.. wi lly i"ndicatc loop "tat REFERENCES | ||
: 1. UFSAR, Section 15.PALO VERDE UNITS 1,2,3 B 3.4.4-4 REVISION 4 RCS Loops -MODE 3 B 3.4.5 BASES ACTIONS (continued) | : 1. UFSAR, Section 15.PALO VERDE UNITS 1,2,3 B 3.4.4-4 REVISION 4 RCS Loops -MODE 3 B 3.4.5 BASES ACTIONS (continued) | ||
C.1 and C.2 If no RCS loop is OPERABLE or in operation, all operations involving a reduction of RCS boron concentration must be immediately suspended. | C.1 and C.2 If no RCS loop is OPERABLE or in operation, all operations involving a reduction of RCS boron concentration must be immediately suspended. | ||
| Line 1,493: | Line 1,358: | ||
te reqIL U iar-asscss RCS loop In, additior,, control room indication and alaFrmS Will oremally indicatc loop status.SR 3.4.6.2 This SR requires verification every 12 hou-rs of secondary side water level in the required SG(s) _ 25% wide range. A adequate SG water level is required in order to have a heat sink for removal of the core decay heat from the reactor cool...... | te reqIL U iar-asscss RCS loop In, additior,, control room indication and alaFrmS Will oremally indicatc loop status.SR 3.4.6.2 This SR requires verification every 12 hou-rs of secondary side water level in the required SG(s) _ 25% wide range. A adequate SG water level is required in order to have a heat sink for removal of the core decay heat from the reactor cool...... | ||
The 12 hAur int.r..al har ..h.W by operation F Insert 1 a6d verify opcration within safety analyses assumptions SR 3.4.6.3 Verification that the required pump is OPERABLE ensures that an additional RCS loop or SDC train can be placed in operation, if needed to maintain decay heat removal and reactor coolant circulation. | The 12 hAur int.r..al har ..h.W by operation F Insert 1 a6d verify opcration within safety analyses assumptions SR 3.4.6.3 Verification that the required pump is OPERABLE ensures that an additional RCS loop or SDC train can be placed in operation, if needed to maintain decay heat removal and reactor coolant circulation. | ||
Verification is performed by verifying proper breaker alignment and power available to the required .4-ýo The Frcgquency of 7 days is considcred Insertl an ha benshown to bhe acceptable by oper-ating-REFERENCES | Verification is performed by verifying proper breaker alignment and power available to the required .4-ýo The Frcgquency of 7 days is considcred Insertl an ha benshown to bhe acceptable by oper-ating-REFERENCES | ||
: 1. PVNGS Operating License Amendments 52, 38 and 24 for Units 1, 2 and 3, respectively, and associated NRC Safety Evaluation dated July 25, 1990.2. Not used.3. PVNGS Calculation 13-JC-SH-0200, Section 2.9.PALO VERDE UNITS 1,2.3 B 3.4.6-5 REVISION 662-RCS Loops -MODE 5, Loops Filled B 3.4.7 BASES (continued) | : 1. PVNGS Operating License Amendments 52, 38 and 24 for Units 1, 2 and 3, respectively, and associated NRC Safety Evaluation dated July 25, 1990.2. Not used.3. PVNGS Calculation 13-JC-SH-0200, Section 2.9.PALO VERDE UNITS 1,2.3 B 3.4.6-5 REVISION 662-RCS Loops -MODE 5, Loops Filled B 3.4.7 BASES (continued) | ||
SURVEILLANCE REQUIREMENTS SR 3.4.7.1 This SR requires verification every 12 he'rs that one SDC train is in operation and circulating reactor coolant at a flow rate of greater than or equal to 3780 gpm. Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing decay heat r:ý The 12 hour Frequency s been sh.w. by .pcrating tc assess d.gr.adation Ind dityi o n iy within safety analyses assumptions Un .dditinn r-ontr-l room iniato .;d 4hr-mg. u.411* i* i I I ora Y inaicatcP 4oo9 StatuS.The SDC flow is established to ensure that core outlet temperature is maintained sufficiently below saturation to allow time for swapover to the standby SDC train should the operating train be lost.SR 3.4.7.2 Verifying the SGs are OPERABLE by ensuring their secondary side water levels are _> 25% wide range level ensures that redundant heat removal paths are available if the second SDC train is inoperable. | SURVEILLANCE REQUIREMENTS SR 3.4.7.1 This SR requires verification every 12 he'rs that one SDC train is in operation and circulating reactor coolant at a flow rate of greater than or equal to 3780 gpm. Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing decay heat r:ý The 12 hour Frequency s been sh.w. by .pcrating tc assess d.gr.adation Ind dityi o n iy within safety analyses assumptions Un .dditinn r-ontr-l room iniato .;d 4hr-mg. u.411* i* i I I ora Y inaicatcP 4oo9 StatuS.The SDC flow is established to ensure that core outlet temperature is maintained sufficiently below saturation to allow time for swapover to the standby SDC train should the operating train be lost.SR 3.4.7.2 Verifying the SGs are OPERABLE by ensuring their secondary side water levels are _> 25% wide range level ensures that redundant heat removal paths are available if the second SDC train is inoperable. | ||
| Line 1,509: | Line 1,374: | ||
PALO VERDE UNITS 1,2,3 B 3.4.9-5 REVISION 4 Pressurizer B 3.4.9 BASES SURVEILLANCE REQUIREMENTS SR 3.4.9.2 (continued) | PALO VERDE UNITS 1,2,3 B 3.4.9-5 REVISION 4 Pressurizer B 3.4.9 BASES SURVEILLANCE REQUIREMENTS SR 3.4.9.2 (continued) | ||
The Surveillance is satisfied when the power supplies are demonstrated to be capable of producing the minimum power and the associated pressurizer heaters are verified to be at their design rating. (This may be done by testing the power supply output and by performing an electrical check on heater element continuit "Th Frcgucncy of insert 1 -nd hll been shown b epience to be acccpbble. | The Surveillance is satisfied when the power supplies are demonstrated to be capable of producing the minimum power and the associated pressurizer heaters are verified to be at their design rating. (This may be done by testing the power supply output and by performing an electrical check on heater element continuit "Th Frcgucncy of insert 1 -nd hll been shown b epience to be acccpbble. | ||
REFERENCES | REFERENCES | ||
: 1. NUREG-0737, November 1980.PALO VERDE UNITS 1,2,3 B 3.4.9-6 REVISION G Pressurizer Safety Valves-MODE 4 B 3.4.11 BASES (continued) | : 1. NUREG-0737, November 1980.PALO VERDE UNITS 1,2,3 B 3.4.9-6 REVISION G Pressurizer Safety Valves-MODE 4 B 3.4.11 BASES (continued) | ||
SURVEILLANCE SR 3.4.11.1 REQUIREMENTS SRs are specified in the Inservice Testing Program.Pressurizer safety valves are to be tested in accordance with the requirements of the ASME OM Code (Ref. 2), which provides the activities and the Frequency necessary to satisfy the SRs. No additional requirements are specified. | SURVEILLANCE SR 3.4.11.1 REQUIREMENTS SRs are specified in the Inservice Testing Program.Pressurizer safety valves are to be tested in accordance with the requirements of the ASME OM Code (Ref. 2), which provides the activities and the Frequency necessary to satisfy the SRs. No additional requirements are specified. | ||
| Line 1,520: | Line 1,385: | ||
REQUIREMENTS b I.- Onoc every 31 days for a vent pathw':ay that l lockId.se le , or- n~ ,,,r-is q e u 22 , eer .the specified flow capacity, it Insert I requires removing all pressurizer safety valves, or similarly establishing a vent by opening the pressurizer manway (Ref. 11). The vent path(s) must be above the level of reactor coolant, so as not to drain the RCS when open.The passive vent arrangement must only be open (vent pathway exists) to be OPERABLE. | REQUIREMENTS b I.- Onoc every 31 days for a vent pathw':ay that l lockId.se le , or- n~ ,,,r-is q e u 22 , eer .the specified flow capacity, it Insert I requires removing all pressurizer safety valves, or similarly establishing a vent by opening the pressurizer manway (Ref. 11). The vent path(s) must be above the level of reactor coolant, so as not to drain the RCS when open.The passive vent arrangement must only be open (vent pathway exists) to be OPERABLE. | ||
These Surveillances need only be performed if the vent or the Shutdown Cooling System suction line relief valves are being used to satisfy the requirements of this LCO. The Frequencies consider operating experience with mispositioning of unlocked and locked pathway vent valves, and passive pathway obstructions. | These Surveillances need only be performed if the vent or the Shutdown Cooling System suction line relief valves are being used to satisfy the requirements of this LCO. The Frequencies consider operating experience with mispositioning of unlocked and locked pathway vent valves, and passive pathway obstructions. | ||
SR 3.4.13.3 SRs are specified in the Inservice Testing Program.Shutdown Cooling System suction line relief valves are to be tested in accordance with the requirements of the ASME OM Code (Ref. 10), which provides the activities and the Frequency necessary to satisfy the SRs. The Shutdown Cooling System suction line relief valve set point is 467 psig.REFERENCES | SR 3.4.13.3 SRs are specified in the Inservice Testing Program.Shutdown Cooling System suction line relief valves are to be tested in accordance with the requirements of the ASME OM Code (Ref. 10), which provides the activities and the Frequency necessary to satisfy the SRs. The Shutdown Cooling System suction line relief valve set point is 467 psig.REFERENCES | ||
: 1. 10 CFR 50, Appendix G.2. Generic Letter 88-11.3. UFSAR, Section 15.4. 10 CFR 50.46.5. 10 CFR 50, Appendix K.6. Generic Letter 90-06.7. UFSAR, Section 5.2.(continued) | : 1. 10 CFR 50, Appendix G.2. Generic Letter 88-11.3. UFSAR, Section 15.4. 10 CFR 50.46.5. 10 CFR 50, Appendix K.6. Generic Letter 90-06.7. UFSAR, Section 5.2.(continued) | ||
PALO VERDE UNITS 1,2,3 B 3.4.13-10 REVISION 64 RCS Operational LEAKAGE B 3.4.14 BASES SURVEILLANCE SR 3.4.14.1 (continued) | PALO VERDE UNITS 1,2,3 B 3.4.13-10 REVISION 64 RCS Operational LEAKAGE B 3.4.14 BASES SURVEILLANCE SR 3.4.14.1 (continued) | ||
REQU IREMENTS An early warning of pressure boundary LEAKAGE or unidentified LEAKAGE is provided by the automatic systems that monitor the containment atmosphere radioactivity and the containment sump level. These leakage detection systems are specified in LCO 3.4.16, "RCS Leakage Detection Instrumentation." Note 2 states that this SR is not applicable to primary to secondary LEAKAGE because LEAKAGE of 150 gallons per day cannot be measured accurately by an RCS water inventory balance.The 72 houpr F ,guency iS a eason-able interwal te txrnd LEAiKAGE -and rnecognizes the impor-tance of early leakage detec-tion in the pr-evention of accnidents This SR verifies that primary to secondary LEAKAGE is less than or equal to 150 gallons per day through any one SG.Satisfying the primary to secondary LEAKAGE limit ensures that the operational LEAKAGE performance criterion in the Steam Generator Program is met. If this SR is not met, compliance with LCO 3.4.18, "Steam Generator Tube Integrity," should be evaluated. | REQU IREMENTS An early warning of pressure boundary LEAKAGE or unidentified LEAKAGE is provided by the automatic systems that monitor the containment atmosphere radioactivity and the containment sump level. These leakage detection systems are specified in LCO 3.4.16, "RCS Leakage Detection Instrumentation." Note 2 states that this SR is not applicable to primary to secondary LEAKAGE because LEAKAGE of 150 gallons per day cannot be measured accurately by an RCS water inventory balance.The 72 houpr F ,guency iS a eason-able interwal te txrnd LEAiKAGE -and rnecognizes the impor-tance of early leakage detec-tion in the pr-evention of accnidents This SR verifies that primary to secondary LEAKAGE is less than or equal to 150 gallons per day through any one SG.Satisfying the primary to secondary LEAKAGE limit ensures that the operational LEAKAGE performance criterion in the Steam Generator Program is met. If this SR is not met, compliance with LCO 3.4.18, "Steam Generator Tube Integrity," should be evaluated. | ||
The 150 gallons per day limit is measured at room temperature as described in Reference | The 150 gallons per day limit is measured at room temperature as described in Reference | ||
: 8. The operational LEAKAGE rate limit applies to LEAKAGE through any one SG. If it is not practical to assign the LEAKAGE to an individual SG, all the primary to secondary LEAKAGE should be conservatively assumed to be from one SG.The Surveillance is modified by a Note which states that the Surveillance is not required to be performed until 12 hours after establishment of steady state operation. | : 8. The operational LEAKAGE rate limit applies to LEAKAGE through any one SG. If it is not practical to assign the LEAKAGE to an individual SG, all the primary to secondary LEAKAGE should be conservatively assumed to be from one SG.The Surveillance is modified by a Note which states that the Surveillance is not required to be performed until 12 hours after establishment of steady state operation. | ||
This means that once steady state operating conditions are established, 12 hours is allowed for completing the Surveillance. | This means that once steady state operating conditions are established, 12 hours is allowed for completing the Surveillance. | ||
| Line 1,535: | Line 1,400: | ||
This Note is not intended to allow transients solely for the purpose of avoiding SR 3.4.14.2 performance. | This Note is not intended to allow transients solely for the purpose of avoiding SR 3.4.14.2 performance. | ||
For RCS primary to secondary LEAKAGE determination, steady state is defined as stable RCS pressure, temperature, power level, pressurizer and makeup tank levels, makeup and letdown, and RCP seal injection and return flows.The Surepillan-e Frequency Of 7i2 hors is a Geasonable intergal to trend primary to secndary LMAy9GE -and reco SizeR te tance of ealy leakage detectonit prevention of accpiddents. | For RCS primary to secondary LEAKAGE determination, steady state is defined as stable RCS pressure, temperature, power level, pressurizer and makeup tank levels, makeup and letdown, and RCP seal injection and return flows.The Surepillan-e Frequency Of 7i2 hors is a Geasonable intergal to trend primary to secndary LMAy9GE -and reco SizeR te tance of ealy leakage detectonit prevention of accpiddents. | ||
The primar-y to secondary LEZAK~rG 4r dctcrmincd using continu -proess radiation monitors or radiochemical grab sampling in accordanea w:ith the EPRI REFERENCES | The primar-y to secondary LEZAK~rG 4r dctcrmincd using continu -proess radiation monitors or radiochemical grab sampling in accordanea w:ith the EPRI REFERENCES | ||
: 1. 10 CFR 50, Appendix A, GDC 30.2. Regulatory Guide 1.45, May 1913.3. UFSAR, Section 15.6.4. UFSAR, Section 6.4.5. 10 CFR Part 100.6. 10 CFR 50, Appendix A, GDC19.7. NEI 97-06, "Steam Generator Program Guidelines." 8. EPRI, "Pressurized Water Reactor Primary-to-Secondary Leak Guidelines." PALO VERDE UNITS 1,2,3 B 3.4.14-8 REVISION 39 RCS PIV Leakage B 3.4.15 BASES SURVEILLANCE REQUIREMENTS | : 1. 10 CFR 50, Appendix A, GDC 30.2. Regulatory Guide 1.45, May 1913.3. UFSAR, Section 15.6.4. UFSAR, Section 6.4.5. 10 CFR Part 100.6. 10 CFR 50, Appendix A, GDC19.7. NEI 97-06, "Steam Generator Program Guidelines." 8. EPRI, "Pressurized Water Reactor Primary-to-Secondary Leak Guidelines." PALO VERDE UNITS 1,2,3 B 3.4.14-8 REVISION 39 RCS PIV Leakage B 3.4.15 BASES SURVEILLANCE REQUIREMENTS | ||
!insert 1 ----SR 3.4.15.1 (continued) | !insert 1 ----SR 3.4.15.1 (continued) | ||
| Line 1,548: | Line 1,413: | ||
The Note that allows this provision is complimentary to the Frequency of prior to entry into MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months. In addition, this Surveillance is not required to be performed on the SDC System when the SDC System is aligned to the RCS in the shutdown cooling mode of operation. | The Note that allows this provision is complimentary to the Frequency of prior to entry into MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months. In addition, this Surveillance is not required to be performed on the SDC System when the SDC System is aligned to the RCS in the shutdown cooling mode of operation. | ||
PIVs contained in the SDC shutdown cooling flow path must be leakage rate tested after SDC is secured and stable unit conditions and the necessary differential pressures are established. | PIVs contained in the SDC shutdown cooling flow path must be leakage rate tested after SDC is secured and stable unit conditions and the necessary differential pressures are established. | ||
SR 3.4.15.2 Verifying that the SDC open permissive interlocks are OPERABLE, when tested as described in Reference 10, ensures that RCS pressure will not pressurize the SDC system beyond 125% of its design pressure of 485 psig. The interlock setpoint that prevents the valves from being opened is set so the actual RCS pressure must be <410 psia to open the valves. This setpoint ensures the SDC design pressure will not be exceeded and the SDC relief valves (Reference | SR 3.4.15.2 Verifying that the SDC open permissive interlocks are OPERABLE, when tested as described in Reference 10, ensures that RCS pressure will not pressurize the SDC system beyond 125% of its design pressure of 485 psig. The interlock setpoint that prevents the valves from being opened is set so the actual RCS pressure must be <410 psia to open the valves. This setpoint ensures the SDC design pressure will not be exceeded and the SDC relief valves (Reference | ||
: 9) will not lI The IS mgifth PpgeG ...... baStd t hP APeed- to-bascd on considerati-V V of th e ndesig n that aIpi y confiýrmig oprtn xper-ience of the equipment.(continued) | : 9) will not lI The IS mgifth PpgeG ...... baStd t hP APeed- to-bascd on considerati-V V of th e ndesig n that aIpi y confiýrmig oprtn xper-ience of the equipment.(continued) | ||
PALO VERDE UNITS 1,2,3 B 3.4.15-6 REVISION 35 RCS Leakage Detection Instrumentation B 3.4.16 BASES (continued) | PALO VERDE UNITS 1,2,3 B 3.4.15-6 REVISION 35 RCS Leakage Detection Instrumentation B 3.4.16 BASES (continued) | ||
| Line 1,558: | Line 1,423: | ||
These SRs require the performance of a CHANNEL CALIBRATION for each of the RCS leakage detection instrumentation channels. | These SRs require the performance of a CHANNEL CALIBRATION for each of the RCS leakage detection instrumentation channels. | ||
The calibration verifies the accuracy of the instrument string, including the instruments located inside containme The F=P ..u..y of 18 months is a typica~l and1 Pesiep insert thi Oprain cpcieccha sy is acceptable. | The calibration verifies the accuracy of the instrument string, including the instruments located inside containme The F=P ..u..y of 18 months is a typica~l and1 Pesiep insert thi Oprain cpcieccha sy is acceptable. | ||
REFERENCES | REFERENCES | ||
: 1. 10 CFR 50, Appendix A, Section IV, GDC 30.2. Regulatory Guide 1.45.3. UFSAR, Section 5.2.5.PALO VERDE UNITS 1,2,3 B 3.4.16-6 REVISION 0 RCS Specific Activity B 3.4.17 BASES (continued) | : 1. 10 CFR 50, Appendix A, Section IV, GDC 30.2. Regulatory Guide 1.45.3. UFSAR, Section 5.2.5.PALO VERDE UNITS 1,2,3 B 3.4.16-6 REVISION 0 RCS Specific Activity B 3.4.17 BASES (continued) | ||
SURVEILLANCE SR 3.4.17.1 REQUIREMENTS The Surveillance requires performing a gamma isotopic analysis as a measure of the gross specific activity of the reactor coolant at lea-st on.e pe 7 days. While basically a quantitative measure of radionuclides with half lives longer than 15 minutes, excluding iodines, this measurement is the sum of the degassed gamma activities and the gaseous gamma activities in the sample taken. This Surveillance provides an indication of any increase in gross specific activity.Trending the results of this Surveillance allows proper remedial action to be taken before reaching the LCO limit under normal operating conditions. | SURVEILLANCE SR 3.4.17.1 REQUIREMENTS The Surveillance requires performing a gamma isotopic analysis as a measure of the gross specific activity of the reactor coolant at lea-st on.e pe 7 days. While basically a quantitative measure of radionuclides with half lives longer than 15 minutes, excluding iodines, this measurement is the sum of the degassed gamma activities and the gaseous gamma activities in the sample taken. This Surveillance provides an indication of any increase in gross specific activity.Trending the results of this Surveillance allows proper remedial action to be taken before reaching the LCO limit under normal operating conditions. | ||
| Line 1,566: | Line 1,431: | ||
The E determination directly relates to the LCO and is required to verify plant operation within the specified gross activity LCO limit. The analysis for E is a measurement of the average energies per disintegration for isotopes with half lives longer than 15 minutes, excludin i The F..guency of 184 days IInsert 1 .........= ....This SR has been modified by a Note that indicates sampling is required to be performed within 31 days after 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours should the 184 day Frequency interval be exceeded. | The E determination directly relates to the LCO and is required to verify plant operation within the specified gross activity LCO limit. The analysis for E is a measurement of the average energies per disintegration for isotopes with half lives longer than 15 minutes, excludin i The F..guency of 184 days IInsert 1 .........= ....This SR has been modified by a Note that indicates sampling is required to be performed within 31 days after 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours should the 184 day Frequency interval be exceeded. | ||
Further discussion of SR Note format is found in Section 1.4.Frequency. | Further discussion of SR Note format is found in Section 1.4.Frequency. | ||
equilibrium skewed by a This ensures the radioactive materials are at so the analysis for E is representative and not crud burst or other similar abnormal event.REFERENCES | equilibrium skewed by a This ensures the radioactive materials are at so the analysis for E is representative and not crud burst or other similar abnormal event.REFERENCES | ||
: 1. 10 CFR 100.11, 1973.2. UFSAR, Section 15.6.3.PALO VERDE UNITS 1,2,3 B 3.4.17-6 REVISION SITs-Operating B 3.5.1 BASES (continued) | : 1. 10 CFR 100.11, 1973.2. UFSAR, Section 15.6.3.PALO VERDE UNITS 1,2,3 B 3.4.17-6 REVISION SITs-Operating B 3.5.1 BASES (continued) | ||
SURVEILLANCE SR 3.5.1.1 REQUIREMENTS Verification every 12 he'-rs that each SIT isolation valve is fully open, as indicated in the control room, ensures that SITs are available for injection and ensures timely discovery if a valve should be partially closed. If an isolation valve is not fully open, the rate of injection to the RCS would be reduced. Although a motor operated valve should not change position with power removed, a closed valve could result in not meeting accident analysis assumpti 12 hour Frc..qu.. | SURVEILLANCE SR 3.5.1.1 REQUIREMENTS Verification every 12 he'-rs that each SIT isolation valve is fully open, as indicated in the control room, ensures that SITs are available for injection and ensures timely discovery if a valve should be partially closed. If an isolation valve is not fully open, the rate of injection to the RCS would be reduced. Although a motor operated valve should not change position with power removed, a closed valve could result in not meeting accident analysis assumpti 12 hour Frc..qu.. | ||
| Line 1,587: | Line 1,452: | ||
REQUIREMENTS beca'use the ..ater. contincd in the RIT igs withi thc SIT boro conentrtion rcquircr ts." This; is conSiStent With the rcommndatons f NUHREG 136 (Ref1.SR 3.5.2.5 Verification every-41 day.& that power is removed from each required SIT isolation valve operator when the pressurizer pressure is 1500 psia ensures that an active failure could not result in the undetected closure of a SIT motor operated isolation valve. If this were to occur, two less than the required SITs would be available for injection, given a single failure coincident with a LOCA.Since installation and remo'eal of power to the SIT iseolation valve is eonducted " admi tr-*4"e control,-the 31 day Frequency was chosen to ppevide -ad-ditionRal Slnser 11 --1 SR allows power to be supplied to the motor operated isolation valves when pressurizer pressure is < 1500 psia, thus allowing operational flexibility by avoiding unnecessary delays to manipulate the breakers during unit startups or shutdowns. | REQUIREMENTS beca'use the ..ater. contincd in the RIT igs withi thc SIT boro conentrtion rcquircr ts." This; is conSiStent With the rcommndatons f NUHREG 136 (Ref1.SR 3.5.2.5 Verification every-41 day.& that power is removed from each required SIT isolation valve operator when the pressurizer pressure is 1500 psia ensures that an active failure could not result in the undetected closure of a SIT motor operated isolation valve. If this were to occur, two less than the required SITs would be available for injection, given a single failure coincident with a LOCA.Since installation and remo'eal of power to the SIT iseolation valve is eonducted " admi tr-*4"e control,-the 31 day Frequency was chosen to ppevide -ad-ditionRal Slnser 11 --1 SR allows power to be supplied to the motor operated isolation valves when pressurizer pressure is < 1500 psia, thus allowing operational flexibility by avoiding unnecessary delays to manipulate the breakers during unit startups or shutdowns. | ||
Even with power supplied to the valves, inadvertent closure is prevented by the RCS pressure interlock associated with the valves. Should closure of a valve occur in spite of the interlock, the SI signal provided to the valves would open a closed valve in the event of a LOCA. At RCS pressures above the valve auto-open interlock, the maximum pressure at which the SIAS open signal will open the. valves is limited by the valve operator differential pressure design capability. | Even with power supplied to the valves, inadvertent closure is prevented by the RCS pressure interlock associated with the valves. Should closure of a valve occur in spite of the interlock, the SI signal provided to the valves would open a closed valve in the event of a LOCA. At RCS pressures above the valve auto-open interlock, the maximum pressure at which the SIAS open signal will open the. valves is limited by the valve operator differential pressure design capability. | ||
REFERENCES | REFERENCES | ||
: 1. IEEE Standard 279-1971.2. 10 CFR 50.46.3. UFSAR, Chapter 15.4. NUREG-1366, "Improvements to Technical Specifications Surveillance Requirements," December 1992.5. CE NPSD-994, "CEOG Joint Applications Report for Safety Injection Tank AOT/STI Extension," May 1995.6. UFSAR Section 7.6.2.2.2 7. TRM T3.5 (ECCS): TSR 3.5.200.4 PALO VERDE UNITS 1,2,3 B 3.5.2-10 REVISION 5 ECCS -Operating B 3.5.3 BASES SURVEILLANCE SR 3.5.3.1 REQUIREMENTS 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. | : 1. IEEE Standard 279-1971.2. 10 CFR 50.46.3. UFSAR, Chapter 15.4. NUREG-1366, "Improvements to Technical Specifications Surveillance Requirements," December 1992.5. CE NPSD-994, "CEOG Joint Applications Report for Safety Injection Tank AOT/STI Extension," May 1995.6. UFSAR Section 7.6.2.2.2 7. TRM T3.5 (ECCS): TSR 3.5.200.4 PALO VERDE UNITS 1,2,3 B 3.5.2-10 REVISION 5 ECCS -Operating B 3.5.3 BASES SURVEILLANCE SR 3.5.3.1 REQUIREMENTS 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. | 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. | ||
| Line 1,613: | Line 1,478: | ||
g V g SR 3.5.5.3 Boron concentration of the RWT shall be verified every 7-days to be within the required range. This Frequency ensures that the reactor will remain subcritical following a LOCA and the boron precipitation in the core will not occur earlier than predicted. | g V g SR 3.5.5.3 Boron concentration of the RWT shall be verified every 7-days to be within the required range. This Frequency ensures that the reactor will remain subcritical following a LOCA and the boron precipitation in the core will not occur earlier than predicted. | ||
Further, it ensures that the resulting sump pH will be maintained in an acceptable range such that the effect of chloride and caustic stress corrosion on mechanical systems and components will be minimiTedp, inee ¢ RIITI ,,lw,1 4s. ne- l stab I, a 7 day.......... | Further, it ensures that the resulting sump pH will be maintained in an acceptable range such that the effect of chloride and caustic stress corrosion on mechanical systems and components will be minimiTedp, inee ¢ RIITI ,,lw,1 4s. ne- l stab I, a 7 day.......... | ||
is ... ... R÷,=~ ..hwn t-hpnngh I .....r ...Z. ..... ...... ..... .. .. ...hag Insert I ..1 ........ ex e ie e to be .. aee p hl e .REFERENCES | is ... ... R÷,=~ ..hwn t-hpnngh I .....r ...Z. ..... ...... ..... .. .. ...hag Insert I ..1 ........ ex e ie e to be .. aee p hl e .REFERENCES | ||
: 1. UFSAR, Chapter 6 and Chapter 15.2. Engineering Calculation 13-JC-CH-0209 PALO VERDE UNITS 1,2,3 B 3.5.5-9 REVISION -51 TSP B 3.5.6 BASES ACTIONS (continued) | : 1. UFSAR, Chapter 6 and Chapter 15.2. Engineering Calculation 13-JC-CH-0209 PALO VERDE UNITS 1,2,3 B 3.5.5-9 REVISION -51 TSP B 3.5.6 BASES ACTIONS (continued) | ||
B.1 and B.2 If the TSP cannot be restored within limits within the Completion Time of Required Action A.1, the plant must be brought to a MODE in which the LCO does not apply. The specified Completion Times for reaching MODES 3 and 4 are those used throughout the Technical Specifications: | B.1 and B.2 If the TSP cannot be restored within limits within the Completion Time of Required Action A.1, the plant must be brought to a MODE in which the LCO does not apply. The specified Completion Times for reaching MODES 3 and 4 are those used throughout the Technical Specifications: | ||
| Line 1,631: | Line 1,496: | ||
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 which is applicable to SR 3.6.1.1. This ensures that air lock leakage is properly accounted for in determining the combined Type Band C containment leakage rate.SR 3.6.2.2 The air lock interlock is designed to prevent simultaneous opening of both doors in a single air lock. Since both the inner and outer doors of an air lock are designed to withstand the maximum expected post accident containment pressure, closure of either door will support containment OPERABILITY. | 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 which is applicable to SR 3.6.1.1. This ensures that air lock leakage is properly accounted for in determining the combined Type Band C containment leakage rate.SR 3.6.2.2 The air lock interlock is designed to prevent simultaneous opening of both doors in a single air lock. Since both the inner and outer doors of an air lock are designed to withstand the maximum expected post accident containment pressure, closure of either door will support containment OPERABILITY. | ||
Thus, the door interlock feature supports containment OPERABILITY while the air lock is being used for personnel transit into and out of containment. | Thus, the door interlock feature supports containment OPERABILITY while the air lock is being used for personnel transit into and out of containment. | ||
Periodic testing of this interlock demonstrates that the interlock will function as designed and that simultaneous opening of the inner and outer doors will not inadvertently occur. Due to the purely mechanical nature of this interlock, and given that the interlock mechanism is not normally challenged when containment is used for entry and exit (procedures require strict adherence to single door opening), this test is only undder the cond-itions that apply dur-ing a plant outage, anid the potential for- loss of containment OPERABILITY if the Suryeillance were per-for m e d w:i the reco ?tpoF. The 24 month Frequency forP the interlock is justified based on gener-ic-oper-ating exein. The Frequency is based on engieerng udgentandis considered adequate given that theQ inter-lock is not challenged during the use of the-REFERENCES | Periodic testing of this interlock demonstrates that the interlock will function as designed and that simultaneous opening of the inner and outer doors will not inadvertently occur. Due to the purely mechanical nature of this interlock, and given that the interlock mechanism is not normally challenged when containment is used for entry and exit (procedures require strict adherence to single door opening), this test is only undder the cond-itions that apply dur-ing a plant outage, anid the potential for- loss of containment OPERABILITY if the Suryeillance were per-for m e d w:i the reco ?tpoF. The 24 month Frequency forP the interlock is justified based on gener-ic-oper-ating exein. The Frequency is based on engieerng udgentandis considered adequate given that theQ inter-lock is not challenged during the use of the-REFERENCES | ||
: 1. 10 CFR 50, Appendix J, Option B.2. UFSAR, Section 3.8.3. UFSAR, Section 6.2.4. UFSAR, Section 15.6 PALO VERDE UNITS 1,2,3 B 3.6.2-8 REVISION 4 Containment Isolation Valves B 3.6.3 BASES I42 inchI SURVEILLANCE SR 3.6.3.1 REQUIREMENTS Ea=h required-42 i .. timent pur-ge valv:e is required to-containment i/not caused by an inadvertent or spurious opening of a ontainment purge valve. Detailed analysis of the refueling purge valves failed to conclusively demonstrate their ability to close during a LOCA in time to limit offsite doses. Therefore, these valves are required to be in the sealed closed position during MODES 1, 2, 3, and 4. A required containment purge valve that is sealed closed must have motive power to the valve operator removed. This can be accomplished by de-energizing the source of electric power.In this application, the term "sealed" has no connotation of leak tight The ..egu.nc.y is a result. of an NRC tm,- F ,,, ,ee i is u ,,24 (Ref 4), r-l, e ..Insert I cture valve use dur.ing unit operation+. | : 1. 10 CFR 50, Appendix J, Option B.2. UFSAR, Section 3.8.3. UFSAR, Section 6.2.4. UFSAR, Section 15.6 PALO VERDE UNITS 1,2,3 B 3.6.2-8 REVISION 4 Containment Isolation Valves B 3.6.3 BASES I42 inchI SURVEILLANCE SR 3.6.3.1 REQUIREMENTS Ea=h required-42 i .. timent pur-ge valv:e is required to-containment i/not caused by an inadvertent or spurious opening of a ontainment purge valve. Detailed analysis of the refueling purge valves failed to conclusively demonstrate their ability to close during a LOCA in time to limit offsite doses. Therefore, these valves are required to be in the sealed closed position during MODES 1, 2, 3, and 4. A required containment purge valve that is sealed closed must have motive power to the valve operator removed. This can be accomplished by de-energizing the source of electric power.In this application, the term "sealed" has no connotation of leak tight The ..egu.nc.y is a result. of an NRC tm,- F ,,, ,ee i is u ,,24 (Ref 4), r-l, e ..Insert I cture valve use dur.ing unit operation+. | ||
This SR is not required to be met while in Condition D of this LCO.This is reasonable since the penetration flow path would be isolated.SR 3.6.3.2 This SR ensures that the power access purge valves are closed as required or, if open, open for an allowable reason. If a purge valve is open in violation of this SR, the valve is considered inoperable. | This SR is not required to be met while in Condition D of this LCO.This is reasonable since the penetration flow path would be isolated.SR 3.6.3.2 This SR ensures that the power access purge valves are closed as required or, if open, open for an allowable reason. If a purge valve is open in violation of this SR, the valve is considered inoperable. | ||
| Line 1,647: | Line 1,512: | ||
Wa ....epe GGA ....18 month Frequenccy. | Wa ....epe GGA ....18 month Frequenccy. | ||
Thcreorc th Fr............... | Thcreorc th Fr............... | ||
coclde to ~ ~ ~ b be-fre accptbl from~ a reiaiit tadoit REFERENCES | coclde to ~ ~ ~ b be-fre accptbl from~ a reiaiit tadoit REFERENCES | ||
: 1. UFSAR Section 6.2.4.2. UFSAR, Section 6.2.6.3. Generic Issue B-20.4. Generic Issue B-24.5. 10 CFR 50, Appendix J. Option B.6. 10 CFR 50, Appendix A 7. CL Design Basis Manual 8. CRDR 106542 9. CRDR 2326591 PALO VERDE UNITS 1,2,3 B 3.6.3-19 REVISION 43 Containment Pressure B 3.6.4 BASES ACTIONS A.1 When containment pressure is not within the limits of the LCO, containment pressure must be restored to within these limits within 1 hour. The Required Action is necessary to return operation to within the bounds of the containment analysis. | : 1. UFSAR Section 6.2.4.2. UFSAR, Section 6.2.6.3. Generic Issue B-20.4. Generic Issue B-24.5. 10 CFR 50, Appendix J. Option B.6. 10 CFR 50, Appendix A 7. CL Design Basis Manual 8. CRDR 106542 9. CRDR 2326591 PALO VERDE UNITS 1,2,3 B 3.6.3-19 REVISION 43 Containment Pressure B 3.6.4 BASES ACTIONS A.1 When containment pressure is not within the limits of the LCO, containment pressure must be restored to within these limits within 1 hour. The Required Action is necessary to return operation to within the bounds of the containment analysis. | ||
The 1 hour Completion Time is consistent with the ACTIONS of LCO 3.6.1, "Containment," which requires that containment be restored to OPERABLE status within 1 hour.B.1 and B.2 If containment pressure cannot be restored to within limits within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 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 3.6.4.1 REQUIREMENTS Verifying that containment pressure is within limits ensures that operation remains within the limits assumed in the accident analv .The 12 hour thi, SR was Insert experieneRP related to trending Of containment ppe~surze.-ariations during the applicable MODES. Furthermore, the 12 hour Frunc- iz adequate in ew,, of other ind-atioens | The 1 hour Completion Time is consistent with the ACTIONS of LCO 3.6.1, "Containment," which requires that containment be restored to OPERABLE status within 1 hour.B.1 and B.2 If containment pressure cannot be restored to within limits within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 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 3.6.4.1 REQUIREMENTS Verifying that containment pressure is within limits ensures that operation remains within the limits assumed in the accident analv .The 12 hour thi, SR was Insert experieneRP related to trending Of containment ppe~surze.-ariations during the applicable MODES. Furthermore, the 12 hour Frunc- iz adequate in ew,, of other ind-atioens | ||
.'ailabale in the contiro] room, including alar-ms, to aertthe epcrator to -an abnorma] con-tainmcnt prczzure REFERENCES | .'ailabale in the contiro] room, including alar-ms, to aertthe epcrator to -an abnorma] con-tainmcnt prczzure REFERENCES | ||
: 1. UFSAR, Section 6.2.1 2. UPSAR, Section 7.2 3. Calculation 13-JC-HC-201 PALO VERDE UNITS 1,2,3 B 3.6.4-3 REVISION - | : 1. UFSAR, Section 6.2.1 2. UPSAR, Section 7.2 3. Calculation 13-JC-HC-201 PALO VERDE UNITS 1,2,3 B 3.6.4-3 REVISION - | ||
Containment Air T emperature B 3.6.5 BASES (continued) | Containment Air T emperature B 3.6.5 BASES (continued) | ||
| Line 1,677: | Line 1,542: | ||
Performance of this SR demonstrates that each spray nozzle is unobstructed and provides assurance that spray coverage of the containment during an accident is not deg ue to the passive (conti nued)PALO VERDE UNITS 1,2,3 B 3.6.6-8 REVISION 49 ADVs B 3.7.4 BASES ACTIONS C.1 and C.2 If the ADV lines cannot be restored to OPERABLE status within the associated Completion Time, 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 6 hours, and in MODE 4, without reliance on the steam generator for heat removal, within 24 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 REQUIREMENTS | Performance of this SR demonstrates that each spray nozzle is unobstructed and provides assurance that spray coverage of the containment during an accident is not deg ue to the passive (conti nued)PALO VERDE UNITS 1,2,3 B 3.6.6-8 REVISION 49 ADVs B 3.7.4 BASES ACTIONS C.1 and C.2 If the ADV lines cannot be restored to OPERABLE status within the associated Completion Time, 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 6 hours, and in MODE 4, without reliance on the steam generator for heat removal, within 24 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 REQUIREMENTS | ||
[Insert1 SR 3.7.4.1 To perform a controlled cooldown of the RCS, the ADVs must be able to be opened and throttled through their full range.This SR ensures the ADVs are tested through a full control cycle at least once per fuel cycle. Performance of inservice testing or use of an ADV during a unit cooldown may satisfy this reqjrew n ...-,, cxpcri .... hz Csbw +at't-h iiOMPOPntz Usually pass thc- SR 1APhcn p r-~FFL formedu J abI bi- *8 MORtHr rucqucilcY. | [Insert1 SR 3.7.4.1 To perform a controlled cooldown of the RCS, the ADVs must be able to be opened and throttled through their full range.This SR ensures the ADVs are tested through a full control cycle at least once per fuel cycle. Performance of inservice testing or use of an ADV during a unit cooldown may satisfy this reqjrew n ...-,, cxpcri .... hz Csbw +at't-h iiOMPOPntz Usually pass thc- SR 1APhcn p r-~FFL formedu J abI bi- *8 MORtHr rucqucilcY. | ||
i repefere, LiIe quencby iz dbbeprba-e 0 fdrom a !remElabilit:y btan1mrdpoint REFERENCES | i repefere, LiIe quencby iz dbbeprba-e 0 fdrom a !remElabilit:y btan1mrdpoint REFERENCES | ||
: 1. UFSAR, Section 10.3.PALO VERDE UNITS 1,2,3 B 3.7.4-5 REVISION 9g AFW System B 3.7.5 BASES ACTIONS E.1 (continued) | : 1. UFSAR, Section 10.3.PALO VERDE UNITS 1,2,3 B 3.7.4-5 REVISION 9g AFW System B 3.7.5 BASES ACTIONS E.1 (continued) | ||
Required Action E.1 is modified by a Note indicating that all required MODE changes or power reductions are suspended until one AFW train is restored to OPERABLE status.Completion Times are also suspended at the time the Condition is entered. The Completion Time is resumed with the time remaining when the Condition was entered upon restoration of one AFW train to OPERABLE status.With one AFW train inoperable, action must be taken to immediately restore the inoperable train to OPERABLE status or to immediately verify, by administrative means, the OPERABILITY of a second train. LCO 3.0.3 is not applicable, as it could force the unit into a less safe condition. | Required Action E.1 is modified by a Note indicating that all required MODE changes or power reductions are suspended until one AFW train is restored to OPERABLE status.Completion Times are also suspended at the time the Condition is entered. The Completion Time is resumed with the time remaining when the Condition was entered upon restoration of one AFW train to OPERABLE status.With one AFW train inoperable, action must be taken to immediately restore the inoperable train to OPERABLE status or to immediately verify, by administrative means, the OPERABILITY of a second train. LCO 3.0.3 is not applicable, as it could force the unit into a less safe condition. | ||
| Line 1,700: | Line 1,565: | ||
PALO VERDE UNITS 1,2,3 B 3.7.5-10 REVISION 4 CST B 3.7.6 BASES ACTIONS (continued) | PALO VERDE UNITS 1,2,3 B 3.7.5-10 REVISION 4 CST B 3.7.6 BASES ACTIONS (continued) | ||
B.l and B.2 If the CST cannot be restored to OPERABLE status within the associated Completion Time, 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 6 hours, and in MODE 4, without reliance on steam generator for heat removal, within 24 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 REQUIREMENTS SR 3.7.6.1 This SR verifies that the CST contains the required volume of cooling water. (This level ! 29.5 ft (300.000 galltonsýS iInsert 1"" affect the rCT kinentory between c.he.ks The 12 hour F u ncis cnusidercd adequate in vien W onf o nther u indic-ationAs in. the control room, including alar-m, to alert the operator to abnorm-al CSTU levealdeito. | B.l and B.2 If the CST cannot be restored to OPERABLE status within the associated Completion Time, 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 6 hours, and in MODE 4, without reliance on steam generator for heat removal, within 24 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 REQUIREMENTS SR 3.7.6.1 This SR verifies that the CST contains the required volume of cooling water. (This level ! 29.5 ft (300.000 galltonsýS iInsert 1"" affect the rCT kinentory between c.he.ks The 12 hour F u ncis cnusidercd adequate in vien W onf o nther u indic-ationAs in. the control room, including alar-m, to alert the operator to abnorm-al CSTU levealdeito. | ||
REFERENCES | REFERENCES | ||
: 1. UFSAR, Section 9.2.6.2. UFSAR, Chapter 6.3. UFSAR, Chapter 15.4. NRC Standard Review Plan Branch Technical Position (BTP) RSB 5-1.PALO VERDE UNITS 1,2,3 B 3.7.6-4 REVISION 64 EW System B 3.7.7 BASES B.1 and B.2 (continued) | : 1. UFSAR, Section 9.2.6.2. UFSAR, Chapter 6.3. UFSAR, Chapter 15.4. NRC Standard Review Plan Branch Technical Position (BTP) RSB 5-1.PALO VERDE UNITS 1,2,3 B 3.7.6-4 REVISION 64 EW System B 3.7.7 BASES B.1 and B.2 (continued) | ||
The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.SURVEILLANCE SR 3.7.7.1 REQUIREMENTS Verifying the correct alignment for manual, power operated, and automatic valves in the EW flow path provides assurance that the proper flow paths exist for EW operation. | 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 3.7.7.1 REQUIREMENTS Verifying the correct alignment for manual, power operated, and automatic valves in the EW flow path provides assurance that the proper flow paths exist for EW operation. | ||
| Line 1,708: | Line 1,573: | ||
PALO VERDE UNITS 1,2,3 B 3.7.7-4 REVISION - | PALO VERDE UNITS 1,2,3 B 3.7.7-4 REVISION - | ||
EW System B 3.7.7 BASES SURVEILLANCE REQUIREMENTS IInsert I [-SR 3.7.7.2 (continued) administrative control-,> .peratingq | EW System B 3.7.7 BASES SURVEILLANCE REQUIREMENTS IInsert I [-SR 3.7.7.2 (continued) administrative control-,> .peratingq | ||
.xpcri.n. e has -shown th't u~ua1v -thp Surveill.,nce whr:n pcrfo....-at the 18 month Frequency. .Thccforce, the Frequenc iz acccpt-ablc from -R reli-ability standpoit SR 3.7.7.3 This SR verifies proper automatic operation of the EW on an actual or simulated actuation si -pera itng v,.pumps ilnsert '1 ]- u-e Therefore, thc Frequency is EGcceptabc from a rc.liability REFERENCES | .xpcri.n. e has -shown th't u~ua1v -thp Surveill.,nce whr:n pcrfo....-at the 18 month Frequency. .Thccforce, the Frequenc iz acccpt-ablc from -R reli-ability standpoit SR 3.7.7.3 This SR verifies proper automatic operation of the EW on an actual or simulated actuation si -pera itng v,.pumps ilnsert '1 ]- u-e Therefore, thc Frequency is EGcceptabc from a rc.liability REFERENCES | ||
: 1. UFSAR, Section 9.2.2.2. UFSAR, Section 9.2.1.3. CRDR 980794 PALO VERDE UNITS 1,2,3 B 3.7.7-5 REVISION - | : 1. UFSAR, Section 9.2.2.2. UFSAR, Section 9.2.1.3. CRDR 980794 PALO VERDE UNITS 1,2,3 B 3.7.7-5 REVISION - | ||
ESPS B 3.7.8 BASES SURVEILLANCE SR 3.7.8.1 (continued) | ESPS B 3.7.8 BASES SURVEILLANCE SR 3.7.8.1 (continued) | ||
| Line 1,714: | Line 1,579: | ||
rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position. | rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position. | ||
This SR is modified by a Note indicating that the isolation of the ESPS components or systems renders those components or systems inoperable but does not necessarily affect the OPERABILITY of the ESPS. Isolation of the ESPS to the Diesel Generator (DG) cooler(s), while rendering the DG inoperable, is acceptable and does not impact the OPERABILITY of the ESPS. Isolation of the ESPS to the essential cooling water heat exchanger is not acceptable and would render both the Essential Cooling Water System and the ESPS inoperable (Ref. 3). The ESPS is inoperable in this situation because it is operating outside of the acceptable limits of the system.The 31 day Frequenc-y is based on engineering judgment, i4 cositetwith the proccdural controls 9ocnn .a PVc S',R 31.77.8.2 The SR verifies proper automatic operation of the ESPS pumps 1on an a.ctual or simulated act " " .ip SInsert S1rvei!!ane | This SR is modified by a Note indicating that the isolation of the ESPS components or systems renders those components or systems inoperable but does not necessarily affect the OPERABILITY of the ESPS. Isolation of the ESPS to the Diesel Generator (DG) cooler(s), while rendering the DG inoperable, is acceptable and does not impact the OPERABILITY of the ESPS. Isolation of the ESPS to the essential cooling water heat exchanger is not acceptable and would render both the Essential Cooling Water System and the ESPS inoperable (Ref. 3). The ESPS is inoperable in this situation because it is operating outside of the acceptable limits of the system.The 31 day Frequenc-y is based on engineering judgment, i4 cositetwith the proccdural controls 9ocnn .a PVc S',R 31.77.8.2 The SR verifies proper automatic operation of the ESPS pumps 1on an a.ctual or simulated act " " .ip SInsert S1rvei!!ane | ||
,-a 'e n rfermed at the 18 month Frequency, Thrfrthe Frequency is a~cceptable fro-m -a re-li-ability REFERENCES | ,-a 'e n rfermed at the 18 month Frequency, Thrfrthe Frequency is a~cceptable fro-m -a re-li-ability REFERENCES | ||
: 1. UFSAR, Section 9.2.1.2. UFSAR, Section 5.4.7.3. CRDR 980795 PALO VERDE UNITS 1,2,3 B 3.7.8-4 REVISION - | : 1. UFSAR, Section 9.2.1.2. UFSAR, Section 5.4.7.3. CRDR 980795 PALO VERDE UNITS 1,2,3 B 3.7.8-4 REVISION - | ||
UHS B 3.7.9 BASES SURVEILLANCE REQUIREMENTS SR 3.7.9.1 This SR verifies adequate long term (26 days) cooling can be maintained with no makeup. The level specified also ensures sufficient NPSH is available for operatin th iInsert t~hetr-en"idig efth ar-am~e-t~e-r ariations during.....t I thWe Oppliai OE.Ti SR Ycrifies th-at thcesal (that -:h4c 'I n bc dcpctcd -atcr lc'.'cl of cach ESP is >12ft. A usable water depth of 12 feet requires 13'-6" of actual water depth. The implementing procedure requires the operator to verify that the level is greater than or equal to 13'-6" measured locally at the spray pond or 14'indicated in the control room using installed instrumentation. | UHS B 3.7.9 BASES SURVEILLANCE REQUIREMENTS SR 3.7.9.1 This SR verifies adequate long term (26 days) cooling can be maintained with no makeup. The level specified also ensures sufficient NPSH is available for operatin th iInsert t~hetr-en"idig efth ar-am~e-t~e-r ariations during.....t I thWe Oppliai OE.Ti SR Ycrifies th-at thcesal (that -:h4c 'I n bc dcpctcd -atcr lc'.'cl of cach ESP is >12ft. A usable water depth of 12 feet requires 13'-6" of actual water depth. The implementing procedure requires the operator to verify that the level is greater than or equal to 13'-6" measured locally at the spray pond or 14'indicated in the control room using installed instrumentation. | ||
The difference is a result of instrument uncertainty. | The difference is a result of instrument uncertainty. | ||
SR 3.7.9.2 This SR verifies that the ESPS is available to cool the EW System to at least its maximum design temperature within the maximum accident or normal design heat loads for 26 days The 24 hour Fec.ucncy is based on S...X.p. ...ie.e .rc....tcd to the trcn.di.ng of the insert p1r.ee .ariatin during the applicable MOnEs. Thi.-s SA yprzifics that. the UHS w:ater- temperatur-e is 89 0 F, asr-indcatd i th cotro rom.This Value includ-e-s allow':ance for u.-ncertai nti es.REFERENCES | SR 3.7.9.2 This SR verifies that the ESPS is available to cool the EW System to at least its maximum design temperature within the maximum accident or normal design heat loads for 26 days The 24 hour Fec.ucncy is based on S...X.p. ...ie.e .rc....tcd to the trcn.di.ng of the insert p1r.ee .ariatin during the applicable MOnEs. Thi.-s SA yprzifics that. the UHS w:ater- temperatur-e is 89 0 F, asr-indcatd i th cotro rom.This Value includ-e-s allow':ance for u.-ncertai nti es.REFERENCES | ||
: 1. UFSAR, Section 9.2.5.2. Regulatory Guide 1.27.PALO VERDE UNITS 1,2,3 B 3.7.9-3 REVISION 44 EC System B 3.7.10 BASES SURVEILLANCE SR 3.7.10.1 (continued) | : 1. UFSAR, Section 9.2.5.2. Regulatory Guide 1.27.PALO VERDE UNITS 1,2,3 B 3.7.9-3 REVISION 44 EC System B 3.7.10 BASES SURVEILLANCE SR 3.7.10.1 (continued) | ||
REQUIREMENTS The isolation of the EC System from other components or systems renders those components or systems inoperable, but does not necessarily affect the OPERABILITY of the EC System. Isolation of the EC System to any single EC supplied cooling coil, while rendering the cooling coil inoperable, is acceptable and does not impact the OPERABILITY of the EC System. Isolation of the EC System to any additional cooling coil is not acceptable without an engineering evaluation and an operability determination for that configuration (Ref. 2). The EC System is inoperable in this situation, unless it has been specifically evaluated, because it is operating outside of the acceptable limits of the system.The 31 day Frcgucnc-y is based on enginccring judgment, is con-si-stenAt with the procc~dural controls goerin4vle This SR verifies proper automatic operation of the EC System components and that the EC pumps will start in the event of any accident or transient that generates an applicable ESFAS signal. This SR also ensures that each automatic valve in the flow paths actuates to its correct position on an actual or simulated ESFAS signal.The 18 month Fre..u.ny is based on the Reed to perform this Survillncundr-the coAndition tt pply dur-ing a unit outae ad te ptenialfor -an unplanned tr-an-sient if the Sur.elln...e were performed | REQUIREMENTS The isolation of the EC System from other components or systems renders those components or systems inoperable, but does not necessarily affect the OPERABILITY of the EC System. Isolation of the EC System to any single EC supplied cooling coil, while rendering the cooling coil inoperable, is acceptable and does not impact the OPERABILITY of the EC System. Isolation of the EC System to any additional cooling coil is not acceptable without an engineering evaluation and an operability determination for that configuration (Ref. 2). The EC System is inoperable in this situation, unless it has been specifically evaluated, because it is operating outside of the acceptable limits of the system.The 31 day Frcgucnc-y is based on enginccring judgment, is con-si-stenAt with the procc~dural controls goerin4vle This SR verifies proper automatic operation of the EC System components and that the EC pumps will start in the event of any accident or transient that generates an applicable ESFAS signal. This SR also ensures that each automatic valve in the flow paths actuates to its correct position on an actual or simulated ESFAS signal.The 18 month Fre..u.ny is based on the Reed to perform this Survillncundr-the coAndition tt pply dur-ing a unit outae ad te ptenialfor -an unplanned tr-an-sient if the Sur.elln...e were performed | ||
,.th th .e.to at power. The 18 month Frqunc ibseonprang experi;enc-e and REFERENCES | ,.th th .e.to at power. The 18 month Frqunc ibseonprang experi;enc-e and REFERENCES | ||
: 1. UFSAR, Section 9.2.9.2. CRDR 980796 PALO VERDE UNITS 1,2,3 B 3.7.10-4 REVISION - | : 1. UFSAR, Section 9.2.9.2. CRDR 980796 PALO VERDE UNITS 1,2,3 B 3.7.10-4 REVISION - | ||
CREFS B 3.7.11 BASES ACTIONS E.1 and E.2 (continued) | CREFS B 3.7.11 BASES ACTIONS E.1 and E.2 (continued) | ||
| Line 1,737: | Line 1,602: | ||
Therefore, LCO 3.0.3 must be entered immediately SURVEILLANCE REQUIREMENTS SR 3.7.12.1 This SR verifies that the heat removal capability of the system is sufficient to meet design requirements. | Therefore, LCO 3.0.3 must be entered immediately SURVEILLANCE REQUIREMENTS SR 3.7.12.1 This SR verifies that the heat removal capability of the system is sufficient to meet design requirements. | ||
This SR consists of a combination of testing and calc.Latins-> | This SR consists of a combination of testing and calc.Latins-> | ||
A"-[Insert 1j ------rl --era'da-' Z o --h RDIAT"S -le. and .is t -vp-@Gtd or this time period.REFERENCES | A"-[Insert 1j ------rl --era'da-' Z o --h RDIAT"S -le. and .is t -vp-@Gtd or this time period.REFERENCES | ||
: 1. UFSAR, Section 9.4.PALO VERDE UNITS 1,2,3 B 3.7.12-4 REVISION 4 ESF PREACS B 3.7.13 BASES SURVEILLANCE SR 3.7.13.1 REQUIREMENTS Standby systems should be checked periodically to ensure that they function properly. | : 1. UFSAR, Section 9.4.PALO VERDE UNITS 1,2,3 B 3.7.12-4 REVISION 4 ESF PREACS B 3.7.13 BASES SURVEILLANCE SR 3.7.13.1 REQUIREMENTS Standby systems should be checked periodically to ensure that they function properly. | ||
Since the environment and normal operating conditions on this system are not severe, testing each train once a month provides an adequate check on this system.Monthly operations for 15 minutes demonstrates the function of the system. There is not expected to be any moisture buildup on the adsorbers and HEPA filters due to the low humidity at PVNGS (Ref The 31 dy -Frequency is trai redudn y %he andthet, SR 3.7.13.2 This SR verifies that the required ESF PREACS testing is performed in accordance with the Ventilation Filter Testing Program (VFTP). The ECCS PREACS filter tests are in accordance with Regulatory Guide 1.52 (Ref. 4). The VFTP includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations). | Since the environment and normal operating conditions on this system are not severe, testing each train once a month provides an adequate check on this system.Monthly operations for 15 minutes demonstrates the function of the system. There is not expected to be any moisture buildup on the adsorbers and HEPA filters due to the low humidity at PVNGS (Ref The 31 dy -Frequency is trai redudn y %he andthet, SR 3.7.13.2 This SR verifies that the required ESF PREACS testing is performed in accordance with the Ventilation Filter Testing Program (VFTP). The ECCS PREACS filter tests are in accordance with Regulatory Guide 1.52 (Ref. 4). The VFTP includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations). | ||
| Line 1,746: | Line 1,611: | ||
: 1. UFSAR, Section 6.5.1.2. UFSAR, Section 9.4.2.3. UFSAR, Section 15.6.5.4. Regulatory Guide 1.52 (Rev. 2).5. 10 CFR 100.11.6. NUREG-0800, Section 6.5.1, Rev. 2, July 1981.7. UFSAR, Section 1.8 PALO VERDE UNITS 1,2,3 B 3.7.13-5 REVISION 4 Fuel Storage Pool Water Level B 3.7.14 BASES SURVEILLANCE SR 3.7.14.1 REQUIREMENTS This SR verifies sufficient fuel storage pool water is available in the event of a fuel handling accident. | : 1. UFSAR, Section 6.5.1.2. UFSAR, Section 9.4.2.3. UFSAR, Section 15.6.5.4. Regulatory Guide 1.52 (Rev. 2).5. 10 CFR 100.11.6. NUREG-0800, Section 6.5.1, Rev. 2, July 1981.7. UFSAR, Section 1.8 PALO VERDE UNITS 1,2,3 B 3.7.13-5 REVISION 4 Fuel Storage Pool Water Level B 3.7.14 BASES SURVEILLANCE SR 3.7.14.1 REQUIREMENTS This SR verifies sufficient fuel storage pool water is available in the event of a fuel handling accident. | ||
The water level in the fuel storage pool must be checked periodica | The water level in the fuel storage pool must be checked periodica | ||
'The 7 day F... u.... ... -.ppep.i.t. | 'The 7 day F... u.... ... -.ppep.i.t. | ||
: b. us.acccptable, based @A eperating exer en.During refueling operations, the pool is at equilibrium with that the level in the refueling canal accordance with LCO 3.9.6, "RefuE Assemblies". | : b. us.acccptable, based @A eperating exer en.During refueling operations, the pool is at equilibrium with that the level in the refueling canal accordance with LCO 3.9.6, "RefuE Assemblies". | ||
level in the fuel storage of the refueling canal, and is checked daily inýling Water Level-Fuel REFERENCES | level in the fuel storage of the refueling canal, and is checked daily inýling Water Level-Fuel REFERENCES | ||
: 1. UFSAR, Section 9.1.2.2. UFSAR, Section 9.1.3.3. UFSAR, Section 15.7.4.4. Regulatory Guide 1.25 5. 10 FR 100.11.PALO VERDE UNITS 1,2,3 B 3.7.14-3 REVISION 24 Fuel Storage Pool Boron Concentration B 3.7.15 BASES ACTIONS A.1 and A.2 The Required Actions are modified by a Note indicating that LCO 3.0.3 does not apply.When the concentration of boron in the spent fuel pool is less than required, immediate action must be taken to preclude an accident from happening or to mitigate the consequences of an accident in progress. | : 1. UFSAR, Section 9.1.2.2. UFSAR, Section 9.1.3.3. UFSAR, Section 15.7.4.4. Regulatory Guide 1.25 5. 10 FR 100.11.PALO VERDE UNITS 1,2,3 B 3.7.14-3 REVISION 24 Fuel Storage Pool Boron Concentration B 3.7.15 BASES ACTIONS A.1 and A.2 The Required Actions are modified by a Note indicating that LCO 3.0.3 does not apply.When the concentration of boron in the spent fuel pool is less than required, immediate action must be taken to preclude an accident from happening or to mitigate the consequences of an accident in progress. | ||
This is most efficiently achieved by immediately suspending the movement of fuel assemblies. | This is most efficiently achieved by immediately suspending the movement of fuel assemblies. | ||
This does not preclude the movement of fuel assemblies to a safe position. | This does not preclude the movement of fuel assemblies to a safe position. | ||
In addition, action must be immediately initiated to restore boron concentration to within limit.If moving fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not specify any action. If moving fuel assemblies while in MODE 1, 2, 3, or 4, the fuel movement is independent of reactor operation. | In addition, action must be immediately initiated to restore boron concentration to within limit.If moving fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not specify any action. If moving fuel assemblies while in MODE 1, 2, 3, or 4, the fuel movement is independent of reactor operation. | ||
Therefore, inability to suspend movement of fuel assemblies is not sufficient reason to require a reactor shutdown.SURVEILLANCE REQUIREMENTS SR 3.7.15.1 This SR verifies that the concentration of boron in the spent fuel pool is within the required limit. As long as this SR is met, the analyzed incidents are full, a insert .A wat-r- i1- ..t.d to take plac, ever a ho pf time REFERENCES | Therefore, inability to suspend movement of fuel assemblies is not sufficient reason to require a reactor shutdown.SURVEILLANCE REQUIREMENTS SR 3.7.15.1 This SR verifies that the concentration of boron in the spent fuel pool is within the required limit. As long as this SR is met, the analyzed incidents are full, a insert .A wat-r- i1- ..t.d to take plac, ever a ho pf time REFERENCES | ||
: 1. UFSAR, Section 9.1.2.2. PVNGS Operating License Amendments 82, 69 and 54 for Units 1, 2 and 3, respectively, and associated NRC Safety Evaluation dated September 30, 1994.3. 13-N-001-1900-1221-1, "Palo Verde Spent Fuel Pool Criticality Analysis," ABB calculation A-PV-FE-0106, revision 3, dated January 15, 1999.PALO VERDE UNITS 1,2,3 B 3.7.15-2 REVISION Secondary Speci fi c Acti vi ty B 3.7.16 BASES APPLICABILITY In MODES 1, 2, 3, and 4, the limits on secondary specific activity apply due to the potential for secondary steam releases to the atmosphere. | : 1. UFSAR, Section 9.1.2.2. PVNGS Operating License Amendments 82, 69 and 54 for Units 1, 2 and 3, respectively, and associated NRC Safety Evaluation dated September 30, 1994.3. 13-N-001-1900-1221-1, "Palo Verde Spent Fuel Pool Criticality Analysis," ABB calculation A-PV-FE-0106, revision 3, dated January 15, 1999.PALO VERDE UNITS 1,2,3 B 3.7.15-2 REVISION Secondary Speci fi c Acti vi ty B 3.7.16 BASES APPLICABILITY In MODES 1, 2, 3, and 4, the limits on secondary specific activity apply due to the potential for secondary steam releases to the atmosphere. | ||
In MODES 5 and 6, the steam generators are not being used for heat removal. Both the RCS and steam generators are depressurized, and primary to secondary LEAKAGE is minimal.Therefore, monitoring of secondary specific activity is not required.ACTIONS A.1 and A.2 DOSE EQUIVALENT 1-131 exceeding the allowable value in the secondary coolant, is an indication of a problem in the RCS, and contributes to increased post accident doses. If secondary specific activity cannot be restored to within limits in the associated Completion Time, 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 6 hours, and in MODE 5 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 REQUIREMENTS SR 3.7.16.1 This SR ensures that the secondary specific activity is within the limits of the accident analysis. | In MODES 5 and 6, the steam generators are not being used for heat removal. Both the RCS and steam generators are depressurized, and primary to secondary LEAKAGE is minimal.Therefore, monitoring of secondary specific activity is not required.ACTIONS A.1 and A.2 DOSE EQUIVALENT 1-131 exceeding the allowable value in the secondary coolant, is an indication of a problem in the RCS, and contributes to increased post accident doses. If secondary specific activity cannot be restored to within limits in the associated Completion Time, 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 6 hours, and in MODE 5 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 REQUIREMENTS SR 3.7.16.1 This SR ensures that the secondary specific activity is within the limits of the accident analysis. | ||
| Line 1,936: | Line 1,801: | ||
The verification of proper voltage and frequency output ensures that the required power is readily available for the instrumentation of the RPS and ESFAS connected to the AC vital instrument bus h a rqec ae" "ý The 7 d, Pegunne-y tae iInsert 1 lether- ind-iAtins, -;w-il -bhle i n the r-ent-re!- | The verification of proper voltage and frequency output ensures that the required power is readily available for the instrumentation of the RPS and ESFAS connected to the AC vital instrument bus h a rqec ae" "ý The 7 d, Pegunne-y tae iInsert 1 lether- ind-iAtins, -;w-il -bhle i n the r-ent-re!- | ||
teAem that aler-t the opcr-ator to inverter malfnctions. | teAem that aler-t the opcr-ator to inverter malfnctions. | ||
REFERENCES | REFERENCES | ||
: 1. UFSAR, Chapter 8.2. UFSAR, Chapter 6.3. UFSAR, Chapter 15.PALO VERDE UNITS 1,2,3 B 3.8.7-5 REVISION & | : 1. UFSAR, Chapter 8.2. UFSAR, Chapter 6.3. UFSAR, Chapter 15.PALO VERDE UNITS 1,2,3 B 3.8.7-5 REVISION & | ||
Inverters | Inverters | ||
| Line 1,949: | Line 1,814: | ||
The verification of proper voltage and frequency output ensures that the required power is readily available for the instrumentation connected to the AC vital instrument b~use The 7 day Frequency takes into account the rcndtundn insert ijj __(conti nued)PALO VERDE UNITS 1,2,3 B 3.8.8-4 REVISION 2 Inverters | The verification of proper voltage and frequency output ensures that the required power is readily available for the instrumentation connected to the AC vital instrument b~use The 7 day Frequency takes into account the rcndtundn insert ijj __(conti nued)PALO VERDE UNITS 1,2,3 B 3.8.8-4 REVISION 2 Inverters | ||
-Shutdown B 3.8.8 BASES SURVEILLANCE SR 3.8.8.1 (continued) | -Shutdown B 3.8.8 BASES SURVEILLANCE SR 3.8.8.1 (continued) | ||
REQUIREMENTS capability of the in~'crters And other indicm~Atin av:ailable iln the control room that alertthe operator to in"erter REFERENCES | REQUIREMENTS capability of the in~'crters And other indicm~Atin av:ailable iln the control room that alertthe operator to in"erter REFERENCES | ||
: 1. UFSAR, Chapter 6.2. UFSAR, Chapter 15.PALO VERDE UNITS 1,2,3 B 3.8.8-5 REVISIONI Distribution Systems -Operating B 3.8.9 BASES SURVEILLANCE SR 3.8.9.1 REQU I REMENTS This Surveillance verifies that the AC, DC, and AC vital instrument bus electrical power distribution systems are functioning properly, with the required circuit breakers closed and the buses energized. | : 1. UFSAR, Chapter 6.2. UFSAR, Chapter 15.PALO VERDE UNITS 1,2,3 B 3.8.8-5 REVISIONI Distribution Systems -Operating B 3.8.9 BASES SURVEILLANCE SR 3.8.9.1 REQU I REMENTS This Surveillance verifies that the AC, DC, and AC vital instrument bus electrical power distribution systems are functioning properly, with the required circuit breakers closed and the buses energized. | ||
The correct breaker alignment ensures the appropriate separation and independence of the electrical divisions is maintained, and the appropriate voltage is available to each required bus.The verification of proper voltage availability on the buses ensures that the required voltage is readily available for motive as well as control functions for critical system loads connected to ther The 7 day Frequent y trkes room thataerthoprtrt uytemafnin. | The correct breaker alignment ensures the appropriate separation and independence of the electrical divisions is maintained, and the appropriate voltage is available to each required bus.The verification of proper voltage availability on the buses ensures that the required voltage is readily available for motive as well as control functions for critical system loads connected to ther The 7 day Frequent y trkes room thataerthoprtrt uytemafnin. | ||
REFERENCES | REFERENCES | ||
: 1. UFSAR, Chapter 6.2. UFSAR, Chapter 15.3. Regulatory Guide 1.93, Revision 0, December 1974.PALO VERDE UNITS 1,2,3 B 3.8.9-10 REVISION 4 Distribution Systems -Shutdown B 3.8.10 BASES (continued) | : 1. UFSAR, Chapter 6.2. UFSAR, Chapter 15.3. Regulatory Guide 1.93, Revision 0, December 1974.PALO VERDE UNITS 1,2,3 B 3.8.9-10 REVISION 4 Distribution Systems -Shutdown B 3.8.10 BASES (continued) | ||
ACTIONS (continued) | ACTIONS (continued) | ||
| Line 1,958: | Line 1,823: | ||
In this case, Required Actions A.2.1 through A.2.4 do not adequately address the concerns relating to coolant circulation and heat removal. Pursuant to LCO 3.0.6, the SDC ACTIONS would not be entered.Therefore, Required Action A.2.5 is provided to direct declaring SDC inoperable, which results in taking the appropriate SDC actions.The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. | In this case, Required Actions A.2.1 through A.2.4 do not adequately address the concerns relating to coolant circulation and heat removal. Pursuant to LCO 3.0.6, the SDC ACTIONS would not be entered.Therefore, Required Action A.2.5 is provided to direct declaring SDC inoperable, which results in taking the appropriate 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 unit safety systems may be without power.SURVEILLANCE SR 3.8.10.1 REQUIREMENTS This Surveillance verifies that the AC, DC, and AC vital instrument bus electrical power distribution system is functioning properly, with all the required buses energized. | The restoration of the required distribution subsystems should be completed as quickly as possible in order to minimize the time the unit safety systems may be without power.SURVEILLANCE SR 3.8.10.1 REQUIREMENTS This Surveillance verifies that the AC, DC, and AC vital instrument bus electrical power distribution system is functioning properly, with all the required buses energized. | ||
The verification of proper voltage availability on the buses ensures that the required power is readily available for motive as well as control functions for critical system loads connec~ted to these The 7 day Frequency t-ake-s x.aiw b in the onmtrol room that alcrt the operator to REFERENCES | The verification of proper voltage availability on the buses ensures that the required power is readily available for motive as well as control functions for critical system loads connec~ted to these The 7 day Frequency t-ake-s x.aiw b in the onmtrol room that alcrt the operator to REFERENCES | ||
: 1. UFSAR, Chapter 6.2. UFSAR, Chapter 15.PALO VERDE UNITS 1,2,3 B 3.8.10-4 REVISION G Boron Concentration B 3.9.1 BASES ACTIONS A.3 (continued) | : 1. UFSAR, Chapter 6.2. UFSAR, Chapter 15.PALO VERDE UNITS 1,2,3 B 3.8.10-4 REVISION G Boron Concentration B 3.9.1 BASES ACTIONS A.3 (continued) | ||
In determining the required combination of boration flow rate and concentration, there is no unique design basis event that must be satisfied. | In determining the required combination of boration flow rate and concentration, there is no unique design basis event that must be satisfied. | ||
| Line 1,964: | Line 1,829: | ||
Once boration is initiated, it must be continued until the boron concentration is restored. | Once boration is initiated, it must be continued until the boron concentration is restored. | ||
The restoration time depends on the amount of boron that must be injected to reach the required concentration. | The restoration time depends on the amount of boron that must be injected to reach the required concentration. | ||
SURVEILLANCE SR 3.9.1.1 REQUIREMENTS This SR ensures the coolant boron concentration in the RCS and the refueling canal is within the COLR limits. The boron concentration of the coolant in each volume is determined periodically by chemical analysis.A uf onne every 72 ho.....is therefore a rcsnbcamount of tiPt)vrf the boronn rconcentratioAn of r-epresent-ative Samples. The Fr-equencGy is based on oErtn Kexprience, whic-h h-as shown 72 ousto be REFERENCES | SURVEILLANCE SR 3.9.1.1 REQUIREMENTS This SR ensures the coolant boron concentration in the RCS and the refueling canal is within the COLR limits. The boron concentration of the coolant in each volume is determined periodically by chemical analysis.A uf onne every 72 ho.....is therefore a rcsnbcamount of tiPt)vrf the boronn rconcentratioAn of r-epresent-ative Samples. The Fr-equencGy is based on oErtn Kexprience, whic-h h-as shown 72 ousto be REFERENCES | ||
: 1. 10 CFR 50, Appendix A, GDC 26.2. UFSAR, Section 9.1.2.PALO VERDE UNITS 1,2,3 B 3.9.1-4 REVISION 4 Nuclear Instrumentation B 3.9.2 BASES ACTIONS B.1 (continued) | : 1. 10 CFR 50, Appendix A, GDC 26.2. UFSAR, Section 9.1.2.PALO VERDE UNITS 1,2,3 B 3.9.1-4 REVISION 4 Nuclear Instrumentation B 3.9.2 BASES ACTIONS B.1 (continued) | ||
With no SRM OPERABLE, action to restore a monitor to OPERABLE status shall be initiated immediately. | With no SRM OPERABLE, action to restore a monitor to OPERABLE status shall be initiated immediately. | ||
| Line 1,981: | Line 1,846: | ||
This SR is an extension of SR 3.3.12 for the Boron Dilution Alarm System CHANNEL CALIBRATION listed here because of its Applicability in t The 18 month P.equency is component dsaily pass the Sur-wcillancc when perfor-med on the 18 month F.equency.. | This SR is an extension of SR 3.3.12 for the Boron Dilution Alarm System CHANNEL CALIBRATION listed here because of its Applicability in t The 18 month P.equency is component dsaily pass the Sur-wcillancc when perfor-med on the 18 month F.equency.. | ||
The CHANNEL CALIBRATION is normally performed during a plant outage, but can be performed with the reactor at power if detector curve determination is not performed. | The CHANNEL CALIBRATION is normally performed during a plant outage, but can be performed with the reactor at power if detector curve determination is not performed. | ||
Detector curve determination can only be performed under conditions that apply during a plant outage since the flux level needs to be at shutdown levels for detector energi zati on.REFERENCES | Detector curve determination can only be performed under conditions that apply during a plant outage since the flux level needs to be at shutdown levels for detector energi zati on.REFERENCES | ||
: 1. 10 CFR 50, Appendix A, GDC 13, GDC 26, GDC 28, and GDC 29.2. UFSAR, Section 15.4.6.PALO VERDE UNITS 1,2,3 B 3.9.2-4 REVISION 44 Containment Penetrations B 3.9.3 BASES ACTIONS A.1 and A.2 (continued) valves are open, the unit must be placed in a condition in which the isolation function is not needed. This is accomplished by immediately suspending CORE ALTERATIONS and movement of irradiated fuel assemblies within containment. | : 1. 10 CFR 50, Appendix A, GDC 13, GDC 26, GDC 28, and GDC 29.2. UFSAR, Section 15.4.6.PALO VERDE UNITS 1,2,3 B 3.9.2-4 REVISION 44 Containment Penetrations B 3.9.3 BASES ACTIONS A.1 and A.2 (continued) valves are open, the unit must be placed in a condition in which the isolation function is not needed. This is accomplished by immediately suspending CORE ALTERATIONS and movement of irradiated fuel assemblies within containment. | ||
Performance of these actions shall not preclude completion of movement of a component to a safe position.SURVEILLANCE REQUIREMENTS SR 3.9.3.1 This Surveillance demonstrates that each of the containment penetrations required to be in its closed position is in that position. | Performance of these actions shall not preclude completion of movement of a component to a safe position.SURVEILLANCE REQUIREMENTS SR 3.9.3.1 This Surveillance demonstrates that each of the containment penetrations required to be in its closed position is in that position. | ||
| Line 1,990: | Line 1,855: | ||
Po..gam requwiements. | Po..gam requwiements. | ||
These surveillances performed during MODE 6 will ensure that the valves are capable of closing after a postulated fuel handling accident to limit a release of fission product radioactivity from the containment. | These surveillances performed during MODE 6 will ensure that the valves are capable of closing after a postulated fuel handling accident to limit a release of fission product radioactivity from the containment. | ||
SR 3.9.3.3 This Surveillance demonstrates that the necessary hardware, tools, equipment and personnel are available to close the equipment hatch and that the equipment hatch is clear of obstructions that would impede its CIO The 7-day Frequency is coAmmensur-ate with the Insert 1 T ... 1 .. .,, ....,,, ÷0 b met forp an open equipment hth ftehthi cAsed, the czapabi 1i ty to ls the hac i.o REFERENCES | SR 3.9.3.3 This Surveillance demonstrates that the necessary hardware, tools, equipment and personnel are available to close the equipment hatch and that the equipment hatch is clear of obstructions that would impede its CIO The 7-day Frequency is coAmmensur-ate with the Insert 1 T ... 1 .. .,, ....,,, ÷0 b met forp an open equipment hth ftehthi cAsed, the czapabi 1i ty to ls the hac i.o REFERENCES | ||
: 1. GPU Nuclear Safety Evaluation SE-0002000-O01, Rev. 0, May 20, 1988.2. UFSAR, Section 15.7.4.3. NUREG-0800, Section 15.7.4, Rev. 1, July 1981.PALO VERDE UNITS 1,2,3 B 3.9.3-6 REVISION 4-9 SDC and Coolant Circulation | : 1. GPU Nuclear Safety Evaluation SE-0002000-O01, Rev. 0, May 20, 1988.2. UFSAR, Section 15.7.4.3. NUREG-0800, Section 15.7.4, Rev. 1, July 1981.PALO VERDE UNITS 1,2,3 B 3.9.3-6 REVISION 4-9 SDC and Coolant Circulation | ||
-High Water Level B 3.9.4 BASES ACTIONS A.4 (continued) | -High Water Level B 3.9.4 BASES ACTIONS A.4 (continued) | ||
If SDC loop requirements are not met, all containment penetrations to the outside atmosphere must be closed to prevent fission products, if released by a loss of decay heat event, from escaping the containment building. | If SDC loop requirements are not met, all containment penetrations to the outside atmosphere must be closed to prevent fission products, if released by a loss of decay heat event, from escaping the containment building. | ||
The 4 hour Completion Time allows fixing most SDC problems without incurring the additional action of violating the containment atmosphere. | The 4 hour Completion Time allows fixing most SDC problems without incurring the additional action of violating the containment atmosphere. | ||
SURVEILLANCE REQUIREMENTS SR 3.9.4.1 This Surveillance demonstrates that the SDC loop is in operation and circulating reactor coolant at a flowrate of greater than or equal to 3780 gpm. The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability and to prevent thermal and boron stratification in the The of 12 hourS inoernEtro, and alarm indications available to thc operator in thc contro roo-tm for monitor-ing the SOC System.REFERENCES | SURVEILLANCE REQUIREMENTS SR 3.9.4.1 This Surveillance demonstrates that the SDC loop is in operation and circulating reactor coolant at a flowrate of greater than or equal to 3780 gpm. The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability and to prevent thermal and boron stratification in the The of 12 hourS inoernEtro, and alarm indications available to thc operator in thc contro roo-tm for monitor-ing the SOC System.REFERENCES | ||
: 1. UPSAR, Section 5.4.7.PALO VERDE UNITS 1.2,3 B 3.9.4-4 REVISION 0 SDC and Coolant Circulation | : 1. UPSAR, Section 5.4.7.PALO VERDE UNITS 1.2,3 B 3.9.4-4 REVISION 0 SDC and Coolant Circulation | ||
-Low Water Level B 3.9.5 BASES ACTIONS B.3 (Continued) | -Low Water Level B 3.9.5 BASES ACTIONS B.3 (Continued) | ||
| Line 2,007: | Line 1,872: | ||
REFERENCES | REFERENCES | ||
: 1. UFSAR, Section 5.4.7.PALO VERDE UNITS 1,2,3 B 3.9.5-5 REVISION Refueling Water Level-Fuel Assemblies B 3.9.6 BASES SURVEILLANCE REQUIREMENTS SR 3.9.6.1 (continued) | : 1. UFSAR, Section 5.4.7.PALO VERDE UNITS 1,2,3 B 3.9.5-5 REVISION Refueling Water Level-Fuel Assemblies B 3.9.6 BASES SURVEILLANCE REQUIREMENTS SR 3.9.6.1 (continued) | ||
The Frequency of 21 hourps i~s bhased on cnieR ering judgment and is considcrcd adeut in iew o~f the large volume of~atcrand hc nrmalprocdural controls of valve positions, andHYA opratonswhih mkesignificant unplanned level REFERENCES | The Frequency of 21 hourps i~s bhased on cnieR ering judgment and is considcrcd adeut in iew o~f the large volume of~atcrand hc nrmalprocdural controls of valve positions, andHYA opratonswhih mkesignificant unplanned level REFERENCES | ||
: 1. Regulatory Guide 1.25, March 23, 1972.2. UFSAR, Section 15.7.4.3. NUREG-OBDO, Section 15.7.4.4. 10 CFR 100.10.PALO VERDE UNITS 1,2,3 B 3.9.6-3 REVISION 0 Refueling Water Level-CEAs B 3.9.7 BASES SURVEILLANCE REQUIREMENTS SR 3.9.7.1 Verification of a minimum water level of 23 ft above the top of irradiated fuel assemblies seated within the reactor vessel ensures that the design basis for the postulated fuel handling accident analysis during refueling operations is met. Water at the required level above the top of the irradiated fuel limits the consequences of damaged fuel rods that are postulated to result from a fuel handling accident inside containment (Ref. 2).The Frequenc-y of 24 and ig considered a Innsert peaton houwrg ig based on engiccin Judgment dequatc in view of the large volume of*1 ,.hi-h makc si.-gifici;nt unplanned level REFERENCES | : 1. Regulatory Guide 1.25, March 23, 1972.2. UFSAR, Section 15.7.4.3. NUREG-OBDO, Section 15.7.4.4. 10 CFR 100.10.PALO VERDE UNITS 1,2,3 B 3.9.6-3 REVISION 0 Refueling Water Level-CEAs B 3.9.7 BASES SURVEILLANCE REQUIREMENTS SR 3.9.7.1 Verification of a minimum water level of 23 ft above the top of irradiated fuel assemblies seated within the reactor vessel ensures that the design basis for the postulated fuel handling accident analysis during refueling operations is met. Water at the required level above the top of the irradiated fuel limits the consequences of damaged fuel rods that are postulated to result from a fuel handling accident inside containment (Ref. 2).The Frequenc-y of 24 and ig considered a Innsert peaton houwrg ig based on engiccin Judgment dequatc in view of the large volume of*1 ,.hi-h makc si.-gifici;nt unplanned level REFERENCES | ||
: 1. Regulatory Guide 1.25, March 23, 1972.2. UFSAR, Section 15.7.4.3. NUREG-0800, Section 15.7.4.4. 10 CFR 100.10.PALO VERDE UNITS 1,2,3 B 3.9.7-3 REVISION 0 Insert 1 The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.Insert Attachment 6 Proposed No Significant Hazards Consideration | : 1. Regulatory Guide 1.25, March 23, 1972.2. UFSAR, Section 15.7.4.3. NUREG-0800, Section 15.7.4.4. 10 CFR 100.10.PALO VERDE UNITS 1,2,3 B 3.9.7-3 REVISION 0 Insert 1 The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.Insert Attachment 6 Proposed No Significant Hazards Consideration | ||
| Line 2,018: | Line 1,883: | ||
OF AMENDMENT REQUEST The proposed change requests the adoption of an approved change to the standard technical specifications (STS) for Combustion Engineering Plants (NUREG-1432), to allow relocation of specific technical specification surveillance frequencies to a licensee-controlled program. The proposed change is described in Technical Specification Task Force (TSTF) Traveler 425, Revision 3 (ADAMS Accession No. ML090850642) related to the Relocation of Surveillance Frequencies to Licensee Control -RITSTF Initiative 5b and was described in the Notice of Availability published in the Federal Register on July 6, 2009 (74 FR 31996).The proposed changes are consistent with NRC-approved Industry/Technical Specification Task Force (TSTF) Traveler 425, Rev. 3, "Relocate Surveillance Frequencies to Licensee Control -RITSTF Initiative 5b." The proposed change relocates surveillance frequencies to a licensee-controlled program, the Surveillance Frequency Control Program (SFCP). This change is applicable to licensees using probabilistic risk guidelines contained in NRC-approved NEI 04-10, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies," (ADAMS Accession No. 071360456). | OF AMENDMENT REQUEST The proposed change requests the adoption of an approved change to the standard technical specifications (STS) for Combustion Engineering Plants (NUREG-1432), to allow relocation of specific technical specification surveillance frequencies to a licensee-controlled program. The proposed change is described in Technical Specification Task Force (TSTF) Traveler 425, Revision 3 (ADAMS Accession No. ML090850642) related to the Relocation of Surveillance Frequencies to Licensee Control -RITSTF Initiative 5b and was described in the Notice of Availability published in the Federal Register on July 6, 2009 (74 FR 31996).The proposed changes are consistent with NRC-approved Industry/Technical Specification Task Force (TSTF) Traveler 425, Rev. 3, "Relocate Surveillance Frequencies to Licensee Control -RITSTF Initiative 5b." The proposed change relocates surveillance frequencies to a licensee-controlled program, the Surveillance Frequency Control Program (SFCP). This change is applicable to licensees using probabilistic risk guidelines contained in NRC-approved NEI 04-10, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies," (ADAMS Accession No. 071360456). | ||
2.0 BASIS FOR PROPOSED NO SIGNIFICANT HAZARDS CONSIDERATION As required by 10 CFR 50.91 (a), the Arizona Public Service (APS) Company 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? | |||
FOR PROPOSED NO SIGNIFICANT HAZARDS CONSIDERATION As required by 10 CFR 50.91 (a), the Arizona Public Service (APS) Company 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: | 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. | 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. | ||
| Line 2,044: | Line 1,907: | ||
-Shutdown 3.3.2.1 1 3.3.2.1 Channel Check 1 3.3.2.2 1 3.3.2.2 Channel Functional Test 1 3.3.2.3 N/A 3.3.2.3 Channel Functional Test N/A 3.3.2.4 1 3.3.2.4 Channel Calibration 1 3.3.2.5 1 3.3.2.5 Verify response time within limits 1 3.3.3 Control Element Assembly Calculators 3.3.3.1 1 3.3.3.1 Channel Check 1 3.3.3.2 1 X 3.3.3.2 (Deleted) | -Shutdown 3.3.2.1 1 3.3.2.1 Channel Check 1 3.3.2.2 1 3.3.2.2 Channel Functional Test 1 3.3.2.3 N/A 3.3.2.3 Channel Functional Test N/A 3.3.2.4 1 3.3.2.4 Channel Calibration 1 3.3.2.5 1 3.3.2.5 Verify response time within limits 1 3.3.3 Control Element Assembly Calculators 3.3.3.1 1 3.3.3.1 Channel Check 1 3.3.3.2 1 X 3.3.3.2 (Deleted) | ||
---3.3.3.3 1 3.3.3.3 Channel Functional Test 1 3.3.3.4 1 3.3.3.4 Channel Calibration 1 3.3.3.5 1 3.3.3.5 Channel Functional Test 1 3.3.3.6 1 X 3.3.4 Reactor Protective System Logic and Trip Initiation 3.3.4.2 1 3.3.4.1 Channel Functional Test 1 3.3.4.3 1 3.3.4.2 Channel Functional Test 1 3.3.4.1 1 3.3.4.3 Channel Functional Test 1 3.3.4.4 N/A X --- | ---3.3.3.3 1 3.3.3.3 Channel Functional Test 1 3.3.3.4 1 3.3.3.4 Channel Calibration 1 3.3.3.5 1 3.3.3.5 Channel Functional Test 1 3.3.3.6 1 X 3.3.4 Reactor Protective System Logic and Trip Initiation 3.3.4.2 1 3.3.4.1 Channel Functional Test 1 3.3.4.3 1 3.3.4.2 Channel Functional Test 1 3.3.4.1 1 3.3.4.3 Channel Functional Test 1 3.3.4.4 N/A X --- | ||
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 5 S......, 4tr!e6 OndIng Palo Verde TS 8urve!loance Roqujr'monts | Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 5 S......, 4tr!e6 OndIng Palo Verde TS 8urve!loance Roqujr'monts | ||
()',, -.3.3.5 Engineered Safety Features Actuation System Instrumentation 3.3.5.1 1 3.3.5.1 Channel Check 1 3.3.5.2 1 3.3.5.2 Channel Functional Test 1 3.3.5.3 1 3.3.5.3 Channel Calibration 1 3.3.5.4 1 3.3.5.4 Verify response time within limits 1 3.3.5.5 N/A 3.3.5.5 Channel Functional Test N/A 3.3.6 Engineered Safety Features Actuation System Logic and Manual Trip 3.3.6.1 1 3.3.6.1 Channel Functional Test 1 3.3.6.2 1 3.3.6.2 Perform subgroup relay test 1 X 3.3.6.3 1 X ---3.3.7 Diesel Generator | ()',, -.3.3.5 Engineered Safety Features Actuation System Instrumentation 3.3.5.1 1 3.3.5.1 Channel Check 1 3.3.5.2 1 3.3.5.2 Channel Functional Test 1 3.3.5.3 1 3.3.5.3 Channel Calibration 1 3.3.5.4 1 3.3.5.4 Verify response time within limits 1 3.3.5.5 N/A 3.3.5.5 Channel Functional Test N/A 3.3.6 Engineered Safety Features Actuation System Logic and Manual Trip 3.3.6.1 1 3.3.6.1 Channel Functional Test 1 3.3.6.2 1 3.3.6.2 Perform subgroup relay test 1 X 3.3.6.3 1 X ---3.3.7 Diesel Generator | ||
-Loss of Voltage Start 3.3.7.1 1 3.3.7.1 Channel Check 1 3.3.7.2 1 3.3.7.2 Channel Functional Test 1 3.3.7.3 1 3.3.7.3 Channel Calibration 1 3.3.8 Containment Purge Isolation Actuation Signal 3.3.8.1 1 3.3.8.1 Channel Check 1 3.3.8.2 1 X ---3.3.8.3 1 3.3.8.2 Channel Functional Test 1 3.3.8.4 1 X ---3.3.8.5 1 3.3.8.3 Channel Functional Test 1 3.3.8.6 1 3.3.8.4 Channel Calibration 1 3.3.8.7 1 X --- | -Loss of Voltage Start 3.3.7.1 1 3.3.7.1 Channel Check 1 3.3.7.2 1 3.3.7.2 Channel Functional Test 1 3.3.7.3 1 3.3.7.3 Channel Calibration 1 3.3.8 Containment Purge Isolation Actuation Signal 3.3.8.1 1 3.3.8.1 Channel Check 1 3.3.8.2 1 X ---3.3.8.3 1 3.3.8.2 Channel Functional Test 1 3.3.8.4 1 X ---3.3.8.5 1 3.3.8.3 Channel Functional Test 1 3.3.8.6 1 3.3.8.4 Channel Calibration 1 3.3.8.7 1 X --- | ||
| Line 2,050: | Line 1,913: | ||
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 8 j.Palo V'rde TS Survell"ance R q .r.e.tsO(N) | Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 8 j.Palo V'rde TS Survell"ance R q .r.e.tsO(N) | ||
)3.4.7.2 1 3.4.7.2 Verify secondary side water level 1 __3.4.7.3 1 3.4.7.3 Verify breaker alignment and power available I _____________3.4.8 RCS Loops -Mode 5, Loops Not Filled 3.4.8.1 1 3.4.8.1 Verify SDC train in operation1 3.4.8.2 1 3.4.8.2 Verify breaker alignment and power available I___________3.4.9 Pressurizer 3.4.9.1 1 3.4.9.1 Verify water level 1 __3.4.9.2 1 3.4.9.2 Verify heater capacity 1 3.4.9.3 1 X--____ 3.4.10 Pressurizer Safety Valves -Modes 1, 2 and 3 Not in TSTF ___ 3.4.10.1 Verify safety valve Operable N/A____ 3.4.11 Pressurizer Safety Valves -Mode 4 Not in TSTF __ 3.4.11.1 Verify safety valve Operable N/A Not in TSTF __ 3.4.11.2 Verify SDC relief valve aligned 1 X Not in TSTF ___ 3.4.11.3 Verify SDC relief valve Operable N/A ___ 3.4.12 Pressurizer Vents Not in TSTF __ 3.4.12.1 Cycle Pressurizer Vent Valve 1 X Not in TSTF 3.4.12.2 Verify flow through pressurizer vent path 1 X 13 Low Temperature Overpressure Protection System 3.4.12.1 1 X I--- | )3.4.7.2 1 3.4.7.2 Verify secondary side water level 1 __3.4.7.3 1 3.4.7.3 Verify breaker alignment and power available I _____________3.4.8 RCS Loops -Mode 5, Loops Not Filled 3.4.8.1 1 3.4.8.1 Verify SDC train in operation1 3.4.8.2 1 3.4.8.2 Verify breaker alignment and power available I___________3.4.9 Pressurizer 3.4.9.1 1 3.4.9.1 Verify water level 1 __3.4.9.2 1 3.4.9.2 Verify heater capacity 1 3.4.9.3 1 X--____ 3.4.10 Pressurizer Safety Valves -Modes 1, 2 and 3 Not in TSTF ___ 3.4.10.1 Verify safety valve Operable N/A____ 3.4.11 Pressurizer Safety Valves -Mode 4 Not in TSTF __ 3.4.11.1 Verify safety valve Operable N/A Not in TSTF __ 3.4.11.2 Verify SDC relief valve aligned 1 X Not in TSTF ___ 3.4.11.3 Verify SDC relief valve Operable N/A ___ 3.4.12 Pressurizer Vents Not in TSTF __ 3.4.12.1 Cycle Pressurizer Vent Valve 1 X Not in TSTF 3.4.12.2 Verify flow through pressurizer vent path 1 X 13 Low Temperature Overpressure Protection System 3.4.12.1 1 X I--- | ||
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 9.r* bt , i Irl, 1ar Cprroponding Palo Verde TS Surveillano Requirement. | Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 9.r* bt , i Irl, 1ar Cprroponding Palo Verde TS Surveillano Requirement. | ||
($1)4 3.4.12.2 1 X 3.4.12.3 1 X ---3.4.12.4 1 3.4.13.1 Verify RCS vent open 1 Not in TSTF 3.4.13.2 Verify SDC relief valve aligned 1 X Not in TSTF 3.4.13.3 Verify SDC relief valve Operable NIA 3.4.12.5 1 X 3.4.12.6 1 X 3.4.12.7 1 X 3.4.14 RCS Operational Leakage 3.4.13.1 1 3.4.14.1 Perform RCS water inventory balance 1 3.4.13.2 1 3.4.14.2 Verify primary to secondary leakage 1 3.4.15 RCS Pressure Isolation Valve (PIV) Leakage 3.4.14.1 1 3.4.15.1 Verify leakage from PIV 1 3.4.14.2 1 3.4.15.2 Verify SDC interlock 1 3.4.14.3 1 X ---3.4.16 RCS Leakage Detection Instrumentation 3.4.15.1 1 3.4.16.1 Channel Check 1 3.4.15.2 1 3.4.16.2 Channel Functional Test 1 3.4.15.3 1 3.4.16.3 Channel Calibration 1 3.4.15.4 1 3.4.16.4 Channel Calibration 1 3.4.15.5 1 X___________ | ($1)4 3.4.12.2 1 X 3.4.12.3 1 X ---3.4.12.4 1 3.4.13.1 Verify RCS vent open 1 Not in TSTF 3.4.13.2 Verify SDC relief valve aligned 1 X Not in TSTF 3.4.13.3 Verify SDC relief valve Operable NIA 3.4.12.5 1 X 3.4.12.6 1 X 3.4.12.7 1 X 3.4.14 RCS Operational Leakage 3.4.13.1 1 3.4.14.1 Perform RCS water inventory balance 1 3.4.13.2 1 3.4.14.2 Verify primary to secondary leakage 1 3.4.15 RCS Pressure Isolation Valve (PIV) Leakage 3.4.14.1 1 3.4.15.1 Verify leakage from PIV 1 3.4.14.2 1 3.4.15.2 Verify SDC interlock 1 3.4.14.3 1 X ---3.4.16 RCS Leakage Detection Instrumentation 3.4.15.1 1 3.4.16.1 Channel Check 1 3.4.15.2 1 3.4.16.2 Channel Functional Test 1 3.4.15.3 1 3.4.16.3 Channel Calibration 1 3.4.15.4 1 3.4.16.4 Channel Calibration 1 3.4.15.5 1 X___________ | ||
___ ___3.4.17 RCS Specific Activity __ | ___ ___3.4.17 RCS Specific Activity __ | ||
| Line 2,056: | Line 1,919: | ||
'3.4.16.1 1 3.4.17.1 Verify gross specific activity 3.4.16.2 1 3.4.17.2 Verify Dose Equivalent 1-131 1 3.4.16.3 1 3.4.17.3 Determine E-BAR 1 3.4.18 Steam Generator Tube Integrit Not in TSTF 3.4.18.1 Verif tube integrity N/A Not in TSTF 3.4.18.2 Verif tubes plugged N/A 3.5.1 Safet Injection Tanks -0perating 3.5.1.1 SITs 1 3.5.1.1 Verif valve open 1 3.5.1.2 SITs 1 3.5.1.2 Verif borated water volume 1 3.5.1.3 SITs 1 3.5.1.3 Verif nitrogen cover pressure 1 3.5.1.4 SITs 1 3.5.1.4 Verif boron concentration 1 3.5.1.5 SITs 1 3.5.1.5 Verif power removed from valve operator 1 3.5.2 Safet Injection Tanks -Shutdown Not in TSTF 3.5.2.1 Verif valve open 1 X Not in TSTF 3.5.2.2 Verif borated water volume 1 X Not in TSTF 3.5.2.3 Verif nitrogen cover pressure 1 X Not in TSTF 3.5.2.4 Verif boron concentration 1 X Not in TSTF 3.5.2.5 Verif power removed from valve operator 1 X 3.5.3 Emergency Core Cooling Systems -0perating 3.5.2.1 1 X--3.5.2.2 1 3.5.3.1 Verif valve position 1 3.5.2.3 1 3.5.3.2 Verifiy piing full 1 Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 11.I... ...rospondlng Polo Verde T8 Survellance Requirements.(.R) | '3.4.16.1 1 3.4.17.1 Verify gross specific activity 3.4.16.2 1 3.4.17.2 Verify Dose Equivalent 1-131 1 3.4.16.3 1 3.4.17.3 Determine E-BAR 1 3.4.18 Steam Generator Tube Integrit Not in TSTF 3.4.18.1 Verif tube integrity N/A Not in TSTF 3.4.18.2 Verif tubes plugged N/A 3.5.1 Safet Injection Tanks -0perating 3.5.1.1 SITs 1 3.5.1.1 Verif valve open 1 3.5.1.2 SITs 1 3.5.1.2 Verif borated water volume 1 3.5.1.3 SITs 1 3.5.1.3 Verif nitrogen cover pressure 1 3.5.1.4 SITs 1 3.5.1.4 Verif boron concentration 1 3.5.1.5 SITs 1 3.5.1.5 Verif power removed from valve operator 1 3.5.2 Safet Injection Tanks -Shutdown Not in TSTF 3.5.2.1 Verif valve open 1 X Not in TSTF 3.5.2.2 Verif borated water volume 1 X Not in TSTF 3.5.2.3 Verif nitrogen cover pressure 1 X Not in TSTF 3.5.2.4 Verif boron concentration 1 X Not in TSTF 3.5.2.5 Verif power removed from valve operator 1 X 3.5.3 Emergency Core Cooling Systems -0perating 3.5.2.1 1 X--3.5.2.2 1 3.5.3.1 Verif valve position 1 3.5.2.3 1 3.5.3.2 Verifiy piing full 1 Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 11.I... ...rospondlng Polo Verde T8 Survellance Requirements.(.R) | ||
., 3.5.2.4 N/A __3.5.3.3 Verify pump differential pressure N/A 3.5.2.5 N/A X--3.5.2.6 1 3.5.3.4 Verify valve actuation 1 __3.5.2.7 1 _ 3.5.3.5 Verify pump starts 1 3.5.2.8 1 3.5.3.6 Verify pump stops 1 __3.5.2.9 1 3.5.3.7 Verify throttle valve position 1 3.5.2.10 1 3.5.3.8 Verify flow path not obstructed 1__3.5.4 Emergency Core Cooling Systems -Shutdown Not in TSTF 3.5.4.1 Surveillance Requirements are applicable N/A 3.5.5 Refueling Water Tank 3.5.4.1 1 3.5.5.1 Verify water temperature 1 3.5.4.2 1 3.5.5.2 Verify borated water volume 1 3.5.4.3 1 3.5.5.3 Verify boron concentration 1 3.5.6 Trisodium Phosphate (TSP)3.5.5.1 1 3.5.6.1 Verify baskets contain TSP 1 3.5.5.2 1 3.5.6.2 Verify TSP provides adequate pH adjustment 1 3.6.1 Containment Not in TSTF 3.6.1.1 Perform leakage rate testing N/A Not in TSTF 3.6.1.2 Verify containment integrity N/A 3.5.2.4N/A | ., 3.5.2.4 N/A __3.5.3.3 Verify pump differential pressure N/A 3.5.2.5 N/A X--3.5.2.6 1 3.5.3.4 Verify valve actuation 1 __3.5.2.7 1 _ 3.5.3.5 Verify pump starts 1 3.5.2.8 1 3.5.3.6 Verify pump stops 1 __3.5.2.9 1 3.5.3.7 Verify throttle valve position 1 3.5.2.10 1 3.5.3.8 Verify flow path not obstructed 1__3.5.4 Emergency Core Cooling Systems -Shutdown Not in TSTF 3.5.4.1 Surveillance Requirements are applicable N/A 3.5.5 Refueling Water Tank 3.5.4.1 1 3.5.5.1 Verify water temperature 1 3.5.4.2 1 3.5.5.2 Verify borated water volume 1 3.5.4.3 1 3.5.5.3 Verify boron concentration 1 3.5.6 Trisodium Phosphate (TSP)3.5.5.1 1 3.5.6.1 Verify baskets contain TSP 1 3.5.5.2 1 3.5.6.2 Verify TSP provides adequate pH adjustment 1 3.6.1 Containment Not in TSTF 3.6.1.1 Perform leakage rate testing N/A Not in TSTF 3.6.1.2 Verify containment integrity N/A 3.5.2.4N/A | ||
....... .33.6.2 Containm ent Air Locks 3.6.2.1 N/A 3.6.2.1 Perform leakage rate testing N/A Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 12 I J t:l''Ulr Qo ll00ndcng Palo Verd itS urveilianoe 0 (R 3.6.2.2 1 3.6.2.2 Verif door operation1 | ....... .33.6.2 Containm ent Air Locks 3.6.2.1 N/A 3.6.2.1 Perform leakage rate testing N/A Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 12 I J t:l''Ulr Qo ll00ndcng Palo Verd itS urveilianoe 0 (R 3.6.2.2 1 3.6.2.2 Verif door operation1 3.6.3 Containment Isolation Valves 3.6.3.1 1 3.6.3.1 Verif valve position 1 3.6.3.2 1 3.6.3.3 Verif valve position 1 3.6.3.3 1 3.6.3.3 Verif valve position 1 3.6.3.4 N/A 3.6.3.4 Verif valve position N/A 3.6.3.5 1 3.6.3.5 Verif valve isolation time N/A 3.6.3.6 1 3.6.3.6 Perform leakae rate testing i 3.6.3.7 1 3.6.3.7 Verify valve actuation 1 3.6.3.8 1 X 3.6.3.9 N/A X 3.6.4 Containment Pressure 3.6.4A.1 1 3.6.4.1 Verify ressure within limits 1 3.6.5 Containment Air Ten erature 3.6.5.1 1 3.6.5.1 Verify tererature within limit 1 3.6.6 Containment S ray 3.6.6A.1 1 3.6.6.1 Verify valve position 1 3.6.6A.2 X 3.6.6A.3 1 X 3.6.6A.4 1 3.6.6.2 Verify piping full 1 3.6.6A.5 N/A 3.6.6.3 Verify ump ressure N/A 3.6.6A.6 1 3.6.6.4 Verify valve actuation 1 | ||
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 13.. In~I1taC6r*sponding Palo Verde TS Surveillance Requlrements (1R), 3.6.6A.7 1 3.6.6.5 Verify pump starts 1 3.6.6A.8 1 X 3.6.6A.9 1 3.6.6.6 Verify spray nozzle not obstructed 3.7.1 Main Steam Safety Valves Not in TSTF 3.7.,1.1 Verify lift setpoint N/A 3.7.2 Main Steam Isolation Valves 3.7.2.1 N/A 3.7.2.1 Verify valve isolation time N/A 3.7.2.2 1 X ---3.7.3 Main Feedwater Isolation Valves 3.7.3.1 N/A 3.7.3.1 Verify valve isolation time N/A 3.7.3.2 1 X ---3.7.4 Atmospheric Dump Valves 3.7.4.1 1 3.7.4.1 Cycle valves 1 3.7.4.2 1 X ---3.7.5 Auxiliary Feedwater System 3.7.5.1 1 3.7.5.1 Verify valve position 1 3.7.5.2 N/A 3.7.5.2 Verify pump pressure N/A 3.7.5.3 1 3.7.5.3 Verify valve actuation 1 3.7.5.4 1 3.7.5.4 Verify pump starts 1 3.7.5.5 N/A 3.7.5.5 Verify water flow N/A__ _ [ 1_ II 1i Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 14'0irnu r rp ndln Palo Verd' :S SurvelIInce Roqulrisnts | |||
Isolation Valves 3.6.3.1 1 3.6.3.1 Verif valve position 1 3.6.3.2 1 3.6.3.3 Verif valve position 1 3.6.3.3 1 3.6.3.3 Verif valve position 1 3.6.3.4 N/A 3.6.3.4 Verif valve position N/A 3.6.3.5 1 3.6.3.5 Verif valve isolation time N/A 3.6.3.6 1 3.6.3.6 Perform leakae rate testing i 3.6.3.7 1 3.6.3.7 Verify valve actuation 1 3.6.3.8 1 X 3.6.3.9 N/A X 3.6.4 Containment Pressure 3.6.4A.1 1 3.6.4.1 Verify ressure within limits 1 3.6.5 Containment Air Ten erature 3.6.5.1 1 3.6.5.1 Verify tererature within limit 1 3.6.6 Containment S ray 3.6.6A.1 1 3.6.6.1 Verify valve position 1 3.6.6A.2 X 3.6.6A.3 1 X 3.6.6A.4 1 3.6.6.2 Verify piping full 1 3.6.6A.5 N/A 3.6.6.3 Verify ump ressure N/A 3.6.6A.6 1 3.6.6.4 Verify valve actuation 1 | |||
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 13.. In~I1taC6r*sponding Palo Verde TS Surveillance Requlrements (1R), 3.6.6A.7 1 3.6.6.5 Verify pump starts 1 3.6.6A.8 1 X 3.6.6A.9 1 3.6.6.6 Verify spray nozzle not obstructed 3.7.1 Main Steam Safety Valves Not in TSTF 3.7.,1.1 Verify lift setpoint N/A 3.7.2 Main Steam Isolation Valves 3.7.2.1 N/A 3.7.2.1 Verify valve isolation time N/A 3.7.2.2 1 X ---3.7.3 Main Feedwater Isolation Valves 3.7.3.1 N/A 3.7.3.1 Verify valve isolation time N/A 3.7.3.2 1 X ---3.7.4 Atmospheric Dump Valves 3.7.4.1 1 3.7.4.1 Cycle valves 1 3.7.4.2 1 X ---3.7.5 Auxiliary Feedwater System 3.7.5.1 1 3.7.5.1 Verify valve position 1 3.7.5.2 N/A 3.7.5.2 Verify pump pressure N/A 3.7.5.3 1 3.7.5.3 Verify valve actuation 1 3.7.5.4 1 3.7.5.4 Verify pump starts 1 3.7.5.5 N/A 3.7.5.5 Verify water flow N/A__ _ [ 1_ II 1i Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 14'0irnu r rp ndln Palo Verd' :S SurvelIInce Roqulrisnts | |||
(,,),, J 3.7.6 Condensate Storage Tank 3.7.6.1 1 3.7.6.1 Verify level 1 3.7.7 Essential Cooling Water System 3.7.7.1 1 _ 3.7.7.1 Verify valve position 1 3.7.7.2 1 3.7.7.2 Verify valve actuation 1 3.7.7.3 1 3.7.7.3 Verify pump starts 1 3.7.8 Essential Spray Pond System 3.7.8.1 1 3.7.8.1 Verify valve position 1 3.7.8.2 1 X--3.7.8.3 1 3.7.8.2 Verify pump starts 1 3.7.9 Ultimate Heat Sink 3.7.9.1 1 3.7.9.1 Verify water depth 1 __3.7.9.2 1 3.7.9.2 Verify water temperature 1 3.7.9.3 1 X--3.7.10 Essential Chilled Water System 3.7.10.1 1 3.7.10.1 Verify valve position 1 __3.7.10.2 1 3.7.10.2 Verify system component actuation 1 3.7.11 Control Room Essential Filtration System 3.7.11.1 1 3.7.11.1 Operate each train 1 3.7.11.2 N/A __3.7.11.2 Perform filter testing N/A __3.7.11.3 1 __3.7.11.3 Verify train actuation 1 __ | (,,),, J 3.7.6 Condensate Storage Tank 3.7.6.1 1 3.7.6.1 Verify level 1 3.7.7 Essential Cooling Water System 3.7.7.1 1 _ 3.7.7.1 Verify valve position 1 3.7.7.2 1 3.7.7.2 Verify valve actuation 1 3.7.7.3 1 3.7.7.3 Verify pump starts 1 3.7.8 Essential Spray Pond System 3.7.8.1 1 3.7.8.1 Verify valve position 1 3.7.8.2 1 X--3.7.8.3 1 3.7.8.2 Verify pump starts 1 3.7.9 Ultimate Heat Sink 3.7.9.1 1 3.7.9.1 Verify water depth 1 __3.7.9.2 1 3.7.9.2 Verify water temperature 1 3.7.9.3 1 X--3.7.10 Essential Chilled Water System 3.7.10.1 1 3.7.10.1 Verify valve position 1 __3.7.10.2 1 3.7.10.2 Verify system component actuation 1 3.7.11 Control Room Essential Filtration System 3.7.11.1 1 3.7.11.1 Operate each train 1 3.7.11.2 N/A __3.7.11.2 Perform filter testing N/A __3.7.11.3 1 __3.7.11.3 Verify train actuation 1 __ | ||
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 15 OW.. .. Ciortespondlng Palo Verde TS Surveillanoe Requiroents (M)4 .T 3.7.11.4 1 X ---Not in TSTF 3.7.11.4 Perform air inleakage testing N/A 3.7.12 Control Room Emergency Air Temperature Control System 3.7.12.1 1 3.7.12.1 Verify train capability 1 3.7.13 Engineered Safety Feature Pump Room Exhaust Air Cleanup System 3.7.13.1 1 3.7.13.1 Operate each train 1 3.7.13.2 N/A 3.7.13.2 Perform filter testing N/A 3.7.13.3 1 3.7.13.3 Verify train actuation 1 3.7.13.4 1 3.7.13.4 Verify train capability 1 3.7.13.5 1 X 3.7.14 Fuel Storage Pool Water Level 3.7.16.1 1 3.7.14.1 Verify water level 1 3.7.15 Fuel Storage Pool Boron Concentration 3.7.17.1 1 3.7.15.1 Verify boron concentration 1 3.7.16 Secondary Specific Activity 3.7.19.1 1 3.7.16.1 Verify specific activity 1 3.7.17 Spent Fuel Assembly Storage Not in TSTF 3.7.17.1 Verify enrichment, burnup, and decay time N/A 3.8.1 AC Sources -Operating Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 16 Tip 4.. ,, it1. | Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 15 OW.. .. Ciortespondlng Palo Verde TS Surveillanoe Requiroents (M)4 .T 3.7.11.4 1 X ---Not in TSTF 3.7.11.4 Perform air inleakage testing N/A 3.7.12 Control Room Emergency Air Temperature Control System 3.7.12.1 1 3.7.12.1 Verify train capability 1 3.7.13 Engineered Safety Feature Pump Room Exhaust Air Cleanup System 3.7.13.1 1 3.7.13.1 Operate each train 1 3.7.13.2 N/A 3.7.13.2 Perform filter testing N/A 3.7.13.3 1 3.7.13.3 Verify train actuation 1 3.7.13.4 1 3.7.13.4 Verify train capability 1 3.7.13.5 1 X 3.7.14 Fuel Storage Pool Water Level 3.7.16.1 1 3.7.14.1 Verify water level 1 3.7.15 Fuel Storage Pool Boron Concentration 3.7.17.1 1 3.7.15.1 Verify boron concentration 1 3.7.16 Secondary Specific Activity 3.7.19.1 1 3.7.16.1 Verify specific activity 1 3.7.17 Spent Fuel Assembly Storage Not in TSTF 3.7.17.1 Verify enrichment, burnup, and decay time N/A 3.8.1 AC Sources -Operating Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 16 Tip 4.. ,, it1. | ||
| Line 2,069: | Line 1,928: | ||
* a T S S r lh "1,A ,~ ~,. I , , ,, , * ý0 , pn,,, P a ,, ....3.8.6.5 1 X ---3.8.6.6 1 X 3.8.7 Inverters | * a T S S r lh "1,A ,~ ~,. I , , ,, , * ý0 , pn,,, P a ,, ....3.8.6.5 1 X ---3.8.6.6 1 X 3.8.7 Inverters | ||
-Operating 3.8.7.1 1 3.8.7.1 Verify inverter voltage, frequency, and alignment 1 3.8.8 Inverters | -Operating 3.8.7.1 1 3.8.7.1 Verify inverter voltage, frequency, and alignment 1 3.8.8 Inverters | ||
-Shutdown 3.8.8.1 1 3.8.8.1 Verify inverter voltage, frequency, and alignment 1 3.8.9 Distribution Systems -Operating 3.8.9.1 1 3.8.9.1 Verify breaker alignment and voltage to distribution subsystems 1 3.8.10 Distribution Systems -Shutdown 3.8.10.1 1 3.8.10.1 Verify breaker alignment and voltage to distribution subsystems 1 3.9.1 Boron Concentration 3.9.1.1 1 3.9.1.1 Verify boron concentration | -Shutdown 3.8.8.1 1 3.8.8.1 Verify inverter voltage, frequency, and alignment 1 3.8.9 Distribution Systems -Operating 3.8.9.1 1 3.8.9.1 Verify breaker alignment and voltage to distribution subsystems 1 3.8.10 Distribution Systems -Shutdown 3.8.10.1 1 3.8.10.1 Verify breaker alignment and voltage to distribution subsystems 1 3.9.1 Boron Concentration 3.9.1.1 1 3.9.1.1 Verify boron concentration 3.9.2 Nuclear Instrumentation 3.9.2.1 1 3.9.2.1 Channel Check 1 3.9.2.2 1 3.9.2.2 Channel Calibration 1 3.9.3 Containment Penetrations 3.9.3.1 1 3.9.3.1 Verify containment penetration in required status 1 3.9.3.2 1 3.9.3.2 Verify valve actuation 1 Not in TSTF 3.9.3.3 Verify capability to close equipment hatch 1 X Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 19 6s~s~on ing Ow' OVo Vrde To$Surve It~~ 00! ri~nt f 3.9.4 Shutdown Cooling and Coolant Circulation | ||
Instrumentation 3.9.2.1 1 3.9.2.1 Channel Check 1 3.9.2.2 1 3.9.2.2 Channel Calibration 1 3.9.3 Containment Penetrations 3.9.3.1 1 3.9.3.1 Verify containment penetration in required status 1 3.9.3.2 1 3.9.3.2 Verify valve actuation 1 Not in TSTF 3.9.3.3 Verify capability to close equipment hatch 1 X Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 19 6s~s~on ing Ow' OVo Vrde To$Surve It~~ 00! ri~nt f 3.9.4 Shutdown Cooling and Coolant Circulation | |||
-High Water Level 3.9.4.1 1 3.9.4.1 Verif laoo operable 1 3.9.5 Shutdown Cooling and Coolant Circulation | -High Water Level 3.9.4.1 1 3.9.4.1 Verif laoo operable 1 3.9.5 Shutdown Cooling and Coolant Circulation | ||
-Low Water Level 3.9.5.1 1 3.9.5.1 Verif loop operable 1 3.9.5.2 1 3.9.5.2 Verif breaker alignment and ower available 1 3.9.6 Refueling Water Level -Fuel Assemblies 3.9.6.1 1 3.9.6.1 Verif water level 1 3.9.7 Refueling Water Level -CEAs Not in TSTF 3.9.7.1 Verify water level 1 X Notes 1 .TSTF 425 SR Number -A list of the surveillance requirements provided in the TSTF for change.2. Insert -"1l" is provided in this column where standard insert wording is being used for the surveillance requirement being relocated, --"is provided where the surveillance requirement does not exist, and "N/A" is provided where no change is proposed because the surveillance requirement is event driven, conditional, or controlled by another approved program and therefore not a candidate for relocation. | -Low Water Level 3.9.5.1 1 3.9.5.1 Verif loop operable 1 3.9.5.2 1 3.9.5.2 Verif breaker alignment and ower available 1 3.9.6 Refueling Water Level -Fuel Assemblies 3.9.6.1 1 3.9.6.1 Verif water level 1 3.9.7 Refueling Water Level -CEAs Not in TSTF 3.9.7.1 Verify water level 1 X Notes 1 .TSTF 425 SR Number -A list of the surveillance requirements provided in the TSTF for change.2. Insert -"1l" is provided in this column where standard insert wording is being used for the surveillance requirement being relocated, --"is provided where the surveillance requirement does not exist, and "N/A" is provided where no change is proposed because the surveillance requirement is event driven, conditional, or controlled by another approved program and therefore not a candidate for relocation. | ||
: 3. N/A PV -An "X" in this column means Palo Verde does not have the surveillance requirement referenced in the TSTF.4. Similar Corresponding Palo Verde TS Surveillance Requirements (SR) -A list of the similar surveillance requirements that are included in the PVNGS Technical Specifications. | : 3. N/A PV -An "X" in this column means Palo Verde does not have the surveillance requirement referenced in the TSTF.4. Similar Corresponding Palo Verde TS Surveillance Requirements (SR) -A list of the similar surveillance requirements that are included in the PVNGS Technical Specifications. | ||
: 5. TSTF Logic -An "X" in this column indentifies where logic from the TSTF was used to justify changes to PVNGS surveillance requirements.}} | : 5. TSTF Logic -An "X" in this column indentifies where logic from the TSTF was used to justify changes to PVNGS surveillance requirements.}} | ||
Revision as of 15:20, 30 April 2019
| ML11103A053 | |
| Person / Time | |
|---|---|
| Site: | Palo Verde  |
| Issue date: | 03/31/2011 |
| From: | Mims D C Arizona Public Service Co |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| 102-06341-DCM/DLK | |
| Download: ML11103A053 (439) | |
Text
10 CFR 50.90 i A M A subsidiary of Pinnacle West Capital Corporation Dwight C. Mims Mail Station 7605 Palo Verde Nuclear Senior Vice President Tel. 623-393-5403 P.O. Box 52034 Generating Station Nuclear Regulatory and Oversight Fax 623-393-6077 Phoenix, Arizona 85072-2034 102-06341-DCM/DLK March 31, 2011 ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001
Dear Sirs or Madam:
Subject:
Palo Verde Nuclear Generating Station (PVNGS)Units 1, 2, and 3 Docket Nos. STN 50-528, 50-529, and 50-530 Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee-Controlled Program Pursuant to 10 CFR 50.90, Arizona Public Service Company (APS) hereby requests to amend Operating License Nos. NPF-41, NPF-51, and NPF-74 for Palo Verde Nuclear Generating Station (PVNGS) Units 1, 2, and 3, respectively.
The proposed amendment would modify the Palo Verde Technical Specifications by relocating specific surveillance frequencies to a licensee-controlled program in accordance with Nuclear Energy Institute (NEI) 04-10 "Risk-Informed Technical Specification Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies." PVNGS is a member of the Strategic Teaming and Resource Sharing (STARS) alliance.This amendment request has been prepared in conjunction with STARS and utilized the lessons learned from previous STARS amendment requests.
The STARS alliance has previously obtained approval for two member utilities (Diablo Canyon and South Texas)to utilize the provisions of NEI 04-10. Additional STARS utilities are considering similar risk informed application requests.
The STARS alliance plans on using the experience and resources of the alliance in order to share programs, training, and procedures relative to a licensee-controlled surveillance frequency control program.All required information is provided in the attachments to this letter. Attachment 1 provides a description of the proposed changes, the required confirmation of A member of the STARS (Strategic Teaming and Resource Sharing) Alliance Callaway
- Comanche Peak
- Diablo Canyon
- Palo Verde 0 San Onofre 0 South Texas 0 Wolf Creek ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Request to Relocate Surveillance Frequency Requirements to Licensee-Controlled Program Page 2 applicability, and plant-specific verifications.
Attachment 2 provides documentation of probabilistic risk assessment (PRA) technical adequacy.
Attachment 3 provides the existing TS pages marked up to show the proposed change. Attachment 4 provides revised (retyped)
TS pages. Attachment 5 provides the marked up existing TS Bases in support of the proposed change. Attachment 6 provides the No Significant Hazards Consideration.
Attachment 7 provides a cross-reference between Technical Specification Task Force (TSTF)-425 (NUREG-1432) and the Palo Verde Technical Specifications.
APS requests approval of the proposed license amendment by April 1, 2012, with the amendment being implemented within 180 days following NRC approval of the license amendment.
In accordance with the PVNGS Quality Assurance Program, the Plant Review Board and the Offsite Safety Review Committee have reviewed and concurred with the proposed amendment.
By copy of this letter, this submittal is being forwarded to the Arizona Radiation Regulatory Agency (ARRA) pursuant to 10 CFR 50.91 (b)(1).No commitments are being made to the NRC by this letter.Should you need further information regarding this amendment request, please contact Russell A. Stroud, Licensing Section Leader, at (623) 393-5111.I declare under penalty of perjury that the foregoing is true and correct.Executed on ___-5 __1_(Date)Sincerely, DMC/RAS/DLK/
ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Request to Relocate Surveillance Frequency Requirements to Licensee-Controlled Program Page 3 Attachments:
- 1. Description and Assessment
- 2. Documentation of PRA Technical Adequacy 3. Proposed Technical Specification Changes 4. Retyped Technical Specification Pages 5. Proposed Technical Specification Bases Changes 6. Proposed No Significant Hazards Consideration
- 7. TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference cc: E. E. Collins Jr.L. K. Gibson J. R. Hall M. A. Brown A. V. Godwin T. Morales NRC Region IV Regional Administrator NRC NRR Project Manager for PVNGS NRC NRR Senior Project Manager NRC Senior Resident Inspector for PVNGS Arizona Radiation Regulatory Agency (ARRA)Arizona Radiation Regulatory Agency (ARRA)
Attachment I Description and Assessment
1.0 DESCRIPTION
2.0 ASSESSMENT 2.1 Applicability of Published Safety Evaluation 2.2 Optional Changes and Variations 3.0 REGULATORY ANALYSIS 3.1 Applicable Regulatory Requirements/Criteria 3.2 Precedent 3.3 No Significant Hazards Consideration Determination 3.4 Conclusions 4.0 ENVIRONMENTAL CONSIDERATION 5.0 REFERENCE Attachment 1 Description and Assessment Request for Adoption of TSTF 425, Rev. 3 Page 1
1.0 DESCRIPTION
Pursuant to 10 CFR 50.90, Arizona Public Service Company (APS) hereby requests to amend Operating License Nos. NPF-41, NPF-51, and NPF-74 for Palo Verde Nuclear Generating Station (PVNGS) Units 1, 2, and 3, respectively.
The proposed amendment would modify the PVNGS technical specifications by relocating specific surveillance frequencies to a licensee-controlled program with the adoption of Technical Specification Task Force (TSTF) Traveler 425, Revision 3,"Relocate Surveillance Frequencies to Licensee Control -Risk Informed Technical Specification Task Force (RITSTF) Initiative 5b." Additionally, the change would add a new program, the Surveillance Frequency Control Program, to Technical Specification (TS) Section 5, Administrative Controls.
The existing TS Bases information describing the basis for the Surveillance Frequency will be relocated to the licensee-controlled Surveillance Frequency Control Program.The changes are consistent with NRC approved Industry/TSTF STS change TSTF-425, Revision 3, (ADAMS Accession No. ML090850642).
The Federal Register Notice published on July 6, 2009 (74 FR 31996) announced the availability of this TS improvement.
Included in the Federal Register Notice was a generic Safety Evaluation intended to be used for processing/approving license amendment requests submitted by licensees choosing to adopt TSTF-425.2.0 ASSESSMENT 2.1 Applicability of Published Safety Evaluation Arizona Public Service Company (APS) has reviewed the generic safety evaluation included in the Federal Register Notice published on July 6, 2009 (74 FR 31996) for implementation of TSTF-425, Revision 3, and the requirements specified in NEI 04-10, Rev. 1, (ADAMS Accession No.ML071360456).
Attachment 2 includes APS documentation of the technical adequacy of the current PVNGS probabilistic risk assessment (PRA) with regards to the requirements of Regulatory Guide 1.200, Revision 2 (ADAMS Accession No.ML090410014)
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.APS has concluded that the justifications presented in the TSTF proposal and the safety evaluation prepared by the NRC staff are applicable to PVNGS and justify the requested license amendment to incorporate the changes to the PVNGS TS.
Attachment I Description and Assessment Request for Adoption of TSTF 425, Rev. 3 Page 2 2.2 Optional Changes and Variations The proposed amendment is consistent with the NUREG 1432 Standard Technical Specifications (STS) changes described in TSTF-425, Revision 3;but, APS proposes variations or deviations from TSTF-425, as identified below. The proposed variations or deviations may include differing TS surveillance numbers." The definition of STAGGERED TEST BASIS is being retained in PVNGS TS Definition Section 1.1 since this terminology is mentioned in Administrative TS Section 5.5.17, "Control Room Envelope Habitability Program," which is not the 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 (74 FR 31996)." NRC letter dated April 14, 2010 (Reference
- 1) provides a change to an optional insert (INSERT #2) to the existing TS Bases to facilitate adoption of the TSTF while retaining the existing NUREG 1432 TS surveillance frequency (SF) Bases considerations for licensees not choosing to adopt TSTF-425.
The TSTF-425 TS Bases insert states as follows: The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program.Recently several licensees submitting license amendment requests for adoption of TSTF-425 have identified a need to deviate from this statement because it only applies to frequencies that have been changed in accordance with the Surveillance Frequency Control Program (SFCP) and does not apply to frequencies that are relocated but not changed.The NRC staff agreed that the TSTF-425 TS Bases insert applies to SFs that are relocated and subsequently evaluated and changed, in accordance with the SFCP in NRC letter dated April 14, 2010 (Reference 1). The TSTF-425 TS Bases does not apply to SFs relocated to the SFCP but not changed. Therefore, for SFs relocated to the SFCP but not changed, the existing TS Bases description remains a valid description of the TS SF Bases for the unchanged SF.
Attachment 1 Description and Assessment Request for Adoption of TSTF 425, Rev. 3 Page 3 To resolve this issue with existing license amendment requests and to avoid future problems, the NRC staff supported the following recommended changes to clarify the applicability of the TS SF Bases, maintain consistency with TSTF-425 TS SFCP requirements, and allow retention of existing TS SF Bases for licensees who choose not to adopt TSTF-425: 1. The existing Bases information describing the basis for the Surveillance Frequency will be relocated to the licensee-controlled Surveillance Frequency Control Program.2. The TSTF-425 TS Bases, INSERT #2, should be added to the end of the existing TS Bases and changed to read as follows: The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.APS has incorporated these recommended changes into this license amendment request.3.0 REGULATORY ANALYSIS 3.1 Applicable Regulatory Requirements/Criteria None 3.2 Precedent Peach Bottom On August 27, 2010, the Nuclear Regulatory Commission issued Amendment Nos. 278 and 281 to Renewed Facility Operating License Nos. DPR-44 and DPR-56 for the Peach Bottom Atomic Power Station (PBAPS), Units 2 and 3.The amendments consist of changes to the Technical Specifications in response to the Licensee's application dated August 31, 2009 (ADAMS Accession No. ML092470153).
The amendments revised the PBAPS Units 2 and 3 TSs to adopt approved Technical Specification Task Force (TSTF)Traveler 425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control -Risk-Informed Technical Specification Task Force Initiative 5b," (ADAMS Accession No. ML090850627)
Oyster Creek On September 27, 2010, the Nuclear Regulatory Commission issued Amendment No. 276 to Renewed Facility Operating License No. DPR-16 for Attachment I Description and Assessment Request for Adoption of TSTF 425, Rev. 3 Page 4 the Oyster Creek Nuclear Generating Station. The amendment consisted of changes to the Technical Specifications in response to the Licensee's application dated October 30, 2009, (ADAMS Accession No. ML093060126), as supplemented by letters dated April 16, 2010, and August 31,2010 (ADAMS Accession Nos. ML101060560 and ML102430467, respectively).
The amendment revised the Oyster Creek Technical Specifications to relocate a number of Surveillance Requirement frequencies to a licensee-controlled document.3.3 No Significant Hazards Consideration APS has reviewed the proposed no significant hazards consideration determination (NSHC) published in the Federal Register on July 6, 2009 (74 FR 31996) and has concluded that the proposed NSHC presented in the Federal Register notice is applicable to Palo Verde. As such, the NSHC determination for this amendment request is provided as Attachment 6 to this license amendment request which satisfies the requirements of 10 CFR 50.91(a).3.4 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 CONSIDERATIONS A review has determined that the proposed amendment would change an inspection or surveillance requirement.
However, the proposed amendment does not involve (i) a significant hazards consideration, (ii) a significant change in the types or a significant increase in the amounts of any effluents that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure.
Accordingly, the proposed amendment meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9).
Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed amendment.
Attachment 1 Description and Assessment Request for Adoption of TSTF 425, Rev. 3 Page 5 5.0 REFERENCE 1. NRC Letter, "Notification of Issue with NRC-Approved Technical Specification Task Force (TSTF) Traveler 425, Revision 3, 'Relocate Surveillance Frequencies to Licensee Control -RITSTF Initiative 5b,"' dated April 14, 2010 (ADAMS Accession No ML100990099).
Attachment 2 Documentation of Probabilistic Risk Assessment Technical Adequacy 1.0 OVERVIEW 2.0 BASIS TO CONCLUDE THAT THE PRA MODEL REPRESENTS THE AS-BUILT, AS-OPERATED PLANT 3.0 PEER REVIEW FINDINGS AND OBSERVATIONS FOR INTERNAL EVENTS AND INTERNAL FLOOD PRA MODEL 4.0 METHODOLOGY TO BE USED TO ASSESS STI CHANGES 5.0 KEY ASSUMPTIONS AND APPROXIMATIONS 6.0 EXTERNAL EVENTS RISK
7.0 CONCLUSION
S ON PRA TECHNICAL ADEQUACY
8.0 REFERENCES
TABLE 1 OPEN CEOG INTERNAL EVENT PRA PEER REVIEW F&Os TABLE 2 RG 1.200 CATEGORY II SUPPORTING REQUIREMENTS NOT MET EVALUATION Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 1 1.0 OVERVIEW Palo Verde Nuclear Generating Station (PVNGS) will follow the methodology provided in NEI 04-10 (Reference
- 1) for Risk-Informed Technical Specifications (RITS) Initiative 5b. NEI 04-10 endorses Regulatory Guide (RG) 1.200 (Reference
- 2) for determining the technical adequacy of a plant Probabilistic Risk Assessment (PRA). Consistent with the requirements of RG 1.200 Section 4.2, the technical adequacy of the PVNGS PRA model used as the basis for risk-informed applications is established by the following: " Identifying plant changes that have been incorporated at the site, but are not yet in the PRA model and justify why the changes do not impact the PRA results used to support the amendment request.* Documenting that the parts of the current PRA used in support of the amendment request are consistent with applicable standards endorsed by RG 1.200 (Reference
- 2) and, where specific requirements in the Regulatory Guide are not adequately met, justifying why the recommendations not met will not unduly impact the results.* Identifying key assumptions and approximations relevant to the results used in the decision-making process including the peer reviewers' assessment of those assumptions.
- Documenting 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, justifying why the significant contributors would not be impacted.2.0 BASIS TO CONCLUDE THAT THE PRA MODEL REPRESENTS THE AS-BUILT, AS-OPERATED PLANT To ensure the technical adequacy of the PVNGS PRA model and documentation, PVNGS administrative procedure 70DP-ORA03, "Probabilistic Risk Assessment Model Control," provides guidelines for updating the PRA model and documentation.
In accordance with 70DP-ORA03 and related procedures, plant changes that could impact the PRA model are screened and evaluated.
Plant changes that are screened and evaluated are: plant modifications, error corrections, procedure changes, plant data update, and improved methods.Procedure 70DP-ORA03 defines the process and the minimum frequency for updating the PRA model and associated documentation that may be impacted by plant changes. The objective of the above-described procedural guidance is to assure that the PRA model is an accurate reflection of the as-built and as-operated plants. At the present time, the Internal Events and Flood PRA model reflects the as-built, as-operated plant.
Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 2 3.0 PEER REVIEW FINDINGS AND OBSERVATIONS FOR INTERNAL EVENTS AND INTERNAL FLOOD PRA MODEL The PVNGS Internal Events and Internal Flood PRA model received several assessments to establish the technical quality of the PRA. These assessments are identified and discussed in the paragraphs below.* In 1999, a PRA peer review was conducted by the Combustion Engineering Owners Group (CEOG) on the Internal Events PRA model.This peer review included an assessment of the PRA model maintenance and update process using the CEOG established peer review process based on the Boiling Water Reactor Owners Group peer review process." In 2010, a PVNGS self-assessment was performed on the Internal Events PRA model to assess the gaps between the CEOG peer review scope/detail for the PVNGS peer review results and the American Society of Mechanical Engineers (ASME)/American Nuclear Society (ANS) PRA Standard (Reference
- 3) and RG 1.200 (Reference
- 2) guidance." In 2010, Westinghouse performed a peer review of the PVNGS PRA Internal Flood model against the requirements of the ASME/ANS PRA Standard (Reference
- 3) and any Clarifications and Qualifications provided in RG 1.200 (Reference 2).A peer review was conducted in 1999 by the CEOG on the PVNGS Internal Events PRA model resulting in 77 Fact & Observations (F&Os). The levels of significance of the F&Os are as follows: A -Extremely important and necessary to address to assure the technical adequacy of the Probabilistic Safety Assessment (PSA) or the quality of the PSA or the quality of the PSA update process.(Contingent Item for Certification)
B -Important and necessary to address, but may be deferred until the next PSA update. (Contingent Item for Certification)
C -Considered desirable to maintain maximum flexibility in PSA Applications and consistency in the Industry but not likely to significantly affect the results or insights.D -Editorial or Minor Technical Item, left to the discretion of the host utility.O -Observation.
S -Superior treatment exceeding requirements and exceeding what would be found in most PRAs.There were 8 'A', 27 'B', 20 'C', and 11 'D' level F&Os identified during the review. Additionally, there were 2 'S' F&Os denoting a strength and 9 '0' F&Os Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 3 which are observations used to define a scope of review. There are three remaining open level 'A' or 'B' F&Os. All three are level 'B' F&Os and are listed in Table 1.A PVNGS self-assessment performed on the Internal Events PRA model was completed in 2010. The self-assessment was performed based on the PRA ASME/ANS RA-Sa-2009 Standard (Reference
- 3) and RG 1.200 (Reference 2).The results of the self-assessment identified four supporting requirements (SRs)from the ASME/ANS RA-Sa -2009 Standard (Reference
- 3) for which there were potential gaps to Capability Category II of the Standard.
As part of this amendment request, the four SRs not meeting Capability Category II in the self-assessment were reviewed to evaluate their potential impact on the surveillance test interval (STI) assessments.
A summary of the "not met" SRs for Capability Category II is provided in Table 2. An assessment is provided for each "not met" SR that indicates the impact on the application of the current PRA for this amendment request.In 2010, a peer review of the Internal Flood PRA model was performed by Westinghouse covering a total of sixty-two (62) SRs associated with internal flood in the ASME/ANS PRA Standard (Reference 3). The peer review identified seven priority 'A' and no priority 'B' F&Os. All of the priority 'A' F&Os have been resolved.
Therefore, all findings of "not met" Capability Category II SRs have been resolved.4.0 METHODOLOGY TO BE USED TO ASSESS STI CHANGES The methodology/guidance of NEI 04-10 (Reference
- 1) will be used to assess STI changes.5.0 KEY ASSUMPTIONS AND APPROXIMATIONS The following definitions from the RG 1.200, Section 4.2 (Reference 2), are used to clarify the nature of the "key assumptions." A "key assumption" is one that is made in response to a key source of model uncertainty in the knowledge that a different reasonable alternative assumption would produce different results, or an assumption that results in an approximation made for modeling convenience in the knowledge that a more detailed model would produce different results. For the base PRA, the term"different results" refers to a change in the risk profile [e.g., total core damage frequency (CDF) and total large early release frequency (LERF), the set of initiating events and accident sequences that contribute most to CDF and to LERF, and the associated changes in insights derived from the changes in the risk profile].
A "reasonable alternative" assumption is one that has broad acceptance within the technical community and for which the technical basis for Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 4 consideration is at least as sound as that of the assumption being challenged.
A"key source of uncertainty" is one that is related to an issue in which there is no consensus approach or model and where the choice of approach or model is known to have an impact on the risk profile such that it influences a decision being made using the PRA. Such an impact might occur, for example, by introducing a new functional accident sequence or a change to the overall CDF or LERF estimates significant enough to affect insights gained from the PRA.Based on these definitions, a list of potential contributors to the uncertainty in the PRA was compiled.
Affected STI changes shall be evaluated using sensitivity analyses for these uncertainties.
There were no related peer review comments identified for the following key assumptions.
- Reactor Coolant Pump (RCP) Seal Leak or Rupture* Loss of Coolant Accident (LOCA) Frequencies
- Loss of Off-site Power (LOOP) Frequency* Loss of Off-site Power at Switchyard (LOSP) Associated Non-Recovery Probabilities
- Battery Life Assumptions RCP Seal Leak or Rupture RCP Seal Leak or Rupture is not modeled as a loss of RCS Inventory safety function.
Based on Westinghouse WCAP-1 5749 (Reference
- 8) and pump seal vendor information, it was concluded that because of the very tight clearances, leakage into the seal package from the RCS is limited to about 17 gallons per minute per pump. Each of the four RCPs has a seal package which consists of three seals. As a result, even if the seal package on all four RCPs failed, the total leak rate would be within the capacity of two charging pumps and does not qualify as a LOCA. An analysis was performed showing that continuing to model RCP seal leakage and requiring charging pumps to mitigate the leakage represented an insignificant contribution to CDF or LERF, even assuming one of the three seals on each pump failed. The analysis also showed that modeling catastrophic failure due to operator failure to secure the pumps upon loss of cooling and seal injection was an insignificant contributor to CDF or LERF.LOCA Frequencies NUREG/CR-6928 "Industry-Average Performance for Components and Initiating Events at U.S. Commercial Nuclear Power Plants" (Reference
- 9) restated the results from NUREG-1 829 "Estimating Loss-of-Coolant Accident (LOCA)Frequencies through the Elicitation Process" (Reference 10). The LOCA frequencies are based upon expert elicitations.
The LOCA sizes identified by the NRC are different from those estimated for PVNGS. For PVNGS, a small LOCA Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 5 is that of an equivalent flow area <0.03 sq ft; a medium LOCA equivalent diameter is between 0.03 and 0.3 sq ft; and a large LOCA is one of >0.3 sq ft.LOOP Frequency The national LOOP data presented in the latest EPRI events report 1002987 (Reference
- 5) and 100980 (Reference
- 6) was used to obtain point-estimates for switchyard centered and severe weather related LOOP frequencies.
The EPRI Reports provide that the generic LOOP data is subject to user modifications and screenings to fit the local plant designs and environmental conditions.
This approach of LOOP screening is considered reasonable and necessary to avoid erroneous skewing of the LOOP data. The frequency of extreme weather LOOP category was obtained as that of the frequency of tornado occurrence with category F2 or higher. The frequency of grid related LOOP was obtained by Bayesian updating the reported value for western region (Western Electricity Coordinating Council) in the Draft NRC NUREG/CR-INEEL/EXT-04-02326 (Reference 7).LOSP Associated Non-Recovery Probabilities The probabilities of offsite power non-recoveries were obtained from Table 4-1 of the draft NRC NUREG/CR-INEEL/EXT-04-02326 (Reference 7). The error factors associated with LOOP frequencies and LOOP non-recovery probabilities were obtained from the draft NRC NUREG/CR-INEEL/EXT-04-02326 (Reference
- 7) (when provided), otherwise, by using available in-house statistical programs for lognormal and Weibull distributions.
Battery Life Assumptions The PVNGS batteries are not credited in the long term fault trees, because they are conservatively assumed to be discharged after 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. Although the class batteries are designed to operate for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, Engineering has determined that the class batteries' life is at least 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. Thus they are available for power recovery at 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />.For each STI change under consideration PVNGS PRA personnel will determine if any assumptions or approximations will impact the PRA calculations, and therefore need to be addressed using sensitivity analyses or other means.6.0 EXTERNAL EVENTS RISK For the Individual Plant Examination of External Events (IPEEE), PVNGS employed the following methodologies:
Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 6 (a) EPRI's Seismic Margins Analysis (0.3g Review Level Earthquake) to identify vulnerabilities to seismic events;(b) Fire Induced Vulnerability Evaluation (FIVE) (including NRC prescribed enhancements) to identify vulnerabilities due to internal fires; and (c) Utilization of the screening approach described in NUREG-1407 (Reference
- 4) to identify potential vulnerabilities due to high winds, external floods, and transportation and nearby facility accidents.
The NEI 04-10 (Reference
- 1) guidance takes these methodologies into account.In cases where these methodologies cannot be used for an STI change evaluation, qualitative or bounding analysis will be utilized to provide justification for the acceptability of the proposed STI change. PVNGS will follow the NEI 04-10 (Reference
- 1) guidance to assess the fire and seismic risk associated with STI changes.
7.0 CONCLUSION
S ON PRA TECHNICAL ADEQUACY As a result of the sound basis of the PVNGS PRA model and the efforts to incorporate the latest industry insights into the PRA through the use of self-assessments and peer reviews, PVNGS is confident that the application of the PVNGS Internal Events and Flood PRA model in support of the license amendment will meet the expectations for PRA technical adequacy.
PVNGS will evaluate the impact of future model updates for both internal and external events models on the conclusions of the assessments that are performed in support of this amendment request. This approach is judged to be the most effective approach in assuring the appropriateness of the PRA technical adequacy and scope.
Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 7
8.0 REFERENCES
- 1. NEI 04-10, Revision 1, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies." 2. Regulatory Guide 1.200, Revision 2, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities." 3. ASME/ANS RA-Sa-2009, "Addenda to ASME/ANS RA-S-2008 Standard for Level 1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications." 4. NUREG-1407, "Procedural and submittal Guidance for the Individual Plant Examination of External Events (IPEEE) for Severe Accident Vulnerabilities." 5. EPRI Report 1002987, "Loss of Offsite Power at U.S. Nuclear Plants Through 2001 ." 6. EPRI Report 100980, "Loss of Offsite Power at U.S. Nuclear Plants Through 2004." 7. NUREG/CR-INEEL/EXT-04-02326, "Evaluation of Loss of Offsite Power Events at Nuclear Power Plants." (draft)8. WCAP-1 5749, Revision 1, "Guidance for the Implementation of the CEOG Model for Failure of RCP Seals Given Loss of Seal Cooling." 9. NUREG/CR -6928, "Industry-Average Performance for Components and Initiating Events at U.S. Commercial Nuclear Power Plants." 10. NUREG-1 829, "Estimating Loss-of-Coolant Accident (LOCA) Frequencies Through the Elicitation Process."
Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 8 TABLE I OPEN CEOG INTERNAL EVENT PRA PEER REVIEW F&Os Table I -Open COGG Internal Event PRA Peer Review F&Os Sub-ID element Observation Level Possible Resolution Plant Response SY-03 SY-3 Many of the assumptions contained in the AFW B Independently review the This issue is part of SR analysis address plant phenomena, but contain no assumptions and key inputs. Link SY-C1, which is listed plant references.
For example, AF024, states no plant documents directly to the as "Open" in Table 2 significant diversion paths were identified.
But no assumptions and key inputs, and addressed there.detailed discussion is provided.
There are several piping taps from the [condensate storage tank] CST.From a walkdown some of these taps occur high in the tank, while others associated with the condensate transfer pumps are low in the tank. It is not clear that potential diversions through the condensate transfer pumps have been examined.
The drawings that illustrate the flow destination for the pumps are not referenced in the AFW system study: DGP-001, ECP-001, and EWP-001. It also appears that the assumptions themselves are not independently reviewed.
As a result, the independent reviews of the system studies are not complete.
Each individual assumption should have plant documentation and an independent review. The system study independent review would then only need to ensure that the assumption is applicable to and reflects the model itself. This appears to be what is done now, but without an independent review of the assumptions.
Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 9 Table I -Open EGInternaG vn P pper Rpview F&Os _______ID Obsrbaio element Observation Level Possible Resolution Plant Response SY-05 SY-4 It is difficult to verify that the systems are in B Link dependencies directly to plant This issue is part of SR agreement with the as-built conditions.
The current documentation.
SY-C1, which is listed software is only capable of displaying a two by three as "Open" in Table 2 portion of the fault tree. When attempting to verify the and addressed there.AFW system, only a sample of the fault tree was examined.
From the portion examined no discrepancies were identified.
There were no direct references between the fault tree supports and the plant drawings.
For example the power supplies to the motor driven pumps are contained in the fault tree, but a plant drawing reference is not directly linked to this dependency.
The back of the system study does provide a list of references, but the specific references are not linked to dependencies.
Not only does this make review by outside personnel difficult, it makes internal independent reviews difficult as well.DE-10 DE-12, The documentation is considered marginal largely B Directly link dependencies to plant This issue is part of SR DE-13, based on the lack of traceability of the system studies references.
SY-C1, which is listed DE-14 to plant documentation for each component as "Open" in Table 2 dependency.
and addressed there.
Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 10 TABLE 2 RG 1.200 CATEGORY II SUPPORTING REQUIREMENTS NOT MET EVALUATION
............
Table 2- RG .200 Cz ojy Ii sLupporýg Requirements Not Met"Evaluation1 Assessment Comments .RTS 5b SUbrnittai Evai'atloh IDCteoyI E-A8 INTERVIEW plant personnel (e.g., operations, 13-NS-B060 does not document or suggest CE System-80 specific initiating events maintenance, engineering, safety analysis) to that interviews were conducted.
were identified in 13-NS-B060.
These determine if potential initiating events have been PVNGS-specific initiators were identified overlooked.
through extensive input from System Engineering and Operations personnel.
The documentation of that input may be insufficient.
Plant experience is reviewed to periodically update initiating event frequencies.
New types of relatively frequent events would be picked up during this review. Knowledge of infrequent or rare events would probably not come from operators or engineers.
It is judged that this lack of documentation of operator and engineer interviews has not resulted in any significant initiators unaccounted for. Until the documentation for each system is updated, the impact of this gap will be evaluated for each surveillance frequency change.
Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 11___ Table 2-; .G12O -ategoryI Supportingiq feugemdents' NtMet Ealu o Sec Sec .Category.
...Assessment Comments ROTS, 5b Submittal Evaluation., ID _______ ______ _____',__1'r__'-:, SY-A4 PERFORM plant walkdowns and interviews with Walkdowns and interviews either were not Athough not documented, system engineers knowledgeable plant personnel (e.g., engineering, plant conducted or not documented
-SR not met. reviewed the fault tree modeling for their operations, etc.) to confirm that the systems analysis systems and provided comments and input correctly reflects the as-built, as-operated plant. to the PRA analysts.
The PRA analysts were also knowledgeable in plant layout and operation, both normal and emergency.
Several of the PRA staff involved in system analysis held a Shift Technical Advisor or Senior Reactor Operator license or certification.
Changes to procedures, drawings and other relevant documents are tracked and reviewed to ensure the PRA reflects the as-built and as-operated plant.Therefore, there is high confidence that the PRA reflects the as-built, as-operated plant.Until the documentation for each system is updated, the impact of this gap will be evaluated for each surveillance frequency change.SY-Ci I)OCUMENT the systems analysis in a manner that System studies have not been updated for several Changes to the plant design and procedures facilitates PRA applications, upgrades, and peer review, revisions of the model. Although the memos in are captured in model impacts documented Risk Spectrum are maintained current and are in 13-NS-B067.
System boundaries, linked to the appropriate parameter, this cannot functions and success criteria have been be said to facilitate applications, upgrades and reviewed and further defined for reviews -this SR is not met. Maintenance Rule documentation and compliance.
No actual shortcomings that would impact this application have been discovered internally or through peer reviews. Until the documentation for each system is updated, the impact of this gap will be evaluated for each surveillance frequency change.
Attachment 2 Documentation of PRA Technical Adequacy Request for Adoption of TSTF 425, Rev. 3 Page 12____ Table 2 CG 1 Category ll Supporting Requirenents Noth et Evaluatlon; C a'go r y' I A s s m t C m e R IýT S 5 b Si E v a l u t io n ID Cate'gory Hl Assessment Comments RITS 5b Submittal Evaluation SY-C2 DOCUMENT the system functions and boundary, the associated success criteria, the modeled components and failure modes including human actions, and a description of modeled dependencies including support system and common cause failures, including the inputs, methods, and results. For example, this documentation typically includes (a) system function and operation under normal and emergency operations (b) system model boundary (c)system schematic illustrating all equipment and components necessary for system operation (d)information and calculations to support equipment operability considerations and assumptions (e) actual operational history indicating any past problems in the system operation (f) system success criteria and relationship to accident sequence models (g) human actions necessary for operation of system (h) reference to system-related test and maintenance procedures (i) system dependencies and shared component interface (j)component spatial information (k) assumptions or simplifications made in development of the system models (1) the components and failure modes included in the model and justification for any exclusion of components and failure modes (in) a description of the modularization process (if used) (n) records of resolution of logic loops developed during fault tree linking (if used) (o) results of the system model evaluations (p) results of sensitivity studies (if used) (q) the sources of the above information (e.g., completed checklist from walkdowns, notes from discussions with plant personnel) (r) basic events in the system fault trees so that they are traceable to modules and to cutsets (s) the nomenclature used in the system models.Fhe system studies are out of date (not revised since model was converted for UNIX). Many of the required elements of this SR are missing or incomplete, even in the memos in the Risk Spectrum database (lower case sy is the system designator; xx denotes a sequential number). (a)Documented in SY-sy02 memos (b)Documented in SYsy0 I memos (c) Only in outdated studies (d) Applicable documents are connected to parameters, basic events or gates within Risk Spectrum (e) Not included (f)Documented in 13-NS-B061 (g) Documented in 13-NS-B061 (h) Procedures are connected to basic events where the periodicity of a procedure is the basis for the test interval applied (i) System dependencies are documented in 13-NS-B061.
System interfaces are documented in SYsy0 1 memos. (j) Not included (k) Documented in SY syxx memos (1) Documented in SYsyxx memos (in) not applicable (n) Documented in SY-syxx memos. Also the dependency matrix in 13-NS-B061 App. B shows these inter-dependencies. (o) Not included (p) No sensitivity studies performed on system modeling (q)Documents used in system modeling are referenced and linked to basic events and gates (r) Basic events appear in cutsets (s)Nomenclature is defined in procedure 70DP-ORA03. The following subsections are considered not to meet the SR: c, e, j, o, p.Elements of this SR are addressed in various documents.
However, there is no single document that captures all of the elements.Those sub elements listed as "not met" are addressed as follows: (c) The lack of a schematic is not a material deficiency; no impact. (e) During 25 years of plant operation (75 reactor years), system problems have been identified, documented and addressed through the Corrective Action Program. Necessary modeling changes are tracked and implemented through the PRA impact process. Also, plant-specific failure data and unavailability are used in updating the PRA model on a periodic basis, so PRA results reflect operating history; no significant impact. (j)Spatial information of components is not specifically documented, but is considered regarding environmental conditions following an event. This is included in paragraphs (d) and (g); no impact. (o) There was no systematic evaluation of record that was performed for single systems.However, after numerous model updates, enhancements, NRC significance determinations and PRA applications, it is unlikely that significant problems would be identified by such evaluations.
No significant impact. (p) No sensitivity studies have been performed regarding system modeling and its effect on the base case PRA. No significant impact on base case model.
Attachment 3 Proposed Technical Specification Changes (Based on Amendment 184)Pages 3.1.1-1 3.3.6-3 3.4.15-2 3.7.7-2 3.8.3-3 3.1.2-2 3.3.7-3 3.4.15-3 3.7.8-2 3.8.4-2 3.1.3-2 3.3.8-2 3.4.16-2 3.7.9-1 3.8.4-3 3.1.5-3 3.3.8-3 3.4.16-3 3.7.10-1 3.8.4-4 3.1.6-2 3.3.9-2 3.4.17-2 3.7.11-3 3.8.6-2 3.1.7-3 3.3.9-3 3.4.17-3 3.7.12-2 3.8.6-3 3.1.8-2 3.3.10-3 3.5.1-2 3.7.13-1 3.8.7-2 3.1.9-2 3.3.11-2 3.5.2-2 3.7.13-2 3.8.8-2 3.1.10-2 3.3.12-3 3.5.2-3 3.7.14-1 3.8.9-2 3.2.1-2 3.4.1-2 3.5.3-2 3.7.15-2 3.8.10-2 3.2.2-2 3.4.2-1 3.5.3-3 3.7.16-1 3.9.1-1 3.2.3-3 3.4.3-2 3.5.5-2 3.8.1-6 3.9.2-2 3.2.4-2 3.4.4-1 3.5.6-1 3.8.1-7 3.9.3-2 3.2.5-1 3.4.5-2 3.6.2-4 3.8.1-8 3.9.4-2 3.3.1-3 3.4.6-2 3.6.3-5 3.8.1-9 3.9.5-2 3.3.1-4 3.4.6-3 3.6.3-6 3.8.1-10 3.9.6-1 3.3.1-5 3.4.7-3 3.6.4-1 3.8.1-11 3.9.7-1 3.3.1-6 3.4.8-2 3.6.5-1 3.8.1-12 5.5-17 3.3.2-3 3.4.9-2 3.6.6-2 3.8.1-13 Insert 3.3.2-4 3.4.11-2 3.7.4-2 3.8.1-14 3.3.3-4 3.4.12-1 3.7.5-3 3.8.1-15 3.3.4-3 3.4.13-3 3.7.5-4 3.8.1-16 3.3.5-3 3.4.14-2 3.7.6-1 3.8.1-17 SDM -Reactor Trip Breakers Open 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM) -Reactor Trip Breakers Open LCO 3.1.1 APPLICABILITY:
SDM shall be the value in the COLR.MODES 3, 4, and 5 with the Reactor Trip Breakers Open or the CEA drive system not capable of CEA withdrawal.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Initiate boration to 15 minutes restore SDM to within limit.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM is _> the value in the COLR.-24. <- =PALO VERDE UNITS 1,2,3 3.1.1-1 AMENDMENT NO. 1-17 SDM -Reactor Trip Breakers Closed 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 Verify SDM is > the value in the COLR.SR 3.1.2.2 -----------------
NOTE--------------
Only required if Tc <- 500 0 F.A-24. <24~hIa <- Isr:24A-he--
<s Verify KN.1 < 0.99.SR 3.1.2.3 Verify criticality cannot be achieved with shutdown group CEA movement.PALO VERDE UNITS 1,2,3 3.1.2-2 AMENDMENT NO. 147-Reactivity Balance 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 -----------------
NOTES--------------
The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days (EFPD) after each fuel loading.Verify overall core reactivity balance is within +/- 1.0% Ak/k of predicted values.Prior to entering MODE 1 after fuel loading AND----- NOTE -----Only required after 60 EFPD 3!EFPQ 4- Insert i, PALO VERDE UNITS 1,2,3 3.1.3-2 AMENDMENT NO. 14r7 CEA Alignment 3.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY i SR 3.1.5.1 Verify the indicated position of each full strength and part strength CEA is within 6.6 inches of all other CEAs in its group.SR 3.1.5.2 Verify that, for each CEA, its OPERABLE CEA position indicator channels indicate within 5.2 inches of each other.4 1-2 h o -- -& 1 -1:2 h-whe <92 days h&SR 3.1.5.3 Verify full strength CEA freedom of movement (trippability) by moving each individual full strength CEA that is not fully inserted in the core at least 5 inches.SR 3.1.5.4 Perform a CHANNEL FUNCTIONAL TEST of each reed switch position transmitter channel.SR 3.1.5.5 Verify each full strength CEA drop time Prior to 4.0 seconds. reactor criticality, after each removal of the reactor head PALO VERDE UNITS 1,2,3 3.1.5-3 AMENDMENT NO. 152, !79 Shutdown CEA Insertion Limits 3.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify each shutdown CEA is withdrawn> 147.75 inches.1-2-hu PALO VERDE UNITS 1,2,3 3.1.6-2 AMENDMENT NO. 117, 168 Regulating CEA Insertion Limits 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 1*SR 3.1.7.1 -----------------
NOTE---------------
This Surveillance is not required to be performed prior to entry into MODE 2.Verify each regulating CEA group position is within its insertion limits.SR 3.1.7.2 Verify the accumulated times during which the regulating CEA groups are inserted beyond the steady state insertion limits but within the transient insertion limits.12 h-hrer,<s 24 hew&< fn -e-t 1 31 dayLs SR 3.1.7.3 Verify PDIL alarm circuit is OPERABLE.PALO VERDE UNITS 1,2,3 3.1.7-3 AMENDMENT NO. 44-7 Part Strength CEA Insertion Limits 3.1.8 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 Verify part strength CEA group position.12h- Insert I PALO VERDE UNITS 1,2,3 3.1.8-2 AMENDMENT NO. 152, 179 STE-SDM 3.1.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 4 SR 3.1.9.1 Verify that the position of each CEA not fully inserted is within the acceptance criteria for available negative reactivity addition.2 hei-.& E- Isr SR 3.1.9.2 Verify each full strength CEA not fully Within 7 days inserted is capable of full insertion when prior to tripped from at least the 50% withdrawn reducing SDM position.
requirements to less than the limits of LCO 3.1.2 SR 3.1.9.3 -----------------
NOTE--------------
Only required to be performed in Mode 3.Verify that with all full strength CEAs fully inserted, the reactor is subcritical within the acceptance criteria.2 h-wh g <PALO VERDE UNITS 1,2,3 3.1.9-2 AMENDMENT NO. 117, 162 STE -MODES 1 and 2 3.1.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.10.1 Verify THERMAL POWER equal to or less than the test power plateau.SR 3.1.10.2 Verify that the position of each CEA not fully inserted is within the acceptance criteria for available negative reactivity addition.2 Insert 1 PALO VERDE UNITS 1,2,3 3.1.10-2 AMENDMENT NO. 14r; 1-69 LHR 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1---------------
NOTE---------------
- 1. Only applicable when COLSS is out of service. With COLSS in service, LHR is continuously monitored.
- 2. Not required to be performed until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after MODE 1 with THERMAL POWER> 20% RTP.Verify LHR, local power limits.as indicated on any OPERABLE density channel, is within its 2 h-hei- <- Isr 31 days <-ýý1 SR 3.2.1.2 Verify the COLSS margin alarm actuates at a THERMAL POWER equal to or less than the core power operating limit based on LHR.PALO VERDE UNITS 1,2,3 3.2.1-2 AMENDMENT NO. 44-7 3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify measured Fy obtained using the Incore Detector System is equal to or less than the value of F' used in the COLSS and CPCs.Once after each fuel loading with THERMAL POWER > 40% RTP but prior to operations above 70% RTP AND 3!eF-PDa r Inser 1 PALO VERDE UNITS 1,2,3 3.2.2-2 AMENDMENT NO. 4-1.7 Tq 3.2.3ýSURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 -----------------
NOTES--------------
- 1. Only applicable when COLSS is out of service. With COLSS in service, this parameter is continuously monitored.
- 2. Not required to be performed until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after MODE 1 with THERMAL POWER > 20% RTP.Calculate Tq and verify it is within the limit.SR 3.2.3.2 Verify COLSS azimuthal tilt alarm is actuated at a Tq value less than the value used in the CPCs.12-hemps <- Isr 31 day- <-ý1 21 UP0 <- Isr T SR 3.2.3.3 Independently confirm the validity of the COLSS calculated Tq by use of the incore detectors.
PALO VERDE UNITS 1,2,3 3.2.3-3 AMENDMENT NO. 144 DNBR 3.2.4 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. DNBR outside the B.1 Determine trend in DNBR. Once per region of acceptable AND 15 minutes operation when COLSS is out of service. B.2.1 With an adverse trend, restore DNBR I hour to within limit.OR B.2.2 With no adverse 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> trend, restore DNBR to within limit.C. Required Action and C.1 Reduce THERMAL POWER 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion to 20% RTP.Time not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 -----------------
NOTE----------------
- 1. Only applicable when COLSS is out of service. With COLSS in service, this parameter is continuously monitored.
- 2. Not required to be performed until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after MODE 1 with THERMAL POWER > 20% RTP.Verify DNBR, as indicated on any OPERABLE DNBR channels, is within the limit of the COLR, as applicable.
2 -hers -Insert 1I 31 days&SR 3.2.4.2 Verify COLSS margin alarm actuates at a THERMAL POWER level equal to or less than the core power operating limit based on DNBR.PALO VERDE UNITS 1,2,3 3.2.4-2 AMENDMENT NO. 159, 179 ASI 3.2.5 3.2 POWER DISTRIBUTION LIMITS 3.2.5 AXIAL SHAPE INDEX (ASI)LCO 3.2.5 APPLICABILITY:
ASI shall be within the limits specified in the COLR.MODE 1 with THERMAL POWER > 20% RTP.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Core average ASI not A.1 Restore ASI to within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> within limits, limits.B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion to 20% RTP.Time not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.5.1 -----------------
Notes--------------
Not required to be performed until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after MODE 1 with THERMAL POWER > 20% RTP.Verify ASI is within limits.12 h--hew <&PALO VERDE UNITS 1,2,3 3.2.5-1 AMENDMENT NO. 444 RPS Instrumentation
-Operating 3.3.1 SURVEILLANCE REQUIREMENTS
NOTE ----------------------------
Refer to Table 3.3.1-1 to determine which SR shall be performed for each RPS Function.SURVEILLANCE FREQUENCY 4 SR 3.3.1.1 Perform a CHANNEL CHECK of each RPS instrument channel.SR 3.3.1.2 -----------------
NOTE--------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER 70% RTP.Verify total Reactor Coolant System (RCS)flow rate as indicated by each CPC is less than or equal to the RCS total flow rate.If necessary, adjust the CPC addressable constant flow coefficients such that each CPC indicated flow is less than or equal to the RCS flow rate.12-e~12-h~12-hours, -Iner SR 3.3.1.3 Check the CPC System Event Log.(continued)
PALO VERDE UNITS 1,2,3 3.3.1-3 AMENDMENT NO. 159, 179 RPS Instrumentation
-Operating 3.3.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.1.4--- --- --- --- ---NOTES--------------
- 1. Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER 20% RTP.2. The daily calibration may be suspended during PHYSICS TESTS, provided the calibration is performed upon reaching each major test power plateau and prior to proceeding to the next major test power plateau.Perform calibration (heat balance only) and adjust the linear power level signals and the CPC addressable constant multipliers to make the CPC AT power and CPC nuclear power calculations agree with the calorimetric, if the absolute difference is 2% when THERMAL POWER is 80% RTP. Between 20%and 80% RTP the maximum difference is -0.5%to 10%.24 A-rh1;31-days -~SR 3.3.1.5------ ------ -----NOTE ---------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER 70% RTP.Verify total RCS flow rate indicated by each CPC is less than or equal to the RCS flow determined either using the reactor coolant pump differential pressure instrumentation and the ultrasonic flow meter adjusted pump curves or by calorimetric calculations.(continued)
PALO VERDE UNITS 1,2,3 3.3.1-4 AMENDMENT NO. 159, !79 RPS Instrumentation
-Operating 3.3.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.1.6 -----------------
NOTE--------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER 15% RTP.Verify linear power subchannel gains of the excore detectors are consistent with the values used to establish the shape annealing matrix elements in the CPCs.31 days i SR 3.3.1.7----------------
NOTES--------------
- 1. The CPC CHANNEL FUNCTIONAL TEST shall include verification that the correct values of addressable constants are installed in each OPERABLE CPC.2. Not required to be performed for logarithmic power level channels until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after reducing logarithmic power below 1E-4% NRTP.Perform CHANNEL FUNCTIONAL TEST on each channel.+SR 3.3.1.8----------------
NOTE Neutron detectors are excluded from the CHANNEL CALIBRATION.
92 days <Perform CHANNEL CALIBRATION of range neutron flux channels.the power (continued)
PALO VERDE UNITS 1,2,3 3.3.1-5 AMENDMENT NO. 159, 179 RPS Instrumentation
-Operating 3.3.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY 4 SR 3.3.1.9 --------------------
NOTE Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION on each channel, including bypass removal functions.
8- mnths&SR 3.3.1.10 Perform a CHANNEL FUNCTIONAL TEST on each CPC channel.I8-months
- - Isr SR 3.3.1.11 Using the incore detectors, verify the Once after each shape annealing matrix elements to be used refueling prior by the CPCs. to exceeding 70% RTP SR 3.3.1.12 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal function.
92 days prior to each reactor startup SR 3.3.1.13---------------N O T E ----------Neutron detectors are excluded.Verify RPS RESPONSE TIME is within limits.18 MonthA on a STAGE-REDDD TEST BASIS61$6 6 PALO VERDE UNITS 1,2,3 3.3.1-6 AMENDMENT NO. 150, !79 RPS Instrumentation
-Shutdown 3.3.2 SURVEILLANCE REQUIREMENTS
NOTE -----------------------------
Refer to Table 3.3.2-1 to determine which SR shall be performed for each RPS function.SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform a CHANNEL CHECK of each RPS instrument channel.3 he--'-S SR 3.3.2.2 Perform a channel.CHANNEL FUNCTIONAL TEST on each 92-day <SR 3.3.2.3 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal function.
92 days prior to each reactor startup SR 3.3.2.4----------------
NOTE---------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform a CHANNEL CALIBRATION on each channel, including bypass removal function.I-R- ment-146 <-=(continued)
PALO VERDE UNITS 1,2,3 3.3.2-3 AMENDMENT NO. 447 RPS Instrumentation
-Shutdown 3.3.2 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY-NOTE---------------4 SR 3.3.2.5---------------N O T E ----------Neutron detectors are excluded.Verify RPS RESPONSE TIME is within limits.18 months ona STA-DERED TOST R A -S I S In s ~e rt1 J.PALO VERDE UNITS 1,2,3 3.3.2-4 AMENDMENT NO. 414 CEACs 3.3.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY+SR 3.3.3.1 Perform a CHANNEL CHECK.42-hei~& *- Insert I SR 3.3.3.2 Deletedf SR 3.3.3.3 Perform a CHANNEL FUNCTIONAL TEST.92 ays<&SR 3.3.3.4 Perform a CHANNEL CALIBRATION.
18 Ronths SR 3.3.3.5 Perform a CHANNEL FUNCTIONAL TEST.1 8 menl'h&PALO VERDE UNITS 1,2,3 3.3.3-4 AMENDMENT NO. 159, 179 RPS Logic and Trip Initiation 3.3.4 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A, AND B, or D not met.E.2 Open all RTCBs. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> OR One or more Functions with more than one Manual Trip, Matrix Logic, Initiation Logic, or RTCB channel inoperable for reasons other than Condition A or D.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform a CHANNEL FUNCTIONAL TEST on each RPS Logic channel and Manual Trip channel.92--- Insert 11 SR 3.3.4.2 Perform a CHANNEL FUNCTIONAL TEST, including separate verification of the undervoltage and shunt trips, on each RTCB.~1*SR 3.3.4.3 Perform RTCB.a CHANNEL FUNCTIONAL TEST on each 1 ..Insert 11 PALO VERDE UNITS 1,2,3 3.3.4-3 AMENDMENT NO. -14W ESFAS Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 Perform a CHANNEL CHECK of each ESFAS channel.12 dha's <--InsertlI 9<dy -- Insert 11-1~SR 3.3.5.2 Perform a CHANNEL FUNCTIONAL TEST of each ESFAS channel..1.SR 3.3.5.3 Perform a CHANNEL CALIBRATION of each ESFAS channel, including bypass removal functions.
Ig-MeRthq 1-SR 3.3.5.4 Verify ESF RESPONSE TIME is within limits.STAEREDE TEST SR 3.3.5.5 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal channel. 92 days prior to each reactor startup PALO VERDE UNITS 1,2,3 3.3.5-3 AMENDMENT NO. 44-7 ESFAS Logic and Manual Trip 3.3.6 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Conditions for AND Safety Injection Actuation Signal, F.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Containment Isolation Actuation Signal, or Reci rcul ati on Actuation Signal not met..SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.6.1 -----------------
NOTE---------------
Testing of Actuation Logic shall include the verification of the proper operation of each initiation relay.Perform a CHANNEL FUNCTIONAL TEST on each ESFAS logic channel and Manual Trip channel.SR 3.3.6.2 -----------------
NOTE---------------
Relays exempt from testing during operation shall be tested each 18 months.9-2 Inse <l 9 months on a STAGGERED TET Perform a subgroup relay test of each Actuation Logic channel, which includes the de-energization of each subgroup relay and verification of the OPERABILITY of each subgroup relay.PALO VERDE UNITS 1,2,3 3.3.6-3 AMENDMENT NO. 4-14 DG -LOVS 3.3.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK.1 -2he~ A_ InsPe&t i SR 3.3.7.2 Perform CHANNEL FUNCTIONAL TEST.1g months SR 3.3.7.3 Perform CHANNEL CALIBRATION with setpoint Allowable Values as follows: a. Degraded Voltage Function 3786 V 3697 V and Time delay: 28.6 seconds and 35 seconds; and b. Loss of Voltage Function Time delay: 10.3 seconds and12.6 seconds at 2929.5 V. and2.0 seconds and 2.4 seconds at 0 V.PALO VERDE UNITS 1,2,3 3.3.7-3 AMENDMENT NO. 11ý, 123 CPIAS 3.3.8 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. CPIAS Manual Trip, C.1 Place and maintain Immediately Actuation Logic, or containment purge and radiation monitor exhaust valves in inoperable during CORE closed position.ALTERATIONS or movement of irradiated OR fuel assemblies within containment.
C.2.1 Suspend CORE Immediately ALTERATIONS.
AND C.2.2 Suspend movement of Immediately irradiated fuel assemblies in containment.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.1 Perform a CHANNEL CHECK on required radiation monitor channel.SR 3.3.8.2 Perform a CHANNEL FUNCTIONAL TEST on each required radiation monitor channel, and Verify the setpoint 2.5 mR/hr.92 days <- Isr I R MAn~t SR 3.3.8.3 ----------------
NOTE---------------
Surveillance of Actuation Logic shall include the verification of the proper operation of each actuation relay.Perform a CHANNEL FUNCTIONAL TEST on required CPIAS Actuation Logic channel.(continued)
PALO VERDE UNITS 1,2,3 3.3.8-2 AMENDMENT NO. 1-1-7 CPIAS 3.3.8 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.8.4 Perform a CHANNEL CALIBRATION on required radiation monitor channel.I8-i~nthq
&SR 3.3.8.5 Perform CHANNEL FUNCTIONAL TEST on required CPIAS Manual Trip channel.PALO VERDE UNITS 1,2.3 3.3.8-3 AMENDMENT NO. 4-14 CREFAS 3.3.9 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. CREFAS Manual Trip, C.1 Place one CREFS train Immediately Actuation Logic, or in operation.
radiation monitor inoperable in MODE 5 OR or 6, or during movement of irradiated C.2.1 Suspend movement of Immediately fuel assemblies, irradiated fuel assemblies.
AND C.2.2 Suspend positive Immediately reactivity additions.
AND C.2.3 Suspend CORE Immediately ALTERATIONS.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.9.1 Perform a CHANNEL CHECK on the required control room radiation monitor channel.42-he~s (continued)
PALO VERDE UNITS 1,2,3 3.3.9-2 AMENDMENT NO. 144 CREFAS 3.3.9 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.9.2 Perform a CHANNEL FUNCTIONAL TEST on required CREFAS radiation monitor channel.Verify CREFAS high radiation setpoint is< 2 x 10- pCi/cc.SR 3.3.9.3--------------
--NOTES---------------
- 1. Surveillance of Actuation Logic shall include the verification of the proper operation of each Actuation relay.2. Relays associated with plant equipment that cannot be operated during plant operation are required to be tested during each MODE 5 entry exceeding 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> unless tested within the previous 6 months.Perform a CHANNEL FUNCTIONAL TEST on required CREFAS Actuation Logic channel.92-dah 4- Insert 1ay!8 MAnths ner i SR 3.3.9.4 Perform a CHANNEL CALIBRATION on required CREFAS radiation monitor channel.SR 3.3.9.5 Perform a CHANNEL FUNCTIONAL TEST on required CREFAS Manual Trip channel.1R meRthA SR 3.3.9.6 Verify that response time of required CREFAS channel is within limits.18 m Dnths 9T a STAGGERED TEST PALO VERDE UNITS 1,2,3 3.3.9-3 AMENDMENT NO. 447-PAM Instrumentation 3.3.10 SURVEILLANCE REQUIREMENTS
NOTE ----------------------------
These SRs apply to each PAM instrumentation Function in Table 3.3.10-1.SURVEILLANCE FREQUENCY SR 3.3.10.1 Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.
+SR 3.3.10.2---- ---- ---- ----NOTE--------------
Neutron detectors are excluded from the CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION.
1--Insert 1!- mer, th4 <-Is 1 PALO VERDE UNITS 1,2,3 3.3.10-3 AMENDMENT NO. 4-14 Remote Shutdown System 3.3.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 1-SR 3.3.11.1 Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.
SR 3.3.11.2 Verify each required control circuit and transfer switch is capable of performing the intended function.1A months <-- Insert 1!8 mRths <------ 1&SR 3.3.11.3---- ---- ---- ----NOTE --------------
Neutron detectors are excluded from the CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION for each required instrumentation channel.PALO VERDE UNITS 1,2,3 3.3.11-2 AMENDMENT NO. 44-7 Boron Dilution Alarm System (BDAS)3.3.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY-------------------
NOTE-------------
SR 3.3.12.1 Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after neutron flux is within the startup range.Perform CHANNEL CHECK.4.----------------------
NOTE-------------
SR 3.3.12.2 Not required to be performed until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after neutron flux is within the startup range.Perform CHANNEL FUNCTIONAL TEST.!2 ho'-rs Isr 44ii. -Insert lI!92-d nth Insert 1<48Men~t SR 3.3.12.3 ------------------
NOTE----------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION.
PALO VERDE UNITS 1,2,3 3.3.12-3 AMENDMENT NO. 4-1; RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. Pressurizer pressure C.1 Restore parameter(s) 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> or RCS cold leg to within limits.temperature not within limits.D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition C not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure 2130< 2295 psia.psia and 12 h -Insert I I SR 3.4.1.2 Verify RCS cold leg temperature within limits as shown in Figure 3.4.1-1.SR 3.4.1.3 ----------------
NOTE Required to be met in MODE 1 with all RCPs running.32 heur-s 12 h--re.q Verify RCS total flow rate> 155.8 E6 lbm/hour.PALO VERDE UNITS 1,2,3 3.4.1-2 AMENDMENT NO. 1-14 RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 Each RCS loop temperature (TCOld) shall be _> 545°F.APPLICABILITY:
MODE 1, MODE 2 with Keff > 1.0.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Tcold in one or more A.1 Be in MODE 3. 30 minutes RCS loops not within limit.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 Verify RCS Tcold in each loop _> 545 0 F.------ NOTE -----Only required if any RCS loop Tcold < 550 0 F.30 i.- t -[Is r1!AND Once within 30 minutes prior to reaching criticality PALO VERDE UNITS 1,2,3 3.4.2-1 AMENDMENT NO. 14 RCS P/T Limits 3.4.3 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. NOTE --------C.1 Initiate action to Immediately Required Action C.2 restore parameter(s) shall be completed to within limits.whenever this Condition is entered. AND C.2 Determine RCS is Prior to Requirements of LCO acceptable for entering MODE 4 not met any time in continued operation.
other than MODE 1, 2, 3, or 4.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 ---------------
NOTE---------------
Only required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing.Verify RCS pressure, RCS temperature, and RCS heatup and cooldown rates within limits specified in the PTLR.30- m4inwe<-PALO VERDE UNITS 1,2,3 3.4.3-2 Amendment No. 117, 178 RCS Loops -MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.4 RCS Loops -MODES 1 and 2 LCO 3.4.4 Two RCS loops shall be OPERABLE and in operation.
APPLICABILITY:
MODES 1 and 2.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of LCO A.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation.
42-he~&PALO VERDE UNITS 1,2,3 3.4.4-1 AMENDMENT NO. 4-9 RCS Loops -MODE 3 3.4.5 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. No RCS loop OPERABLE.
C.1 Suspend all Immediately operations involving OR a reduction of RCS boron concentration.
No RCS loop in operation.
AND C.2 Initiate action to Immediately restore one RCS loop to OPERABLE status and operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loop is in operation.
SR 3.4.5.2 Verify secondary side water steam generator
_> 25%.level in each!.2-heI'-r 4-1 Insert 1I<~d3L -! Insert 1I SR 3.4.5.3 Verify correct breaker alignment indicated power available to the pump that is not in operation.
and required PALO VERDE UNITS 1,2,3 3.4.5-2 AMENDMENT NO. 144 RCS Loops -MODE 4 3.4.6 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. One required SDC train B.1 Be in MODE 5. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> inoperable.
AND Two required RCS loops inoperable.
C. No RCS loop or SDC C.1 Suspend all Immediately train OPERABLE.
operations involving reduction of RCS OR boron concentration.
No RCS loop or SDC AND train in operation.
C.2 Initiate action to Immediately restore one loop or train to OPERABLE status and operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RCS loop or operation.
SDC train is in 12-hewp&1 he~~ 0- Iner FI+SR 3.4.6.2 Verify secondary side water level in required SG(s) is 25%.(continued)
PALO VERDE UNITS 1,2,3 3.4.6-2 AMENDMENT NO. -IýW RCS Loops -MODE 4 3.4.6 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.4.6.3 Verify correct breaker alignment and indicated power available to the required pump that is not in operation.
7 days -PALO VERDE UNITS 1,2,3 3.4.6-3 AMENDMENT NO. 44-7 RCS Loops -MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one SDC train is in operation.
.4 SR 3.4.7.2 Verify required SG secondary side water level is _> 25%.7 days -~SR 3.4.7.3 Verify correct breaker alignment and indicated power available to the required SDC pump that is not in operation.
PALO VERDE UNITS 1,2,3 3.4.7-3 AMENDMENT NO. 11,1 RCS Loops -MODE 5, Loops Not Filled 3.4.8 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. Required SDC trains B.1 Suspend all Immediately inoperable, operations involving reduction of RCS OR boron concentration.
No SDC train in AND operation.
B.2 Initiate action to Immediately restore one SDC train to OPERABLE status and operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one SDC train is in operation.
4.12-hewmg 7-4aY&SR 3.4.8.2 Verify correct breaker alignment and indicated power available to the required SDC pump that is not in operation.
PALO VERDE UNITS 1,2,3 3.4.8-2 AMENDMENT NO. 114 Pressurizer 3.4.9 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition B AND not met.C.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water< 56%level is _> 27% and 92-days <-1 SR 3.4.9.2 Verify capacity of each required group of pressurizer heaters 125 kW.PALO VERDE UNITS 1,2,3 3.4.9-2 AMENDMENT NO. 44 Pressurizer Safety Valves-MODE 4 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 Verify the required pressurizer safety In accordance valve is OPERABLE in accordance with the with the Inservice Testing Program. Following Inservice testing, lift settings shall be within Testing Program+/- 1%.SR 3.4.11.2-----------------
NOTE--------------
Only required to be performed when a Shutdown Cooling System suction line relief valve is being used for overpressure protection.
Verify the required Shutdown Cooling System suction line relief valve is aligned to provide overpressure protection for the RCS.12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> fo unloked, Rnet sealed, e see'-red epeR AND-lockcd, sealed, ptway vent-valve.. j s) , SR 3.4.11.3 Verify the required Shutdown Cooling System In accordance suction line relief valve is OPERABLE with with the the required setpoint.
Inservice Testing Program PALO VERDE UNITS 1,2,3 3.4.11-2 AMENDMENT NO. 44-7 Pressurizer Vents 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.12 Pressurizer Vents LCO 3.4.12 APPLICABILITY:
Four pressurizer vent paths shall be OPERABLE.MODES 1, 2, and 3.MODE 4 with RCS pressure 385 psia.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Two or three required A.1 Restore required 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> pressurizer vent paths pressurizer vent inoperable, paths to OPERABLE status.B. All pressurizer vent B.1 Restore one 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> paths inoperable, pressurizer vent path to OPERABLE status.C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A, AND or B not met.C.2 Be in MODE 4 with RCS 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> pressure < 385 psia.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Perform a complete cycle of each Pressurizer Vent Valve.4----Insert 1I SR 3.4.12.2 Verify flow through each pressurizer vent path.1 -m-Ihs<-ýnsýert 1 ýPALO VERDE UNITS 1.2,3 3.4.12-1 AMENDMENT NO. 4-14 LTOP System 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 Verify RCS Vent 16 square inches is open.12 hou-r-1 for-uneocked, not other",oise not 6eeedepen-
~cntpa h way s)AND-31 days,- locked, sealed, or otherms oe~e-pen-vet a thway4 s)4 SR 3.4.13.2 Verify each Shutdown Cooling.System suction line relief valve is aligned to provide overpressure protection for the RCS.12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />sg for sea! ed,-~Athppwisc not t-* AND--,1,days for-19ockcd, eld or otherwis seeurea- open-SR 3.4.13.3 Verify each Shutdown Cooling System In accordance suction line relief valve is OPERABLE with the with the required setpoint.
Inservice Testing Program.PALO VERDE UNITS 1,2,3 3.4.13-3 AMENDMENT NO. 4-1ý-
RCS Operational LEAKAGE 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 -----------------
NOTES--------------
- 1. Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after establishment of steady state operation.
- 2. Not applicable to primary to secondary LEAKAGE Perform RCS water inventory balance.72 ho'rs -Insert 1 SR 3.4.14.2---------------
NOTE- -------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after establishment of steady state operation.
Verify primary to secondary LEAKAGE is 150 gallons per day through any one SG.72 hoer PALO VERDE UNITS 1,2,3 3.4.14-2 AMENDMENT NO. 117, 161 RCS PIV Leakage 3.4.15 ACTIONS (Continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time for Condition A AND not met.B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1----------------
NOTES--------------
- 1. Not required to be performed in MODES 3 and 4.2. Not required to be performed on the RCS PIVs located in the SDC flow path when in the shutdown cooling mode of operation.
- 3. RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided.Verify leakage from each RCS PIV is equivalent to 0.5 gpm per nominal valve size up to a maximum of 5 gpm RCS pressure 2230 psia and 2270 inch of at an psia.1A mnthD AND Prior to entering MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months, except for SDC PIVs AND (continued)
PALOVERDE UNITS 1,2.3 3.4.15-2 AMENDMENT NO. 44.7 RCS PIV Leakage 3.4.15 SURVEILLANCE REQUIREMENTS (Continued)
SURVEILLANCE FREQUENCY SR 3.4.15.1 (continued)
Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> following valve actuation due to automatic or manual action or flow through the valve, except for SDC PIVs.i SR 3.4.15.2 Verify SDC System open permissive interlock prevents the valves from being opened with a simulated or actual RCS pressure signal> 410 psia.I8mR Mnhq s PALO VERDE UNITS 1,2,3 3.4.15-3 AMENDMENT NO. 117-RCS Leakage Detection Instrumentation 3.4.16 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. Required containment B.1.1 Analyze grab samples Once per atmosphere of the containment 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> radioactivity monitor atmosphere.
OR B.1.2 Perform SR 3.4.14.1.
Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> AND B.2 Restore required 30 days containment atmosphere radioactivity monitor to OPERABLE status.C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> D. All required monitors D.1 Enter LCO 3.0.3 Immediately inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Perform CHANNEL CHECK of the required containment atmosphere radioactivity monitor.1:2 i-rhe <s 92 days <-ýi SR 3.4.16.2 Perform CHANNEL FUNCTIONAL TEST of the required containment atmosphere radioactivity monitor.(continued)
PALO VERDE UNITS 1.2,3 3.4.16-2 AMENDMENT NO. 11ý, 165 RCS Leakage Detection Instrumentation 3.4.16 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.4.16.3 Perform CHANNEL CALIBRATION of the required containment sump monitor.13-mn thR SR 3.4.16.4 Perform CHANNEL CALIBRATION of the required containment atmosphere radioactivity monitor.I RmeR~hA PALO VERDE UNITS 1,2,3 3.4.16-3 AMENDMENT NO. -14W RCS Specific Activity 3.4.17 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3 with 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Tcold< 500 0 F.Time of Condition A not met.OR DOSE EQUIVALENT 1-131 in the unacceptable region of Figure 3.4.17-1.C. Gross specific C.1 Perform SR 3.4.17.2.
4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> activity of the reactor coolant not AND within limit.C.2 Be in MODE 3 with 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Tcold < 500 0 F.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify reactor coolant gross specific activity _< 100/E pCi/gm.7 days <(continued)
PALO VERDE UNITS 1,2,3 3.4.17-2 AMENDMENT NO. 444 RCS Specific Activity 3.4.17 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE I FREQUENCY SR 3.4.17.2 Verify reactor coolant DOSE EQUIVALENT 1-131 specific activity< 1.0 pCi/gm.------ NOTE ------Only required to be performed in MODE 1.AND Between 2 and 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after THERMAL POWER change of 15% RTP within a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period SR 3.4.17.3-------- -------NOTE-------------
Not required to be performed until 31 days after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />.Determine E from a sample taken in MODE 1 after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />.184 days <-ýý1 PALO VERDE UNITS 1,2,3 3.4.17-3 AMENDMENT NO. 1-1,1 SITs-Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each SIT isolation valve is fully open.SR 3.5.1.2 Verify borated water volume in each SIT is> 28% narrow range and 72% narrow range.SR 3.5.1.3 Verify nitrogen cover pressure in each SIT is 600 psig and 625 psig.SR 3.5.1.4 Verify boron concentration
> 2300 ppm and 4400 ppm.in each SIT is 12 ho'r-r, 12 hm'-rs --- Is r AND----- NOTE ------Only required to be performed for affected SIT Once within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, whenever a SIT is drained to maintain the contained borated water level within the limits of SR 3.5.1.2.SR 3.5.1.5 Verify power is removed from each SIT isolation valve operator.31-day& -PALO VERDE UNITS 1,2,3 3.5.1-2 AMENDMENT NO. -14W SITs-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify each required SIT isolation valve is fully open when pressurizer pressure is> 430 psia.12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />s+SR 3.5.2.2 Verify borated water volume in each required SIT is: a. For four OPERABLE SITs, > 39% wide range indication and < 83% wide range indication.
OR b. For three OPERABLE SITs, >range indication and < 83%indication.
60% wide wide range!.2 he'-rs <-1 Insert 1 ai dayrs <---nsrI AND. -Insert 1 AND SR 3.5.2.3 Verify nitrogen cover pressure in each required SIT is 260 psig and 625 psig.SR 3.5.2.4 Verify boron concentration in each required SIT is 2300 ppm and ! 4400 ppm.----- NOTE ------Only required to be performed for affected SIT Once within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, whenever a required SIT is drained to maintain the contai ned borated water level within the limits of SR 3.5.2.2.(continued)
PALO VERDE UNITS 1,2,3 3.5.2-2 AMENDMENT NO. 4-14 SITs-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify power is removed from each required SIT isolation valve operator when pressurizer pressure is 1500 psia.PALO VERDE UNITS 1,2,3 3.5.2-3 AMENDMENT NO. 4ý-
ECCS -Operating 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify each ECCS 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.,4 da... <- Insert I i SR 3.5.3.2 Verify ECCS piping is full of water.31 ays<&SR 3.5.3.3 Verify each ECCS pump develops the required In accordance differential pressure at the flow test with the point. Inservice Testing Program SR 3.5.3.4 Verify each ECCS automatic valve that is not locked, sealed, or otherwise secured in position, in the flow path actuates to the correct position on an actual or simulated actuation signal.8AmoRths, SR 3.5.3.5 Verify each ECCS pump starts automatically on an actual or simulated actuation signal 8-months 4- Insert 1]SR 3.5.3.6 Verify each LPSI pump stops simulated actuation signal.on an actual or 19 months (continued)
PALO VERDE UNITS 1,2,3 3.5.3-2 AMENDMENT NO. 4-14 ECCS -Operating 3.5.3 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.5.3.7 Verify, for each ECCS throttle valve listed below, each position stop is in the correct position.LPSI System Valve Number Hot Leg Injection Valve Numbers SIB-UV SIB-UV SIA-UV SIA-UV SIA-HV SIB-HV 615 625 635 645 306 307 SIC-HV 321 SID-HV 331 I4 -At'h 18-Rmenths SR 3.5.3.8 Verify, by visual inspection, each ECCS train containment sump suction inlet is not restricted by debris and the suction inlet strainers show no evidence of structural distress or abnormal corrosion.
PALO VERDE UNITS 1,2,3 3.5.3-3 AMENDMENT NO. 117, 179 RWT 3.5.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 -----------------
NOTE--------------
Only required to be performed when ambient air temperature is < 60°F or > 120 0 F.Verify RWT borated water temperature is>60°F and 120 0 F.i SR 3.5.5.2 Verify RWT borated water volume is> minimum required RWT volume in Figure 3.5.5-1.24 h--her <7 days 7 days -SR 3.5.5.3 Verify RWT boron concentration is4000 ppm and 4400 ppm.PALO VERDE UNITS 1,2,3 3.5.5-2 AMENDMENT NO. 144 TSP 3.5.6 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)3.5.6 Trisodium Phosphate (TSP)LCO 3.5.6 APPLICABILITY:
The TSP baskets shall contain 524 ft 3 of active TSP.MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. TSP not within limits. A.1 Restore TSP to within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> limits.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.6.1 Verify the TSP baskets contain 524 ft 3 of granular anhydrous trisodium phosphate.
IR manhq <i SR 3.5.6.2 Verify that a sample from the TSP baskets provides adequate pH adjustment of borated water.PALO VERDE UNITS 1,2,3 3.5.6-1 AMENDMENT NO. 1-1-7 Containment Air Locks 3.6.2 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1 -----------------
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.Perform required air lock leakage rate In accordance testing in accordance with the Containment with the Leakage Rate Testing Program. Containment Leakage Rate Testing Program SR 3.6.2.2 Verify only one door in the air lock can be opened at a time.24 AntehS ---1 PALO VERDE UNITS 1,2,3 3.6.2-4 AMENDMENT NO. 4-14 Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each required 42 inch purge valve is sealed closed except for one purge valve in a penetration flow path while in Condition D of this LCO.31 days I.SR 3.6.3.2 Verify each 8 inch purge valve is closed except when the 8 inch purge valves are open for pressure control, ALARA or air quality considerations for personnel entry, or for Surveillances that require the valves to be open.31-days SR 3.6.3.3-------------------
NOTE---------------
Valves and blind flanges in high radiation areas may be verified by use of administrative means.Verify each containment isolation manual valve and blind flange that is located outside containment and not locked, sealed or otherwise secured and is required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.(continued)
PALO VERDE UNITS 1,2,3 3.6.3-5 AMENDMENT NO. 11ý, 166 Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.6.3.4-------------------
NOTE---------------
Valves and blind flanges in high radiation areas may be verified by use of administrative means.Verify each containment isolation manual valve and blind flange that is located inside containment and not locked, sealed or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days SR 3.6.3.5 Verify the isolation time of each required In automatic power operated containment accordance isolation valve is within limits, with the Inservice Testing Program SR 3.6.3.6 Perform leakage rate testing for required containment purge valves with resilient seals.,4 ..days AND Within 92 days after opening the valve SR 3.6.3.7 Verify each required automatic containment isolation valve that is not locked, sealed, or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal.18-m .kh&<-ýi PALO VERDE UNITS 1,2,3 3.6.3-6 AMENDMENT NO. 11ý, 166 Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 APPLICABILITY:
Containment pressure shall be -0.3 psig and +2.5 psig.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment pressure A.1 Restore containment 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> not within limits, pressure to within limits.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Compl eti on Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment limits.pressure is within 12-h~PALO VERDE UNITS 1,2,3 3.6.4-1 AMENDMENT NO. -14W Containment Air Temperature 3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 APPLICABILITY:
Containment average air temperature shall be 117'F.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment average A.1 Restore containment 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> air temperature not average air within limit, temperature to within limit.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment is within limit.average air temperature R4 h-wh g *PALO VERDE UNITS 1,2,3 3.6.5-1 AMENDMENT NO. 44-7 Containment Spray System 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray 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.3.1-days <- Isr SR 3.6.6.2 Verify the containment spray piping is full of water to the 113 ft level in the containment spray header.9daysd <-ýI SR 3.6.6.3 Verify each containment spray pump's In accordance developed head at the flow test point is with the greater than or equal to the required Inservice developed head. Testing Program SR 3.6.6.4 Verify each automatic containment spray valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.1A menh+SR 3.6.6.5 Verify each containment spray pump starts automatically on an actual or simulated actuation signal.1A inethq &SR 3.6.6.6 Verify each spray nozzle is unobstructed.
19-yeaFs <-ýI PALO VERDE UNITS 1,2,3 3.6.6-2 AMENDMENT NO. 44-7 ADVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each ADV.18-0ment-46&
-PALO VERDE UNITS 1,2,3 3.7.4-2 AMENDMENT NO. 14,1 AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify each AFW manual, power operated, and automatic valve in each water flow path and in both steam supply flow paths to the steam turbine driven pump. that is not locked, sealed, or otherwise secured in position, is in the correct position.3"1 ays+SR 3.7.5.2---- ---- ---- ----NOTE---------------
Not required to be performed for the turbine driven AFW pump until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after reaching 532 0 F in the RCS.Verify the developed head of each AFW pump at the flow test point is greater than or equal to the required developed head.In accordance with the Inservice Test Program SR 3.7.5.3 -----------------
NOTES--------------
- 1. Not required to be performed for the turbine driven AFW pump until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after reaching 532 0 F in the RCS.2. Not applicable in MODE 4 when steam generator is relied upon for heat removal.Verify each AFW automatic valve that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.1A MeRthq (continued)
PALO VERDE UNITS 1,2,3 3.7.5-3 AMENDMENT NO. 4-17 AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.7.5.4-------------------
NOTES--------------
- 1. Not required to be performed for the turbine driven AFW pump until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after reaching 532°F in the RCS.2. Not applicable in MODE 4 when steam generator is relied upon for heat removal.Verify each AFW pump starts automatically on an actual or simulated actuation signal.18 meRth&SR 3.7.5.5 Verify the proper alignment of the required Prior to AFW flow paths by verifying flow from the entering MODE 2 condensate storage tank to each steam whenever unit generator.
has been in MODE 5 or 6 for> 30 days PALO VERDE UNITS 1,2,3 3.7.5-4 AMENDMENT NO. 144 CST 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Condensate Storage Tank (CST)LCO 3.7.6 The CST level shall be 29.5 ft.APPLICABILITY:
MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. CST level not within A.1 Verify OPERABILITY of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> limit. backup water supply.AND Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter AND A.2 Restore CST level to 7 days within limit B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4 without 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> reliance on steam generator for heat removal.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify CST level is _> 29.5 ft.12 h~-h .<-6 PALO VERDE UNITS 1.2.3 3.7.6-1 AMENDMENT NO. 1-14 EW System 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1--NOTE--------------
Isolation of EW flow to individual components does not render the EW System inoperable.
Verify each EW manual, power operated, and automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.4.SR 3.7.7.2 Verify each EW automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.31 days -I8-Meth&SR 3.7.7.3 Verify each EW pump starts automatically on an actual or simulated actuation signal.PALO VERDE UNITS 1,2,3 3.7.7-2 AMENDMENT NO. 4-14 ESPS 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 -----------------
Notes--------------
Isolation of ESPS flow to individual components does not render ESPS inoperable.
Verify each ESPS manual and power operated valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.*1.SR 3.7.8.2 Verify each ESPS pump starts automatically on an actual or simulated actuation signal.PALO VERDE UNITS 1,2,3 3.7.8-2 AMENDMENT NO. 11,7 UHS 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Ultimate Heat Sink (UHS)LCO 3.7.9 APPLICABILITY:
The UHS shall be OPERABLE.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. UHS inoperable.
A.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> AND A.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Verify the usable water essential spray pond is depth of each 12 feet.2A4 heus <-2A4he'-rs 4- Insert 1 SR 3.7.9.2 Verify water temperature spray pond is 897F.of each essential PALO VERDE UNITS 1,2,3 3.7.9-1 AMENDMENT NO. 444 EC 3.7.10 3.7 PLANT SYSTEMS 3.7.10 Essential Chilled Water (EC) System LCO 3.7.10 APPLICABILITY:
Two EC trains shall be OPERABLE.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One EC train A.1 Restore EC train to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable.
OPERABLE status.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Verify each EC System manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.48-Rmentl+
SR 3.7.10.2 Verify the proper actuation of each EC System component on an actual or simulated actuation signal.PALO VERDE UNITS 1,2,3 3.7.10-1 AMENDMENT NO. 44-7 CREFS 3.7.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Operate each CREFS train for 15 minutes.31 days <&SR 3.7.11.2 Perform required CREFS filter testing in In accordance accordance with the Ventilation Filter with the VFTP Testing Program (VFTP).SR 3.7.11.3 Verify each CREFS train actuates on an actual or simulated actuation signal.48MAR h SR 3.7.11.4 Perform required CRE unfiltered air In accordance inleakage testing in accordance with the with the Control Control Room Envelope Habitability Program. Room Envelope Habitability Program.PALO VERDE UNITS 1.2,3 3.7.11-3 AMENDMENT NO. !1;, 171 CREATCS 3.7.12 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME E. Two CREATCS trains E.1 Suspend CORE Immediately inoperable in MODE 5 ALTERATIONS.
or 6, or during movement of irradiated AND fuel assemblies.
E.2 Suspend movement of Immediately irradiated fuel assemblies.
F. Two CREATCS trains F.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, 3, or 4.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 Verify each CREATCS train has the capability to remove the assumed heat load.1A-MeRthe PALO VERDE UNITS 1,2,3 3.7.12-2 AMENDMENT NO. 44-7 ESF PREACS 3.7.13 3.7 PLANT SYSTEMS 3.7.13 Engineered Safety Feature (ESF) Pump Room Exhaust System (PREACS)Air Cleanup LCO 3.7.13 APPLICABILITY:
Two ESF PREACS trains shall be OPERABLE.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One ESF PREACS train A.1 Restore ESF PREACS 7 days inoperable, train to OPERABLE status.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.13.1 Operate each> 15 minutes ESF PREACS train for 31 day& <-ý(continued)
PALO VERDE UNITS 1,2,3 3.7.13-1 AMENDMENT NO. 144 ESF PREACS 3.7.13 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.7.13.2 Perform required ESF PREACS filter testing In accordance in accordance with the Ventilation Filter with the VFTP Testing Program (VFTP).SR 3.7.13.3 Verify each ESF PREACS train actuates on an actual or simulated actuation signal.30 months <- Inser 1 SR 3.7.13.4 Verify one E measurable r atmospheric flowrate of 1SF PREACS train can maintain a negative pressure relative to pressure during operation at a 6000 cfm +/-10%.BTAGGERE TEST BASnse 1 PALO VERDE UNITS 1,2,3 3.7.13-2 AMENDMENT NO. 44-7 Fuel Storage Pool Water Level 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Fuel Storage Pool Water Level LCO 3.7.14 APPLICABILITY:
The fuel storage pool water level shall be 23 ft over the top of irradiated fuel assemblies seated in the storage racks.During movement of irradiated fuel assemblies in the fuel storage pool.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool A.1 --------NOTE-------
water level not within LCO 3.0.3 is not limit. applicable.
Suspend movement of Immediately irradiated fuel assemblies in fuel storage pool.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.14.1 Verify the fuel storage pool water level> 23 ft above the top of irradiated fuel assemblies seated in the storage racks.is 7 days -PALO VERDE UNITS 1,2,3 3.7.14-1 AMENDMENT NO. 417 Fuel Storage Pool Boron Concentration 3.7.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.15.1 Verify the fuel storage pool boron concentration is within limit.PALO VERDE UNITS 1,2,3 3.7.15-2 AMENDMENT NO. 447-Secondary Specific Activity 3.7.16 3.7 PLANT SYSTEMS 3.7.16 Secondary Specific Activity LCO 3.7.16 APPLICABILITY:
The specific activity of the secondary coolant shall be< 0.10 pCi/gm DOSE EQUIVALENT 1-131.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Specific activity not A.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> within limit.AND A.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.16.1 Verify the specific activity of the secondary coolant is within limit.31 days <-ýPALO VERDE UNITS 1,2,3 3.7.16-1 AMENDMENT NO. 1-14 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 1~SR 3.8.1.1 Verify correct breaker alignment and indicated power availability for each required offsite circuit.4.SR 3.8.1.2 ------------------
NOTES--------------
- 1. Performance of SR 3.8.1.7 satisfies this SR.2. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.3. A modified DG start involving 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.4. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.7 day& <-ý1 Verify each DG starts from standby condition and achieves steady state voltage 4000 V and ! 4377.2 V, and frequency 59.7 Hz and 60.7 Hz.(continued)
PALO VERDE UNITS 1,2,3 3.8.1-6 AMENDMENT NO. !29, 198 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.3 -----------------
NOTES--------------
- 1. DG loadings may include gradual loading as recommended by the manufacturer.
- 2. Momentary transients outside the load range do not invalidate this test.3. This Surveillance shall be conducted on only one DG at a time.4. This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7.Verify each DG is synchronized and loaded, and operates for 60 minutes at a load> 4950 kW and 5500 kW.31-days *- ý1 SR 3.8.1.4 Verify each day tank contains 550 gal of fuel oil (minimum level of 2.75 feet).SR 3.8.1.5 Check for and remove accumulated water from each day tank.SR 3.8.1.6 Verify the fuel oil transfer system operates to automatically transfer fuel oil from the storage tank to the day tank.(continued)
PALO VERDE UNITS 1,2,3 3.8.1-7 AMENDMENT NO. 1-14 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE I FREQUENCY SR 3.8.1.7 -----------------
NOTE---------------
- 1. All DG starts may be preceded by an engine prelube period followed by a warmup period prior to loading.2. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.Verify each DG starts from standby condition and achieves a. In 10 seconds, voltage 3740 V and frequency 58.8 Hz; and b. Steady state voltage 4000 V and 4377.2 V, and frequency 59.7 Hz and 60.7 Hz.194 days <-ýSR 3.8.1.8-----------------
NOTE-------------
This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Verify manual transfer of AC power sources from the normal offsite circuit to each alternate offsite circuit.18 months (continued)
PALO VERDE UNITS 1,2,3 3.8.1-8 AMENDMENT NO. 129, 156 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.9-----------------
NOTE--------------
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and: a. Following load rejection, the frequency is 64.5 Hz;b. Within 3 seconds following load rejection, the voltage is 3740 V and 4580 V; and c. Within 3 seconds following load rejection, the frequency is 58.8 Hz and 61.2 Hz.10 m eths SR 3.8.1.10 ------------------
NOTE-------------
If performed with the DG synchronized with offsite power, it shall be performed at a power factor of 0.89. 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 DG does not trip, and is maintained 6200 V during and a load rejection of 4950 kW and< 5500 kW.vol tage following 148meRtlh (continued)
PALO VERDE UNITS 1,2,3 3.8.1-9 AMENDMENT NO. 11ý, 167 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.11 -----------------
NOTE----------------
- 1. All DG starts may be preceded by an engine prelube period.2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.3. Momentary voltage and frequency transients induced by load changes do not invalidate this test.4. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.Verify on an actual or simulated loss of 18 Mt -offsite power signal: a. De-energization of emergency buses: b. Load shedding from emergency buses: c. DG auto-starts and: 1. energizes permanently connected loads in 10 seconds, 2. energizes auto-connected emergency loads through automatic load sequencer, 3. maintains steady state voltage> 4000 V and 4377.2 V, 4. maintains steady state frequency> 59.7 Hz and 60.7 Hz, and 5. supplies permanently connected and auto-connected emergency loads for 5 minutes.(continued)
PALO VERDE UNITS 1.2.3 3.8.1-10 AMENDMENT NO. 129, 156 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.12 -----------------
NOTES---------------
- 1. All DG starts may be preceded by an engine prelube period.2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.3. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.Verify on an actual or simulated Engineered 18 menth -Safety Feature (ESF) actuation signal (without a loss of offsite power) each DG auto-starts and: a. In 10 seconds, achieves voltage 3740 V and frequency 58.8 Hz: b. Achieves steady state voltage 4000 and 4377.2 V and frequency 59.7 Hz and 5 60.7 Hz;c. Operates for 5 minutes on standby (running unloaded);
- d. Permanently connected loads remain energized from the offsite power system; and e. Emergency loads are energized (auto-connected through the automatic load sequencer) from the offsite power system.(continued)
PALO VERDE UNITS 1,2,3 3.8.1-11 AMENDMENT NO. 129, 156 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.13 Verify each DG automatic trip is bypassed 1meths <-FJ on actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ESF actuation signal except: a. Engine overspeed;
- b. Generator differential current;c. Engine low lube oil pressure; and d. Manual emergency stop trip.(continued)
PALO VERDE UNITS 1,2,3 3.8.1-12 AMENDMENT NO. 11ý, 156 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.14 -----------------
NOTES--------------
- 1. Momentary transients outside the load range do not invalidate this test.2. If performed with the DG synchronized with offsite power, it shall be performed at a power factor of 0.89.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.
- 3. All DG starts may be preceded by an engine prelube period followed by a warmup period prior to loading.4. DG loading may include gradual loading as recommended by the manufacturer.
Verify each DG operates for 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s: 18 menths <--I a. For 22 hours2.546296e-4 days <br />0.00611 hours <br />3.637566e-5 weeks <br />8.371e-6 months <br /> loaded 4950 kW and 5500 kW; and b. For the remaining hours ( 2) of the test loaded 5775 kW and 6050 kW.(continued)
PALO VERDE UNITS 1,2,3 3.8.1-13 AMENDMENT NO. 11ý, 167 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
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, loaded 4950 kW and 5500 kW, has operated 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> or until temperatures have stabilized.
Momentary transients outside of load range do not invalidate this test.2. All DG starts may be preceded by an engine prelube period.3. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.Verify each DG starts and achieves 18-m~thI a. In 10 seconds, voltage 3740 V and frequency 58.8 Hz: and b. Steady state voltage 4000 V and 4377.2 V, and frequency 59.7 Hz and 60.7 Hz.SR 3.8.1.16 -----------------
NOTE--------------
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Verify each DG: menths <-E, a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;b. Transfers loads to offsite power source; and c. Returns to ready-to-load operation.(continued)
PALO VERDE UNITS 1,2,3 3.8.1-14 AMENDMENT NO. 129, 156 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.17-------------------
NOTE---------------
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Verify, with a DG operating in test mode and connected to its bus, an actual or simulated ESF actuation signal overrides the test mode by: a. Returning DG to ready-to-load operation; and b. Automatically energizing the emergency load from offsite power.I AmMRh SR 3.8.1.18 -----------------
NOTE--------------
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Verify interval between each sequenced load block is within +/- 1 second of design interval for each automatic load sequencer.(continued)
PALO VERDE UNITS 1,2,3 3.8.1-15 AMENDMENT NO. 117, 166 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.19 -----------------
NOTES----------------
- 1. All DG starts may be preceded by an engine prelube period.2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.3. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.Verify on an actual or simulated loss of 18-men offsite power signal in conjunction with an actual or simulated ESF actuation signal: a. De-energization of emergency buses: b. Load shedding from emergency buses;c. DG auto-starts from standby condition and: 1. energizes permanently connected loads in 10 seconds, 2. energizes auto-connected emergency loads through load sequencer, 3. achieves steady state voltage> 4000 V and 4377.2 V, 4. achieves steady state frequency> 59.7 Hz and 60.7 Hz, and 5. supplies permanently connected and auto-connected emergency loads for 5 minutes.(continued)
PALO VERDE UNITS 1,2,3 3.8.1-16 AMENDMENT NO. 129, 156 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.20-------------------
NOTES--------------
- 1. All DG starts may be preceded by an engine prelube period.2. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.Verify, when started simultaneously, each DG achieves a. In 10 seconds, voltage 3740 V and frequency 58.8 Hz; and b. Steady state voltage 4000 V and 4377.2 V, and frequency 59.7 Hz and 60.7 Hz.10 yeaF-s -PALO VERDE UNITS 1,2,3 3.8.1-17 AMENDMENT NO. 129, 156 Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains> 80% indicated fuel level.31 days <-ýSR 3.8.3.2 Verify lubricating oil inventory is> 2.5 inches visible in the sightglass.
31 dayLs <-ý1 SR 3.8.3.3 Verify fuel oil properties of new and In accordance stored fuel oil are tested in accordance with the Diesel with, and maintained within the limits of, Fuel Oil the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.4 Verify each DG starting air receiver pressure is 230 psig.31 days <-ý1~SR 3.8.3.5 Check for and remove accumulated water from each fuel oil storage tank.92 day's PALO VERDE UNITS 1,2,3 3.8.3-3 AMENDMENT NO. 117, 164 DC Sources -Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage on float charge.is _> 129 V 7 days.1.SR 3.8.4.2 Verify no visible corrosion at battery terminals and connectors.
OR Verify battery connection resistance is< 150E-6 ohms for inter-cell connections.
< 150E-6 ohms for inter-rack connections.
< 150E-6 ohms for inter-tier connections.
and _< 150E-6 ohms for terminal connections.
92-days -~1A M9Rth&SR 3.8.4.3 Verify battery cells, cell plates, and racks show no visual indication of physical damage or abnormal deterioration that could degrade battery performance.
SR 3.8.4.4 Remove visible terminal corrosion and verify battery cell to cell and terminal connections are clean, and are coated with anti-corrosion material.18 meith&SR 3.8.4.5 Verify battery connection resistance is" 150E-6 ohms for inter-cell connections." 150E-6 ohms for inter-rack connections." 150E-6 ohms for inter-tier connections.
and 150E-6 ohms for terminal connections.
1_8 menh (continued)
PALO VERDE UNITS 1,2,3 3.8.4-2 AMENDMENT NO. 11ý 159 DC Sources -Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.4.6-------------------
NOTE---------------
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4 on the charger credited for OPERABILITY.
However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Verify each battery charger supplies 400 amps for Batteries A and B and 300 amps for Batteries C and D at 125 V for 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.18 mRnths SR 3.8.4.7-------------------
NOTES--------------
- 1. The battery performance discharge test or the modified performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test in SR 3.8.4.7.2. This Surveillance shall not be performed in MODE 1, 2, 3, or 4.Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.38-months (continued)
PALO VERDE UNITS 1.2,3 3.8.4-3 AMENDMENT NO. 11ý, 166 DC Sources -Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.4.8----------------
NOTE---------------
This Surveillance shall not be performed in MODE 1, 2, 3, or 4.Verify battery capacity is 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test.69 menths AND 12 months when battery shows degradation or has reached 85%of the expected life with capacity< 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected life with capacity 100% of manufacturer's rating PALO VERDE UNITS 1,2,3 3.8.4-4 AMENDMENT NO. 196, 159 Battery Cell Parameters 3.8.6 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Declare associated Immediately associated Completion battery inoperable.
Time of Condition A not met.OR One or more batteries with average electrolyte temperature of the representative cells< 60 0 F.OR One or more batteries with one or more battery cell parameters not within Category C limits.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet Table 3.8.6-1 Category A limits.7 days <(continued)
PALO VERDE UNITS 1,2,3 3.8.6-2 AMENDMENT NO. 447 Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY-t SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6-1 Category B limits.92sdays AND Once within 7 days after battery discharge< 105 V AND Once within 7 days after battery overcharge
> 150 V SR 3.8.6.3 Verify average electrolyte temperature of representative cells is 60 0 F.92 days,<-PALO VERDE UNITS 1,2,3 3.8.6-3 AMENDMENT NO. 11-7 Inverters
-Operating 3.8.7 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, frequency, and alignment to required AC vital instrument buses.7 days&PALO VERDE UNITS 1,2,3 3.8.7-2 AMENDMENT NO. 114 Inverters
-Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)
A.2.4 Initiate action to Immediately restore required inverters to OPERABLE status.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage, frequency, and alignments to required AC vital instrument buses.7 days <-PALO VERDE UNITS 1,2,3 3.8.8-2 AMENDMENT NO. 447-Distribution Systems -Operating 3.8.9 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. One DC electrical C.1 Restore DC electrical 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> power distribution power distribution subsystems inoperable, subsystem to OPERABLE AND status.16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> from discovery of failure to meet LCO D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> E. Two or more inoperable E.1 Enter LCO 3.0.3. Immediately distribution subsystems that result in a loss of safety function.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to required AC, DC, and AC vital instrument bus electrical power distribution subsystems.
7 days &PALO VERDE UNITS 1,2,3 3.8.9-2 AMENDMENT NO. 1-14 Distribution Systems -Shutdown 3.8.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)
A.2.4 Initiate actions to Immediately restore required AC, DC, and AC vital instrument bus electrical power distribution subsystems to OPERABLE status.AND A.2.5 Declare associated Immediately required shutdown cooling subsystem(s) inoperable and not in operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to required AC, DC, and AC vital instrument bus electrical power distribution subsystems.
7-days <-ý1 PALO VERDE UNITS 1,2,3 3.8.10-2 AMENDMENT NO. 44-7 Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentrations of the Reactor Coolant System and the refueling canal shall be maintained within the limit specified in the COLR.APPLICABILITY:
MODE 6.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration A.1 Suspend CORE Immediately not within limit. ALTERATIONS.
AND A.2 Suspend positive Immediately reactivity additions.
AND A.3 Initiate action to Immediately restore boron concentration to within limit.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit specified in the COLR.72 h--he-PALO VERDE UNITS 1,2,3 3.9.1-1 AMENDMENT NO. 44 Nuclear Instrumentation 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Perform CHANNEL CHECK.4.SR 3.9.2.2-------------------
NOTE---------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION.
12 h--he. <PALO VERDE UNITS 1,2,3 3.9.2-2 AMENDMENT NO. 1-14 Containment Penetrations 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify each required containment penetration is in the required status.4 SR 3.9.3.2 Verify each required containment purge and exhaust valve actuates to the isolation position on an actual or simulated actuation signal.SR 3.9.3.3 Verify the capability to close the equipment hatch, if open PALO VERDE UNITS 1,2,3 3.9.3-2 AMENDMENT NO. 443 SDC and Cool ant Circulation
-High Water Level 3.9.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)
A.4 Close all containment 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> penetrations providing direct access from containment atmosphere to outside atmosphere.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify one SDC loop is operable and in operation.
1:2 h--h9 <E PALO VERDE UNITS 1,2,3 3.9.4-2 AMENDMENT NO. 14r7 SDC and Coolant Circulation
-Low Water Level 3.9.5 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. No SDC loop OPERABLE B.1 Suspend operations Immediately or in operation, involving a reduction in reactor coolant boron concentration.
AND B.2 Initiate action to Immediately restore one SDC loop to OPERABLE status and to operation.
AND B.3 Close all 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> containment penetrations providing direct access from containment atmosphere to outside atmosphere.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify required SDC loops are OPERABLE and one SDC loop is in operation.
12 heurs 7 daY6 SR 3.9.5.2 Verify correct breaker alignment and indicated power available to the required SDC pump that is not in operation.
PALO VERDE UNITS 1,2,3 3.9.5-2 AMENDMENT NO. 4-14 Refueling Water Level-Fuel Assemblies 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Refueling Water Level-Fuel Assemblies LCO 3.9.6 APPLICABILITY:
Refueling water level shall be maintained 23 ft above the top of the reactor vessel flange.During movement of fuel assemblies within containment when either the fuel assemblies being moved or the fuel assemblies seated within the reactor vessel are irradiated.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling water level A.1 Suspend movement of Immediately not within limit, fuel assemblies within containment.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify refueling above the top of water level is 23 ft reactor vessel flange.24 he~wr-;<&
_PALO VERDE UNITS 1,2,3 3.9.6-1 AMENDMENT NO. 44-7 Refueling Water Level-CEAs 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Refueling Water Level-CEAs LCO 3.9.7 APPLICABILITY:
Refueling water level shall be maintained 23 ft above the top of irradiated fuel assemblies seated within the reactor vessel.During movement of CEAs within the reactor vessel, when the fuel assemblies seated within the reactor vessel are irradiated.
ACTIONS CONDITION REQUIRED ACTION COMPLETIONTIME A. Refueling water level A.1 Suspend movement of Immediately not within limit. CEAs within the reactor vessel.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling above the top of seated within the water level is 23 ft irradiated fuel assemblies reactor vessel.24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, ----PALO VERDE UNITS 1,2,3 3.9.7-1 AMENDMENT NO. 144 Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.17 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 Essential Filtration System (CREFS), 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 whole body or its equivalent to any part of the body 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 in accordance with the testing methods and the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Determining Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.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 of one train of the CREFS, operating at the flow rate required by the VFTP, at a Frequency of 18 months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the periodic assessment of the CRE boundary.e. The quantitative limits on unfiltered air inleakage into the CRE shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph
- c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences.
- 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.
PAOVREUIS12352-7AEDETN.4~
PALO VERDE UNITS 1,2,3 5.5-17 AMENDMENT NO. 4-74 Insert I In accordance with the Surveillance Frequency Control Program Insert 2 5.5.18 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.Insert Attachment 4 Retyped Technical Specification Pages Pages 3.1.1-1 3.3.6-3 3.4.14-2 3.7.5-4 3.8.1-16 3.1.2-2 3.3.7-3 3.4.15-2 3.7.6-1 3.8.1-17 3.1.3-2 3.3.8-2 3.4.15-3 3.7.7-2 3.8.3-3 3.1.5-3 3.3.8-3 3.4.16-2 3.7.8-2 3.8.4-2 3.1.6-2 3.3.9-2 3.4.16-3 3.7.9-1 3.8.4-3 3.1.7-3 3.3.9-3 3.4.17-2 3.7.10-1 3.8.4-4 3.1.8-2 3.3.10-3 3.4.17-3 3.7.11-3 3.8.6-2 3.1.9-2 3.3.11-2 3.5.1-2 3.7.12-2 3.8.6-3 3.1.10-2 3.3.12-3 3.5.1-3 3.7.13-1 3.8.7-2 3.2.1-2 3.4.1-2 3.5.2-2 3.7.13-2 3.8.8-2 3.2.2-2 3.4.2-1 3.5.2-3 3.7.14-1 3.8.9-2 3.2.3-3 3.4.3-2 3.5.3-2 3.7.15-2 3.8.10-2 3.2.4-2 3.4.4-1 3.5.3-3 3.7.16-1 3.9.1-1 3.2.5-1 3.4.5-2 3.5.5-2 3.8.1-6 3.9.2-2 3.3.1-3 3.4.6-2 3.5.6-1 3.8.1-7 3.9.3-2 3.3.1-4 3.4.6-3 3.6.2-4 3.8.1-8 3.9.4-2 3.3.1-5 3.4.7-3 3.6.3-5 3.8.1-9 3.9.5-2 3.3.1-6 3.4.8-2 3.6.3-6 3.8.1-10 3.9.6-1 3.3.2-3 3.4.9-2 3.6.4-1 3.8.1-11 3.9.7-1 3.3.2-4 3.4.11-2 3.6.5-1 3.8.1-12 5.5-17 3.3.3-4 3.4.12-1 3.6.6-2 3.8.1-13 5.5-18 3.3.4-3 3.4.12-2 3.7.4-2 3.8.1-14 Insert 3.3.5-3 3.4.13-3 3.7.5-3 3.8.1-15 SDM -Reactor Trip Breakers Open 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM) -Reactor Trip Breakers Open LCO 3.1.1 APPLICABILITY:
SDM shall be the value in the COLR.MODES 3, 4, and 5 with the Reactor Trip Breakers Open or the CEA drive system not capable of CEA withdrawal.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Initiate boration to 15 minutes restore SDM to within limit.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM is the value in the COLR. In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.1.1-1 AMENDMENT NO. 444, SDM -Reactor Trip Breakers Closed 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 Verify SDM is the value in the COLR. In accordance with the Surveillance Frequency Control Program SR 3.1.2.2 -----------------
NOTE----------------
Only required if Tc 500 0 F.Verify KN-1 < 0.99. In accordance with the Surveillance Frequency Control Program SR 3.1.2.3 Verify criticality cannot be achieved with In accordance shutdown group CEA movement, with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.1.2-2 AMENDMENT NO. 44-ý,
Reactivity Balance 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1---- ---- ---- ----NOTES --------------
The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days (EFPD) after each fuel loading.Verify overall core reactivity balance is within +/- 1.0% Ak/k of predicted values.Prior to entering MODE 1 after fuel loading AND----- NOTE -----Only required after 60 EFPD In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.1.3-2 AMENDMENT NO. ;-I;-,
CEA Alignment 3.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify the indicated position of each full In accordance strength and part strength CEA is within with the 6.6 inches of all other CEAs in its group. Surveillance Frequency Control Program SR 3.1.5.2 Verify that, for each CEA, its OPERABLE CEA In accordance position indicator channels indicate within with the 5.2 inches of each other. Surveillance Frequency Control Program SR 3.1.5.3 Verify full strength CEA freedom of In accordance movement (trippability) by moving each with the individual full strength CEA that is not Surveillance fully inserted in the core at least 5 Frequency inches. Control Program SR 3.1.5.4 Perform a CHANNEL FUNCTIONAL TEST of each In accordance reed switch position transmitter channel. with the Surveillance Frequency Control Program SR 3.1.5.5 Verify each full strength CEA drop time Prior to< 4.0 seconds, reactor criticality, after each removal of the reactor head PALO VERDE UNITS 1,2,3 3.1.5-3 AMENDMENT NO. 4-7-9, Shutdown CEA Insertion Limits 3.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify each shutdown CEA is withdrawn In accordance 147.75 inches. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.1.6-2 AMENDMENT NO. -ý64, Regulating CEA Insertion Limits 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 -----------------
NOTE------------
This Surveillance is not required to be performed prior to entry into MODE 2.Verify each regulating CEA group position is within its insertion limits.In accordance with the Surveillance Frequency Control Program SR 3.1.7.2 Verify the accumulated times during which In accordance the regulating CEA groups are inserted with the beyond the steady state insertion limits Surveillance but within the transient insertion limits. Frequency Control Program SR 3.1.7.3 Verify PDIL alarm circuit is OPERABLE.
In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.1.7-3 AMENDMENT NO. 44-ý,
Part Strength CEA Insertion Limits 3.1.8 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 Verify part strength CEA group position.
In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.1.8-2 AMENDMENT NO. 74, STE-SDM 3.1.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.9.1 Verify that the position of each CEA not In accordance fully inserted is within the acceptance with the criteria for available negative reactivity Surveillance addition.
Frequency Control Program SR 3.1.9.2 Verify each full strength CEA not fully Within 7 days inserted is capable of full insertion when prior to tripped from at least the 50% withdrawn reducing SDM position.
requirements to less than the limits of LCO 3.1.2 SR 3.1.9.3 -----------------
NOTE--------------
Only required to be performed in Mode 3.Verify that with all full strength CEAs In accordance fully inserted, the reactor is subcritical with the within the acceptance criteria.
Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.1.9-2 AMENDMENT NO. 4-52, STE -MODES 1 and 2 3.1.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.10.1 Verify THERMAL POWER equal to or less than In accordance the test power plateau. with the Surveillance Frequency Control Program SR 3.1.10.2 Verify that the position of each CEA not In accordance fully inserted is within the acceptance with the criteria for available negative reactivity Surveillance addition.
Frequency Control Program PALO VERDE UNITS 1,2,3 3.1.10-2 AMENDMENT NO. 4-59, LHR 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1------------------
NOTE----------------
- 1. Only applicable when COLSS is out of*service.
With COLSS in service, LHR is continuously monitored.
- 2. Not required to be performed until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after MODE 1 with THERMAL POWER> 20% RTP.Verify LHR, as indicated on any OPERABLE local power density channel, is within its limits.In accordance with the Surveillance Frequency Control Program SR 3.2.1.2 Verify the COLSS margin alarm actuates at a In accordance THERMAL POWER equal to or less than the with the core power operating limit based on LHR. Surveillance Frequency Control Program PALO VERDE UNITS 1.2,3 3.2.1-2 AMENDMENT NO. ý,
3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify measured Fy obtained using the Incore Detector System is equal to or less than the value of F' used in the COLSS and CPCs.Once after each fuel loading with THERMAL POWER > 40% RTP but prior to operations above 70% RTP AND In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.2.2-2 AMENDMENT NO. ;4-ý,
Tq 3. 2.3ýSURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 -----------------
NOTES--------------
- 1. Only applicable when COLSS is out of service. With COLSS in service, this parameter is continuously monitored.
- 2. Not required to be performed until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after MODE 1 with THERMAL POWER > 20% RTP.Calculate Tq and verify it is within the In accordance limit. with the Surveillance Frequency Control Program SR 3.2.3.2 Verify COLSS azimuthal tilt alarm is In accordance actuated at a Tq value less than the Tq with the value used in the CPCs. Surveillance Frequency Control Program SR 3.2.3.3 Independently confirm the validity of the In accordance COLSS calculated Tq by use of the incore with the detectors.
Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.2.3-3 AMENDMENT NO.
DNBR 3.2.4 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. DNBR outside the B.1 Determine trend in DNBR. Once per region of acceptable AND 15 minutes operation when COLSS is out of service. B.2.1 With an adverse trend, restore DNBR 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to within limit.OR B.2.2 With no adverse 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> trend, restore DNBR to within limit.C. Required Action and C.1 Reduce THERMAL POWER 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion to 20% RTP.Time not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 -----------------
NOTE----------------
- 1. Only applicable when COLSS is out of service. With COLSS in service, this parameter is continuously monitored.
- 2. Not required to be performed until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after MODE 1 with THERMAL POWER > 20% RTP.Verify DNBR, as indicated on any OPERABLE In accordance DNBR channels, is within the limit of the with the COLR, as applicable.
Surveillance Frequency Control Program SR 3.2.4.2 Verify COLSS margin alarm actuates at a In accordance THERMAL POWER level equal to or less than with the the core power operating limit based on Surveillance DNBR. Frequency Control Program PALO VERDE UNITS 1,2,3 3.2.4-2 AMENDMENT NO. 4-7-9, AS I 3.2.5 3.2 POWER DISTRIBUTION LIMITS 3.2.5 AXIAL SHAPE INDEX (ASI)LCO 3.2.5 APPLICABILITY:
ASI shall be within the limits specified in the COLR.MODE 1 with THERMAL POWER > 20% RTP.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Core average ASI not A.1 Restore ASI to within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> within limits, limits.B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion to 20% RTP.Time not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.5.1 -----------------
Notes--------------
Not required to be performed until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after MODE 1 with THERMAL POWER > 20% RTP.Verify ASI is within limits. In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.2.5-1 AMENDMENT NO. ;4-;,
RPS Instrumentation
-Operating 3.3.1 SURVEILLANCE REQUIREMENTS
NOTE- ----------------------------
Refer to Table 3.3.1-1 to determine which SR shall be performed for each RPS Function.SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform a CHANNEL CHECK of each RPS In accordance instrument channel, with the Surveillance Frequency Control Program SR 3.3.1.2 -----------------
NOTE--------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER 70% RTP.Verify total Reactor Coolant System (RCS) In accordance flow rate as indicated by each CPC is less with the than or equal to the RCS total flow rate. Surveillance Frequency If necessary, adjust the CPC addressable Control Program constant flow coefficients such that each CPC indicated flow is less than or equal to the RCS flow rate.SR 3.3.1.3 Check the CPC System Event Log. In accordance with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1.2.3 3.3.1-3 AMENDMENT NO. 4-;9, RPS Instrumentation
-Operating 3.3.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.1.4 -----------------
NOTES--------------
- 1. Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER_> 20% RTP.2. The daily calibration may be suspended during PHYSICS TESTS, provided the calibration is performed upon reaching each major test power plateau and prior to proceeding to the next major test power plateau.Perform calibration (heat balance only) and adjust the linear power level signals and the CPC addressable constant multipliers to make the CPC AT power and CPC nuclear power calculations agree with the calorimetric, if the absolute difference is 2% when THERMAL POWER is 80% RTP. Between 20%and 80% RTP the maximum difference is -0.5%to 10%.In accordance with the Surveillance Frequency Control Program SR 3.3.1.5---- ---- ---- ----NOTE- --------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER 70% RTP.Verify total RCS flow rate indicated by each CPC is less than or equal to the RCS flow determined either using the reactor coolant pump differential pressure instrumentation and the ultrasonic flow meter adjusted pump curves or by calorimetric calculations.
In accordance with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.3.1-4 AMENDMENT NO. 74, RPS Instrumentation
-Operating 3.3.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.1.6 ------------------
NOTE----------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER 15% RTP.Verify linear power subchannel gains of the In accordance excore detectors are consistent with the with the values used to establish the shape Surveillance annealing matrix elements in the CPCs. Frequency Control Program SR 3.3.1.7 -----------------
NOTES--------------
- 1. The CPC CHANNEL FUNCTIONAL TEST shall include verification that the correct values of addressable constants are installed in each OPERABLE CPC.2. Not required to be performed for logarithmic power level channels until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after reducing logarithmic power below 1E-4% NRTP.Perform CHANNEL FUNCTIONAL TEST on each In accordance channel. with the Surveillance Frequency Control Program SR 3.3.1.8 -----------------
NOTE---------------
Neutron detectors are excluded from the CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION of the power In accordance range neutron flux channels.
with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.3.1-5 AMENDMENT NO.
RPS Instrumentation
-Operating 3.3.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.1.9-------------------
NOTE--------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION on each channel, including bypass removal functions.
In accordance with the Surveillance Frequency Control Program SR 3.3.1.10 Perform a CHANNEL FUNCTIONAL TEST on each In accordance CPC channel. with the Surveillance Frequency Control Program SR 3.3.1.11 Using the incore detectors, verify the Once after each shape annealing matrix elements to be used refueling prior by the CPCs. to exceeding 70% RTP SR 3.3.1.12 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal function.
92 days prior to each reactor startup SR 3.3.1.13 -----------------
NOTE--------------
Neutron detectors are excluded.Verify RPS RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.1-6 AMENDMENT NO. 74, RPS Instrumentation
-Shutdown 3.3.2 SURVEILLANCE REQUIREMENTS
NOTE ------------------------------
Refer to Table 3.3.2-1 to determine which SR shall be performed for each RPS function.SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform a CHANNEL CHECK of each RPS In accordance instrument channel. with the Surveillance Frequency Control Program SR 3.3.2.2 Perform a CHANNEL FUNCTIONAL TEST on each In accordance channel, with the Surveillance Frequency Control Program SR 3.3.2.3 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal function.
92 days prior to each reactor startup SR 3.3.2.4 -----------------
NOTE---------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform a CHANNEL CALIBRATION on each In accordance channel, including bypass removal function.
with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.3.2-3 AMENDMENT NO.
RPS Instrumentation
-Shutdown 3.3.2 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.2.5 -----------------
NOTE---------------
Neutron detectors are excluded.Verify RPS RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.2-4 AMENDMENT NO. 144, CEACs 3.3.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform a CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.3.2 Deleted SR 3.3.3.3 Perform a CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.3.4 Perform a CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program SR 3.3.3.5 Perform a CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.3-4 AMENDMENT NO. ;;-9, RPS Logic and Trip Initiation 3.3.4 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion AND Time of Condition A, B. or D not met. E.2 Open all RTCBs. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> OR One or more Functions with more than one Manual Trip, Matrix Logic, Initiation Logic, or RTCB channel inoperable for reasons other than Condition A or D.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform a CHANNEL FUNCTIONAL TEST on each In accordance RPS Logic channel and Manual Trip channel. with the Surveillance Frequency Control Program SR 3.3.4.2 Perform a CHANNEL FUNCTIONAL TEST, In accordance including separate verification of the with the undervoltage and shunt trips, on each RTCB. Surveillance Frequency Control Program SR 3.3.4.3 Perform a CHANNEL FUNCTIONAL TEST on each In accordance RTCB. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.4-3 AMENDMENT NO. 14, ESFAS Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 Perform a CHANNEL CHECK of each ESFAS In accordance channel. with the Surveillance Frequency Control Program SR 3.3.5.2 Perform a CHANNEL FUNCTIONAL TEST of each In accordance ESFAS channel. with the Surveillance Frequency Control Program SR 3.3.5.3 Perform a CHANNEL CALIBRATION of each ESFAS In accordance channel, including bypass removal with the functions.
Surveillance Frequency Control Program SR 3.3.5.4 Verify ESF RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program SR 3.3.5.5 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal channel. 92 days prior to each reactor startup PALO VERDE UNITS 1,2,3 3.3.5-3 AMENDMENT NO. ý44, ESFAS Logic and Manual Trip 3.3.6 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion AND Time of Conditions for Safety Injection Actuation Signal, F.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Containment Isolation Actuation Signal, or Reci rcul ati on Actuation Signal not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.6.1 -----------------
NOTE---------------
Testing of Actuation Logic shall include the verification of the proper operation of each initiation relay.Perform a CHANNEL FUNCTIONAL TEST on each In accordance ESFAS logic channel and Manual Trip with the channel. Surveillance Frequency Control Program SR 3.3.6.2 -----------------
NOTE---------------
Relays exempt from testing during operation shall be tested each 18 months.Perform a subgroup relay test of each In accordance Actuation Logic channel, which includes the with the de-energization of each subgroup relay and Surveillance verification of the OPERABILITY of each Frequency subgroup relay. Control Program PALO VERDE UNITS 1,2,3 3.3.6-3 AMENDMENT NO. 4-1-;,
DG -LOVS 3.3.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.7.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.7.3 Perform CHANNEL CALIBRATION with setpoint In accordance Allowable Values as follows: with the Surveillance
- a. Degraded Voltage Function 3697 V and Frequency 3786 V Control Program Time delay: 28.6 seconds and 35 seconds; and b. Loss of Voltage Function Time delay: 10.3 seconds and12.6 seconds at 2929.5 V, and 2.0 seconds and 2.4 seconds at 0 V.PALO VERDE UNITS 1,2,3 3.3.7-3 AMENDMENT NO. 4-2-4, CPIAS 3.3.8 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. CPIAS Manual Trip, C.1 Place and maintain Immediately Actuation Logic, or containment purge and radiation monitor exhaust valves in inoperable during CORE closed position.ALTERATIONS or movement of irradiated OR fuel assemblies within containment.
C.2.1 Suspend CORE Immediately ALTERATIONS.
AND C.2.2 Suspend movement of Immediately irradiated fuel assemblies in containment.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.1 Perform a CHANNEL CHECK on required In accordance radiation monitor channel, with the Surveillance Frequency Control Program SR 3.3.8.2 Perform a CHANNEL FUNCTIONAL TEST on each In accordance required radiation monitor channel, and with the Verify the setpoint 2.5 mR/hr. Surveillance Frequency Control Program SR 3.3.8.3 -----------------
NOTE----------------
Surveillance of Actuation Logic shall include the verification of the proper operation of each actuation relay.Perform a CHANNEL FUNCTIONAL TEST on In accordance required CPIAS Actuation Logic channel, with the Surveillance Frequency Control Program (continued)
AMENDMENT NO. 4-7, PALO VERDE UNITS 1,2.3 3.3.8-2 CPIAS 3.3.8 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.8.4 Perform a CHANNEL CALIBRATION on required In accordance radiation monitor channel. with the Surveillance Frequency Control Program SR 3.3.8.5 Perform CHANNEL FUNCTIONAL TEST on required In accordance CPIAS Manual Trip channel, with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2.3 3.3.8-3 AMENDMENT NO. 44-ý,
CREFAS 3.3.9 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. CREFAS Manual Trip, C.1 Place one CREFS train Immediately Actuation Logic, or in operation.
radiation monitor OR inoperable in MODE 5 OR or 6, or during C.2.1 Suspend movement of Immediately movement of irradiated irradiated fuel fuel assemblies.
a d ies.assemblies.
AND C.2.2 Suspend positive Immediately reactivity additions.
AND C.2.3 Suspend CORE Immediately ALTERATIONS.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.9.1 Perform a CHANNEL CHECK on the required In accordance control room radiation monitor channel. with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.3.9-2 AMENDMENT NO. 4-14, CREFAS 3.3.9 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.9.2 Perform a CHANNEL FUNCTIONAL TEST on In accordance required CREFAS radiation monitor channel. with the Surveillance Verify CREFAS high radiation setpoint is Frequency< 2 x 10- pCi/cc. Control Program SR 3.3.9.3 ------------------
NOTES---------------
- 1. Surveillance of Actuation Logic shall include the verification of the proper operation of each Actuation relay.2. Relays associated with plant equipment that cannot be operated during plant operation are required to be tested during each MODE 5 entry exceeding 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> unless tested within the previous 6 months.Perform a CHANNEL FUNCTIONAL TEST on In accordance required CREFAS Actuation Logic channel, with the Surveillance Frequency Control Program SR 3.3.9.4 Perform a CHANNEL CALIBRATION on required In accordance CREFAS radiation monitor channel. with the Surveillance Frequency Control Program SR 3.3.9.5 Perform a CHANNEL FUNCTIONAL TEST on In accordance required CREFAS Manual Trip channel, with the Surveillance Frequency Control Program SR 3.3.9.6 Verify that response time of required In accordance CREFAS channel is within limits, with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.9-3 AMENDMENT NO. 444, PAM Instrumentation 3.3.10 SURVEILLANCE REQUIREMENTS
NOTE- ----------------------------
These SRs apply to each PAM instrumentation Function in Table 3.3.10-1.SURVEILLANCE FREQUENCY SR 3.3.10.1 Perform CHANNEL CHECK for each required In accordance instrumentation channel that is normally with the energized.
Surveillance Frequency Control Program SR 3.3.10.2 -----------------
NOTE--------------
Neutron detectors are excluded from the CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.10-3 AMENDMENT NO.
Remote Shutdown System 3.3.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.11.1 Perform CHANNEL CHECK for each required In accordance instrumentation channel that is normally with the energized.
Surveillance Frequency Control Program SR 3.3.11.2 Verify each required control circuit and In accordance transfer switch is capable of performing with the the intended function.
Surveillance Frequency Control Program SR 3.3.11.3 -----------------
NOTE----------------
Neutron detectors are excluded from the CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION for each In accordance required instrumentation channel. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.11-2 AMENDMENT NO.
Boron Dilution Alarm System (BDAS)3.3.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY----------------------
NOTE------------
SR 3.3.12.1 Not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after neutron flux is within the startup range.Perform CHANNEL CHECK.In accordance with the Surveillance Frequency Control Program----------------------
NOTE------------
SR 3.3.12.2 Not required to be performed until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after neutron flux is within the startup range.Perform CHANNEL FUNCTIONAL TEST.In accordance with the Surveillance Frequency Control Program SR 3.3.12.3--NOTE Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.12-3 AMENDMENT NO. 44--ý,
RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. Pressurizer pressure C.1 Restore parameter(s) 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> or RCS cold leg to within limits.temperature not within limits.D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition C not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure 2130 psia and In accordance 2295 psia. with the Surveillance Frequency Control Program SR 3.4.1.2 Verify RCS cold leg temperature within In accordance limits as shown in Figure 3.4.1-1. with the Surveillance Frequency Control Program SR 3.4.1.3 ----------------
NOTE---------------
Required to be met in MODE 1 with all RCPs running.Verify RCS total flow rate In accordance 155.8 E6 Ibm/hour.
with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.1-2 AMENDMENT NO. 444, RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 APPLICABILITY:
Each RCS loop temperature (TCOld) shall be > 5457F.MODE 1, MODE 2 with Keff -> 1.0.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Tcold in one or more A.1 Be in MODE 3. 30 minutes RCS loops not within limit.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 Verify RCS TCOld in each loop 545'F. ------ NOTE -----Only required if any RCS loop Tcold < 550 0 F.In accordance with the Surveillance Frequency Control Program AND Once within 30 minutes prior to reaching criticality PALO VERDE UNITS 1,2,3 3.4.2-1 AMENDMENT NO.
RCS P/T Limits 3.4.3 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. NOTE --------C.1 Initiate action to Immediately Required Action C.2 restore parameter(s) shall be completed to within limits.whenever this Condition is entered. AND C.2 Determine RCS is Prior to Requirements of LCO acceptable for entering MODE 4 not met any time in continued operation.
other than MODE 1, 2, 3, or 4.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 ---------------
NOTE----------------
Only required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing.Verify RCS pressure, RCS temperature, and In accordance RCS heatup and cooldown rates within limits with the specified in the PTLR. Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.3-2 Amendment No. 4-;9, RCS Loops -MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.4 RCS Loops -MODES 1 and 2 LCO 3.4.4 Two RCS loops shall be OPERABLE and in operation.
APPLICABILITY:
MODES 1 and 2.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of LCO A.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation.
In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.4-1 AMENDMENT NO. 11-7, RCS Loops -MODE 3 3.4.5 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. No RCS loop OPERABLE.
C.1 Suspend all Immediately operations involving OR a reduction of RCS boron concentration.
No RCS loop in operation.
AND C.2 Initiate action to Immediately restore one RCS loop to OPERABLE status and operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loop is in operation.
In accordance with the Surveillance Frequency Control Program SR 3.4.5.2 Verify secondary side water level in each In accordance steam generator 25%. with the Surveillance Frequency Control Program SR 3.4.5.3 Verify correct breaker alignment and In accordance indicated power available to the required with the pump that is not in operation.
Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.5-2 AMENDMENT NO.
RCS Loops -MODE 4 3.4.6 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. One required SDC train B.1 Be in MODE 5. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> inoperable.
AND Two required RCS loops inoperable.
C. No RCS loop or SDC C.1 Suspend all Immediately train OPERABLE.
operations involving reduction of RCS OR boron concentration.
No RCS loop or SDC AND train in operation.
C.2 Initiate action to Immediately restore one loop or train to OPERABLE status and operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RCS loop or SDC train is in In accordance operation.
with the-Surveillance Frequency Control Program SR 3.4.6.2 Verify secondary side water level in In accordance required SG(s) is 25%. with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.4.6-2 AMENDMENT NO. 44ý,
RCS Loops MODE 4 3.4.6 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.4.6.3 Verify correct breaker alignment and In accordance indicated power available to the required with the pump that is not in operation.
Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.6-3 AMENDMENT NO. 11-7, RCS Loops -MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one SDC train is in operation.
In accordance with the Surveillance Frequency Control Program SR 3.4.7.2 Verify required SG secondary side water In accordance level is 25%. with the Surveillance Frequency Control Program SR 3.4.7.3 Verify correct breaker alignment and In accordance indicated power available to the required with the SDC pump that is not in operation.
Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.7-3 AMENDMENT NO.
RCS Loops -MODE 5, Loops Not Filled 3.4.8 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. Required SDC trains B.1 Suspend all Immediately inoperable, operations involving OR reduction of RCS boron concentration.
No SDC train in AND operation.
B.2 Initiate action to Immediately restore one SDC train to OPERABLE status and operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one SDC train is in operation.
In accordance with the Surveillance Frequency Control Program SR 3.4.8.2 Verify correct breaker alignment and In accordance indicated power available to the required with the SDC pump that is not in operation.
Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.8-2 AMENDMENT NO.
Pressurizer 3.4.9 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion AND Time of Condition B not met. C.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is 27% and In accordance 56% with the Surveillance Frequency Control Program SR 3.4.9.2 Verify capacity of each required group of In accordance pressurizer heaters 125 kW. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.9-2 AMENDMENT NO.
Pressurizer Safety Valves-MODE 4 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 Verify the required pressurizer safety In accordance valve is OPERABLE in accordance with the with the Inservice Testing Program. Following Inservice testing, lift settings shall be within Testing Program+/- 1%.SR 3.4.11.2 ------------------
NOTE--------------
Only required to be performed when a Shutdown Cooling System suction line relief valve is being used for overpressure In accordance protection.
with the Surveillance Frequency Verify the required Shutdown Cooling System Control Program suction line relief valve is aligned to provide overpressure protection for the RCS.SR 3.4.11.3 Verify the required Shutdown Cooling System In accordance suction line relief valve is OPERABLE with with the the required setpoint.
Inservice Testing Program PALO VERDE UNITS 1,2,3 3.4.11-2 AMENDMENT NO. 44-ý,
Pressurizer Vents 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.12 Pressurizer Vents LCO 3.4.12 APPLICABILITY:
Four pressurizer vent paths shall be OPERABLE.MODES 1, 2, and 3.MODE 4 with RCS pressure 385 psia.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Two or three required A.1 Restore required 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> pressurizer vent paths pressurizer vent inoperable, paths to OPERABLE status.B. All pressurizer vent B.1 Restore one 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> paths inoperable, pressurizer vent path to OPERABLE status.C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion AND Time of Condition A, or B not met. C.2 Be in MODE 4 with RCS 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> pressure < 385 psia.PALO VERDE UNITS 1.2,3 3.4.12-1 AMENDMENT NO. 4-14, Pressurizer Vents 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Perform a complete cycle of each In accordance Pressurizer Vent Valve. with the Surveillance Frequency Control Program SR 3.4.12.2 Verify flow through each In accordance pressurizer vent path. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.12-2 AMENDMENT NO. 444, LTOP System 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 Verify RCS Vent 16 square inches is In accordance open. with the Surveillance Frequency Control Program SR 3.4.13.2 Verify each Shutdown Cooling System In accordance suction line relief valve is aligned to with the provide overpressure protection for the Surveillance RCS. Frequency Control Program SR 3.4.13.3 Verify each Shutdown Cooling System In accordance suction line relief valve is OPERABLE with the with the required setpoint.
Inservice Testing Program.PALO VERDE UNITS 1,2,3 3.4.13-3 AMENDMENT NO.
RCS Operational LEAKAGE 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 -----------------
NOTES--------------
- 1. Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after establishment of steady state operation.
- 2. Not applicable to primary to secondary LEAKAGE Perform RCS water inventory balance.In accordance with the Surveillance Frequency Control Program 4 T SR 3.4.14.2---------------
NOTE- -------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after establishment of steady state operation.
Verify primary to secondary LEAKAGE is 150 gallons per day through any one SG.In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.14-2 AMENDMENT NO. ;.6;,
RCS PIV Leakage 3.4.15 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion AND Time for Condition A not met. B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1------------------
NOTES----------------
- 1. Not required to be performed in MODES 3 and 4.2. Not required to be performed on the RCS PIVs located in the SDC flow path when in the shutdown cooling mode of operation.
- 3. RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided.Verify leakage from each RCS PIV is equivalent to 0.5 gpm per nominal valve size up to a maximum of 5 gpm RCS pressure 2230 psia and 2270 inch of at an psia.In accordance with the Surveillance Frequency Control Program AND Prior to entering MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months, except for SDC PIVs AND (continued)
PALO VERDE UNITS 1,2,3 3.4.15-2 AMENDMENT NO. 11-7, RCS PIV Leakage 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 4 SR 3.4.15.1 (continued)
Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> following valve actuation due to automatic or manual action or flow through the valve, except for SDC PIVs.SR 3.4.15.2 Verify SDC System open permissive interlock In accordance prevents the valves from being opened with with the a simulated or actual RCS pressure signal Surveillance
> 410 psia. Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.15-3 AMENDMENT NO. 444, RCS Leakage Detection Instrumentation 3.4.16 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. Required containment B.1.1 Analyze grab samples Once per atmosphere of the containment 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> radioactivity monitor atmosphere.
OR B.1.2 Perform SR 3.4.14.1.
Once per AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> B.2 Restore required 30 days containment atmosphere radioactivity monitor to OPERABLE status.C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion AND Time not met.C.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> D. All required monitors D.1 Enter LCO 3.0.3 Immediately inoperable.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Perform CHANNEL CHECK of the required In accordance containment atmosphere radioactivity with the monitor. Surveillance Frequency Control Program SR 3.4.16.2 Perform CHANNEL FUNCTIONAL TEST of the In accordance required containment atmosphere with the radioactivity monitor. Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.4.16-2 AMENDMENT NO. -ý65, RCS Leakage Detection Instrumentation 3.4.16 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.4.16.3 Perform CHANNEL CALIBRATION of the required In accordance containment sump monitor. with the Surveillance Frequency Control Program SR 3.4.16.4 Perform CHANNEL CALIBRATION of the required In accordance containment atmosphere radioactivity with the monitor. Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.16-3 AMENDMENT NO. ;-I-;,
RCS Specific Activity 3.4.17 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3 with 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Tcold< 500 0 F.Time of Condition A not met.OR DOSE EQUIVALENT 1-131 in the unacceptable region of Figure 3.4.17-1.C. Gross specific C.1 Perform SR 3.4.17.2.
4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> activity of the reactor coolant not AND within limit.C.2 Be in MODE 3 with 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Tco1 d< 500 0 F.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify reactor coolant gross specific In accordance with activity IO0/E pCi/gm. the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.4.17-2 AMENDMENT NO. 44ý,
RCS Specific Activity 3.4.17 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.4.17.2 Verify reactor coolant DOSE EQUIVALENT 1-131 specific activity< 1.0 pCi/gm.-NOTE ------Only required to be performed in MODE 1.In accordance with the Surveillance Frequency Control Program AND Between 2 and 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after THERMAL POWER change of 15% RTP within a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period SR 3.4.17.3-------- -------NOTE-------------
Not required to be performed until 31 days after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />.Determine E from a sample taken in MODE 1 after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />.In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.17-3 AMENDMENT NO. ý,
SITs-Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each SIT isolation valve is fully In accordance open. with the Surveillance Frequency Control Program SR 3.5.1.2 Verify borated water volume in each SIT is In accordance 28% narrow range and 72% narrow range. with the Surveillance Frequency Control Program SR 3.5.1.3 Verify nitrogen cover pressure in each SIT In accordance is 600 psig and 625 psig. with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.5.1-2 AMENDMENT NO.
SITs-Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.5.1.4 Verify boron concentration in each SIT is> 2300 ppm and 4400 ppm.In accordance with the Surveillance Frequency Control Program AND----- NOTE ------Only required to be performed for affected SIT Once within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, whenever a SIT is drained to maintain the contai ned borated water level within the limits of SR 3.5.1.2.SR 3.5.1.5 Verify power is removed from each SIT In accordance isolation valve operator.
with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.5.1-3 AMENDMENT NO.
SITs-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify each required SIT isolation valve is In accordance fully open when pressurizer pressure is with the> 430 psia. Surveillance Frequency Control Program SR 3.5.2.2 Verify borated water volume in each In accordance required SIT is: with the a. For four OPERABLE SITs, > 39% wide Surveillance range indication and < 83% wide range Frequency indication.
Control Program OR b. For three OPERABLE SITs, > 60% wide range indication and < 83% wide range indication.
SR 3.5.2.3 Verify nitrogen cover pressure in each In accordance required SIT is 260 psig and 625 psig. with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.5.2-2 AMENDMENT NO.
SITs-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.5.2.4 Verify boron concentration in each required SIT is 2300 ppm and 4400 ppm.In accordance with the Survei 1 lance Frequency Control Program AND----- NOTE ------Only required to be performed for affected SIT Once within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, whenever a required SIT is drained to maintain the contai ned borated water level within the limits of SR 3.5.2.2.SR 3.5.2.5 Verify power is removed from each required In accordance SIT isolation valve operator when with the pressurizer pressure is 1500 psia. Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.5.2-3 AMENDMENT NO.
ECCS -Operating 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify each ECCS manual, power operated, In accordance and automatic valve in the flow path, that with the is not locked, sealed, or otherwise secured Surveillance in position, is in the correct position.
Frequency Control Program SR 3.5.3.2 Verify ECCS piping is full of water. In accordance with the Surveillance Frequency Control Program SR 3.5.3.3 Verify each ECCS pump develops the required In accordance differential pressure at the flow test with the point. Inservice Testing Program SR 3.5.3.4 Verify each ECCS automatic valve that is In accordance not locked, sealed, or otherwise secured in with the position, in the flow path actuates to the Surveillance correct position on an actual or simulated Frequency actuation signal. Control Program SR 3.5.3.5 Verify each ECCS pump starts automatically In accordance on an actual or simulated actuation signal. with the Surveillance Frequency Control Program SR 3.5.3.6 Verify each LPSI pump stops on an actual or In accordance simulated actuation signal. with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.5.3-2 AMENDMENT NO. 444, ECCS -Operating 3.5.3 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.5.3.7 Verify, for each ECCS throttle valve listed below, each position stop is in the correct position.In accordance with the Surveillance Frequency Control Program LPSI System Valve Number Hot Leg Injection Valve Numbers SIB-UV SIB-UV SIA-UV SIA-UV SIA-HV SIB-HV 615 625 635 645 306 307 SIC-HV 321 SID-HV 331 SR 3.5.3.8 Verify, by visual inspection, each ECCS In accordance train containment sump suction inlet is not with the restricted by debris and the suction inlet Surveillance strainers show no evidence of structural Frequency distress or abnormal corrosion.
Control Program PALO VERDE UNITS 1,2,3 3.5.3-3 AMENDMENT NO. 74, RWT 3.5.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 -----------------
NOTE--------------
Only required to be performed when ambient air temperature is < 60°F or > 120 0 F.Verify RWT borated water temperature is In accordance 60°F and 120 0 F. with the Surveillance Frequency Control Program SR 3.5.5.2 Verify RWT borated water volume is In accordance
> minimum required RWT volume in with the Figure 3.5.5-1. Surveillance Frequency Control Program SR 3.5.5.3 Verify RWT boron concentration is In accordance 4000 ppm and 4400 ppm. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.5.5-2 AMENDMENT NO. 14-;L, TSP 3.5.6 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)3.5.6 Trisodium Phosphate (TSP)LCO 3.5.6 APPLICABILITY:
The TSP baskets shall contain 524 ft 3 of active TSP.MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. TSP not within limits. A.1 Restore TSP to within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> limits.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion AND Time not met.B.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.6.1 Verify the TSP baskets contain 524 ft 3 of In accordance granular anhydrous trisodium phosphate.
with the Surveillance Frequency Control Program SR 3.5.6.2 Verify that a sample from the TSP baskets In accordance provides adequate pH adjustment of borated with the water. Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.5.6-1 AMENDMENT NO. 444, Containment Air Locks 3.6.2 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion AND Time not met.D.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1 -----------------
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.Perform required air lock leakage rate In accordance testing in accordance with the Containment with the Leakage Rate Testing Program. Containment Leakage Rate Testing Program SR 3.6.2.2 Verify only one door in the air lock can be In accordance opened at a time. with the Survei 1 lance Frequency Control Program PALO VERDE UNITS 1,2,3 3.6.2-4 AMENDMENT NO. ý,
Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each required 42 inch purge valve is In accordance sealed closed except for one purge valve in with the a penetration flow path while in Surveillance Condition D of this LCO. Frequency Control Program SR 3.6.3.2 Verify each 8 inch purge valve is closed In accordance except when the 8 inch purge valves are with the open for pressure control, ALARA or air Surveillance quality considerations for personnel entry, Frequency or for Surveillances that require the Control Program valves to be open.SR 3.6.3.3 -----------------
NOTE----------------
Valves and blind flanges in high radiation areas may be verified by use of administrative means.Verify each containment isolation manual In accordance valve and blind flange that is located with the outside containment and not locked, sealed Surveillance or otherwise secured and is required to be Frequency closed during accident conditions is Control Program closed, except for containment isolation valves that are open under administrative controls.(continued)
PALO VERDE UNITS 1,2,3 3.6.3-5 AMENDMENT NO. ;464, Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY i SR 3.6.3.4 -----------------
NOTE---------------
Valves and blind flanges in high radiation areas may be verified by use of administrative means.Verify each containment isolation manual valve and blind flange that is located inside containment and not locked, sealed or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days SR 3.6.3.5 Verify the isolation time of each required In automatic power operated containment accordance isolation valve is within limits, with the Inservice Testing Program SR 3.6.3.6 Perform leakage rate testing for required In accordance with containment purge valves with resilient the Surveillance seals. Frequency Control Program AND Within 92 days after opening the valve SR 3.6.3.7 Verify each required automatic containment In accordance with isolation valve that is not locked, sealed, the Surveillance or otherwise secured in position, actuates Frequency Control to the isolation position on an actual or Program simulated actuation signal.PALO VERDE UNITS 1,2,3 3.6.3-6 AMENDMENT NO. 4-64, Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 APPLICABILITY:
Containment pressure shall be -0.3 psig and +2.5 psig.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment pressure A.1 Restore containment 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> not within limits, pressure to within limits.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within In accordance limits. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.6.4-1 AMENDMENT NO.
Containment Air Temperature 3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 APPLICABILITY:
Containment average air temperature shall be 117'F.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment average A.1 Restore containment 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> air temperature not average air within limit, temperature to within limit.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment average air temperature In accordance is within limit. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.6.5-1 AMENDMENT NO. 44--ý,
Containment Spray System 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power In accordance operated, and automatic valve in the flow with the path that is not locked, sealed, or Surveillance otherwise secured in position is in the Frequency correct position.
Control Program SR 3.6.6.2 Verify the containment spray piping is In accordance full of water to the 113 ft level in the with the containment spray header. Surveillance Frequency Control Program SR 3.6.6.3 Verify each containment spray pump's In accordance developed head at the flow test point is with the greater than or equal to the required Inservice developed head. Testing Program SR 3.6.6.4 Verify each automatic containment spray In accordance valve in the flow path that is not locked, with the sealed, or otherwise secured in position, Surveillance actuates to the correct position on an Frequency actual or simulated actuation signal. Control Program SR 3.6.6.5 Verify each containment spray pump starts In accordance automatically on an actual or simulated with the actuation signal. Surveillance Frequency Control Program SR 3.6.6.6 Verify each spray nozzle is unobstructed.
In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.6.6-2 AMENDMENT NO.
ADVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each ADV. In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.7.4-2 AMENDMENT NO.
AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify each AFW manual, power operated, and In accordance automatic valve in each water flow path and with the in both steam supply flow paths to the Surveillance steam turbine driven pump, that is not Frequency locked, sealed, or otherwise secured in Control Program position, is in the correct position.SR 3.7.5.2 -----------------
NOTE----------------
Not required to be performed for the turbine driven AFW pump until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after reaching 532 0 F in the RCS.Verify the developed head of each AFW pump In accordance at the flow test point is greater than or with the equal to the required developed head. Inservice Test Program SR 3.7.5.3 -----------------
NOTES--------------
- 1. Not required to be performed for the turbine driven AFW pump until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after reaching 532 0 F in the RCS.2. Not applicable in MODE 4 when steam generator is relied upon for heat removal.Verify each AFW automatic valve that is not In accordance locked, sealed, or otherwise secured in with the position, actuates to the correct position Surveillance on an actual or simulated actuation signal. Frequency Control Program (continued)
PALO VERDE UNITS 1,2.3 3.7.5-3 AMENDMENT NO.
AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY I.SR 3.7.5.4 -----------------
NOTES--------------
- 1. Not required to be performed for the turbine driven AFW pump until 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after reaching 532 0 F in the RCS.2. Not applicable in MODE 4 when steam generator is relied upon for heat removal.Verify each AFW pump starts automatically on an actual or simulated actuation signal In accordance with the Surveillance Frequency Control Program SR 3.7.5.5 Verify the proper alignment of the required Prior to AFW flow paths by verifying flow from the entering MODE 2 condensate storage tank to each steam whenever unit generator.
has been in MODE 5 or 6 for> 30 days PALO VERDE UNITS 1,2,3 3.7.5-4 AMENDMENT NO.
CST 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Condensate Storage Tank (CST)LCO 3.7.6 The CST level shall be 29.5 ft.APPLICABILITY:
MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. CST level not within A.1 Verify OPERABILITY of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> limit. backup water supply.AND Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter AND A.2 Restore CST level to 7 days within limit B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4 without 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> reliance on steam generator for heat removal.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify CST level is 29.5 ft. In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.7.6-1 AMENDMENT NO. 444, EW System 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 -----------------
NOTE---------------
Isolation of EW flow to individual components does not render the EW System inoperable.
Verify each EW manual, power operated, and automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.In accordance with the Surveillance Frequency Control Program SR 3.7.7.2 Verify each EW automatic valve in the flow In accordance path that is not locked, sealed, or with the otherwise secured in position, actuates to Surveillance the correct position on an actual or Frequency simulated actuation signal. Control Program SR 3.7.7.3 Verify each EW pump starts automatically on In accordance an actual or simulated actuation signal. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.7.7-2 AMENDMENT NO. 444, ESPS 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 -----------------
Notes--------------
Isolation of ESPS flow to individual components does not render ESPS inoperable.
Verify each ESPS manual and power operated In accordance valve in the flow path servicing safety with the related equipment, that is not locked, Surveillance sealed, or otherwise secured in position, Frequency is in the correct position.
Control Program SR 3.7.8.2 Verify each ESPS pump starts automatically In accordance on an actual or simulated actuation signal. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.7.8-2 AMENDMENT NO. ý,
UHS 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Ultimate Heat Sink (UHS)LCO 3.7.9 APPLICABILITY:
The UHS shall be OPERABLE.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. UHS inoperable.
A.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> AND A.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Verify the usable water depth of each In accordance essential spray pond is 12 feet. with the Surveillance Frequency Control Program SR 3.7.9.2 Verify water temperature of each essential In accordance spray pond is 89 0 F. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.7.9-1 AMENDMENT NO. 44-ý,
EC 3.7.10 3.7 PLANT SYSTEMS 3.7.10 Essential Chilled Water (EC) System LCO 3.7.10 APPLICABILITY:
Two EC trains shall be OPERABLE.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One EC train A.1 Restore EC train to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable.
OPERABLE status.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Verify each EC System manual, power In accordance operated, and automatic valve in the flow with the path, that is not locked, sealed, or Surveillance otherwise secured in position, is in the Frequency correct position.
Control Program SR 3.7.10.2 Verify the proper actuation of each EC In accordance System component on an actual or simulated with the actuation signal. Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.7.10-1 AMENDMENT NO. 44-7-,
CREFS 3.7.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Operate each CREFS train for 15 minutes. In accordance with the Surveillance Frequency Control Program SR 3.7.11.2 Perform required CREFS filter testing in In accordance accordance with the Ventilation Filter with the VFTP Testing Program (VFTP).SR 3.7.11.3 Verify each CREFS train actuates on an In accordance actual or simulated actuation signal. with the Surveillance Frequency Control Program SR 3.7.11.4 Perform required CRE unfiltered air In accordance inleakage testing in accordance with the with the Control Control Room Envelope Habitability Program. Room Envelope Habitability Program.PALO VERDE UNITS 1,2,3 3.7.11-3 AMENDMENT NO. 4-4, CREATCS 3.7.12 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME E. Two CREATCS trains E.1 Suspend CORE Immediately inoperable in MODE 5 ALTERATIONS.
or 6, or during movement of irradiated AND fuel assemblies.
E.2 Suspend movement of Immediately irradiated fuel assemblies.
F. Two CREATCS trains F.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, 3, or 4.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 Verify each CREATCS train has the In accordance capability to remove the assumed heat load. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.7.12-2 AMENDMENT NO. ;4--ý,
ESF PREACS 3.7.13 3.7 PLANT SYSTEMS 3.7.13 Engineered Safety Feature (ESF) Pump Room Exhaust System (PREACS)Air Cleanup LCO 3.7.13 APPLICABILITY:
Two ESF PREACS trains shall be OPERABLE.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One ESF PREACS train A.1 Restore ESF PREACS 7 days inoperable, train to OPERABLE status.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.13.1 Operate each ESF PREACS train for In accordance
>15 minutes with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.7.13-1 AMENDMENT NO. 4-14, ESF PREACS 3.7.13 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.7.13.2 Perform required ESF PREACS filter testing In accordance in accordance with the Ventilation Filter with the VFTP Testing Program (VFTP).SR 3.7.13.3 Verify each ESF PREACS train actuates on an In accordance actual or simulated actuation signal. with the Surveillance Frequency Control Program SR 3.7.13.4 Verify one ESF PREACS train can maintain a In accordance measurable negative pressure relative to with the atmospheric pressure during operation at a Surveillance flowrate of 6000 cfm +/-10%. Frequency Control Program PALO VERDE UNITS 1,2,3 3.7.13-2 AMENDMENT NO.
Fuel Storage Pool Water Level 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Fuel Storage Pool Water Level LCO 3.7.14 APPLICABILITY:
The fuel storage pool water level shall be 23 ft over the top of irradiated fuel assemblies seated in the storage racks.During movement of irradiated fuel assemblies in the fuel storage pool.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool A.1 --------NOTE-------
water level not within LCO 3.0.3 is not limit. applicable.
Suspend movement of Immediately irradiated fuel assemblies in fuel storage pool.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.14.1 Verify the fuel storage pool water level is In accordance
> 23 ft above the top of irradiated fuel with the assemblies seated in the storage racks. Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.7.14-1 AMENDMENT NO. 44-ý,
Fuel Storage Pool Boron Concentration 3.7.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.15.1 Verify the fuel storage pool boron In accordance concentration is within limit, with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.7.15-2 AMENDMENT NO. 147ý,
Secondary Specific Activity 3.7.16 3.7 PLANT SYSTEMS 3.7.16 Secondary Specific Activity LCO 3.7.16 APPLICABILITY:
The specific activity of the secondary coolant shall be< 0.10 pCi/gm DOSE EQUIVALENT 1-131.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Specific activity not A.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> within limit.AND A.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.16.1 Verify the specific activity of the In accordance secondary coolant is within limit, with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.7.16-1 AMENDMENT NO. ;44, AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and In accordance indicated power availability for each with the required offsite circuit. Surveillance Frequency Control Program SR 3.8.1.2 ------------------
NOTES---------------
- 1. Performance of SR 3.8.1.7 satisfies this SR.2. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.3. A modified DG start involving 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.4. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.Verify each DG starts from standby In accordance condition and achieves steady state with the voltage 4000 V and 4377.2 V, and Surveillance frequency 59.7 Hz and 60.7 Hz. Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.8.1-6 AMENDMENT NO. 4-59, AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.3 ------------------
NOTES----------------
- 1. DG loadings may include gradual loading as recommended by the manufacturer.
- 2. Momentary transients outside the load range do not invalidate this test.3. This Surveillance shall be conducted on only one DG at a time.4. This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7.Verify each DG is synchronized and loaded, In accordance and operates for > 60 minutes at a load with the> 4950 kW and _< 5500 kW. Surveillance Frequency Control Program SR 3.8.1.4 Verify each day tank contains > 550 gal of In accordance fuel oil (minimum level of 2.75 feet). with the Surveillance Frequency Control Program SR 3.8.1.5 Check for and remove accumulated water from In accordance each day tank. with the Surveillance Frequency Control Program SR 3.8.1.6 Verify the fuel oil transfer system In accordance operates to automatically transfer fuel with the oil from the storage tank to the day tank. Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.8.1-7 AMENDMENT NO. 444, AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.7 -----------------
NOTE----------------
- 1. All DG starts may be preceded by an engine prelube period followed by a warmup period prior to loading.2. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.Verify each DG starts from standby In accordance condition and achieves with the a. In 10 seconds, voltage 3740 V and Surveillance frequency 58.8 Hz; and Frequency b. Steady state voltage 4000 V and Control Program 4377.2 V, and frequency 59.7 Hz and 60.7 Hz.SR 3.8.1.8 ------------------
NOTE--------------
This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Verify manual transfer of AC power sources In accordance from the normal offsite circuit to each with the alternate offsite circuit. Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.8.1-8 AMENDMENT NO. 4-56, AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.9 ------------------
NOTE--------------
This Surveillance shall not normally be performed in MODE 1. 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and: a. Following load rejection, the frequency is 64.5 Hz;b. Within 3 seconds following load rejection, the voltage is 3740 V and 4580 V; and c. Within 3 seconds following load rejection, the frequency is 58.8 Hz and 61.2 Hz.In accordance with the Surveillance Frequency Control Program SR 3.8.1.10-----------------
NOTE-------------
If performed with the DG synchronized with offsite power, it shall be performed at a power factor of 0.89. 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 DG does not trip, and is maintained 6200 V during and a load rejection of 4950 kW and< 5500 kW.vol tage following In accordance with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.8.1-9 AMENDMENT NO. 4.46ý,
AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.11 -----------------
NOTE----------------
- 1. All DG starts may be preceded by an engine prelube period.2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However. portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.3. Momentary voltage and frequency transients induced by load changes do not invalidate this test.4. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.Verify on an actual or simulated loss of In accordance offsite power signal: with the Surveillance
- a. De-energization of emergency buses; Frequency Control Program b. Load shedding from emergency buses;c. DG auto-starts and: 1. energizes permanently connected loads in 10 seconds, 2. energizes auto-connected emergency loads through automatic load sequencer, 3. maintains steady state voltage> 4000 V and 4377.2 V, 4. maintains steady state frequency> 59.7 Hz and 60.7 Hz, and 5. supplies permanently connected and auto-connected emergency loads for 5 minutes.(continued)
PALO VERDE UNITS 1,2,3 3.8.1-10 AMENDMENT NO. 4-5.4, AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.12---- ---- ---- ----NOTES--------------
- 1. All DG starts may be preceded by an engine prelube period.2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.3. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.Verify on an actual or simulated Engineered Safety Feature (ESF) actuation signal (without a loss of offsite power) each DG auto-starts and: a. In 10 seconds, achieves voltage 3740 V and frequency 58.8 Hz;b. Achieves steady state voltage 4000 and 4377.2 V and frequency 59.7 Hz and 60.7 Hz;c. Operates for 5 minutes on standby (running unloaded);
- d. Permanently connected loads remain energized from the offsite power system; and e. Emergency loads are energized (auto-connected through the automatic load sequencer) from the offsite power system.In accordance with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.8.1-11 AMENDMENT NO. 415&6, AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.13 Verify each DG automatic trip is bypassed on actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ESF actuation signal except: a. Engine overspeed;
- b. Generator differential current;c. Engine low lube oil pressure; and d. Manual emergency stop trip.In accordance with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.8.1-12 AMENDMENT NO. 4--&6, AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.14-------------
--NOTES --------------
- 1. Momentary transients outside the load range do not invalidate this test.2. If performed with the DG synchronized with offsite power, it shall be performed at a power factor of 0.89.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.
- 3. All DG starts may be preceded by an engine prelube period followed by a warmup period prior to loading.4. DG loading may include gradual loading as recommended by the manufacturer.
Verify each DG operates for 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s: a. For 22 hours2.546296e-4 days <br />0.00611 hours <br />3.637566e-5 weeks <br />8.371e-6 months <br /> loaded 4950 kW and 5500 kW; and b. For the remaining hours ( 2) of the test loaded 5775 kW and 6050 kW.In accordance with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.8.1-13 AMENDMENT NO.
AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
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, loaded 4950 kW and 5500 kW, has operated 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> or until temperatures have stabilized.
Momentary transients outside of load range do not invalidate this test.2. All DG starts may be preceded by an engine prelube period.3. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.Verify each DG starts and achieves a. In 10 seconds, voltage 2 3740 V and frequency 58.8 Hz; and b. Steady state voltage 4000 V and 4377.2 V, and frequency 59.7 Hz and 60.7 Hz.In accordance with the Surveillance Frequency Control Program SR 3.8.1.16 -----------------
NOTE--------------
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Verify each DG: a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;b. Transfers loads to offsite power source: and c. Returns to ready-to-load operation.
In accordance with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.8.1-14 AMENDMENT NO. 4-569, AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.17-------------------
NOTE---------------
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Verify, with a DG operating in test mode and connected to its bus, an actual or simulated ESF actuation signal overrides the test mode by: a. Returning DG to ready-to-load operation; and b. Automatically energizing the emergency load from offsite power.In accordance with the Surveillance Frequency Control Program i SR 3.8.1.18 -----------------
NOTE--------------
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Verify interval between each sequenced load block is within +/- 1 second of design interval for each automatic load sequencer.
In accordance with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.8.1-15 AMENDMENT NO. 56, AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.19-------------------
NOTES--------------
- 1. All DG starts may be preceded by an engine prelube period.2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.3. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.Verify on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ESF actuation signal: a. De-energization of emergency buses;b. Load shedding from emergency buses: c. DG auto-starts from standby condition and: 1. energizes permanently connected loads in 10 seconds, 2. energizes auto-connected emergency loads through load sequencer, 3. achieves steady state voltage> 4000 V and 4377.2 V, 4. achieves steady state frequency> 59.7 Hz and 60.7 Hz, and 5. supplies permanently connected and auto-connected emergency loads for 5 minutes.In accordance with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.8.1-16 AMENDMENT NO. 4-546, AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.20---- ---- ---- ----NOTES --------------
- 1. All DG starts may be preceded by an engine prelube period.2. The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.Verify, when started simultaneously, each DG achieves a. In 10 seconds, voltage 3740 V and frequency 58.8 Hz; and b. Steady state voltage 4000 V and 4377.2 V, and frequency 59.7 Hz and 60.7 Hz.In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2,3 3.8.1-17 AMENDMENT NO. 4-56, Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains In accordance
>80% indicated fuel level, with the Survei 1 lance Frequency Control Program SR 3.8.3.2 Verify lubricating oil inventory is In accordance
> 2.5 inches visible in the sightglass.
with the Surveillance Frequency Control Program SR 3.8.3.3 Verify fuel oil properties of new and In accordance stored fuel oil are tested in accordance with the Diesel with, and maintained within the limits of, Fuel Oil the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.4 Verify each DG starting air receiver In accordance pressure is 230 psig. with the Surveillance Frequency Control Program SR 3.8.3.5 Check for and remove accumulated water from In accordance each fuel oil storage tank. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.8.3-3 AMENDMENT NO. 444, DC Sources -Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is 129 V In accordance on float charge. with the Surveillance Frequency Control Program SR 3.8.4.2 Verify no visible corrosion at battery In accordance terminals and connectors, with the Surveillance OR Frequency Control Program Verify battery connection resistance is" 150E-6 ohms for inter-cell connections." 150E-6 ohms for inter-rack connections." 150E-6 ohms for inter-tier connections.
and 150E-6 ohms for terminal connections.
SR 3.8.4.3 Verify battery cells, cell plates, and In accordance racks show no visual indication of physical with the damage or abnormal deterioration that could Surveillance degrade battery performance.
Frequency Control Program SR 3.8.4.4 Remove visible terminal corrosion and In accordance verify battery cell to cell and terminal with the connections are clean, and are coated with Surveillance anti-corrosion material.
Frequency Control Program SR 3.8.4.5 Verify battery connection resistance is In accordance" 150E-6 ohms for inter-cell connections, with the" 150E-6 ohms for inter-rack connections.
Surveillance
< 150E-6 ohms for inter-tier connections.
Frequency and 150E-6 ohms for terminal connections.
Control Program (continued)
PALO VERDE UNITS 1,2,3 3.8.4-2 AMENDMENT NO. 4759, DC Sources -Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.4.6-------------------
NOTE---------------
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4 on the charger credited for OPERABILITY.
However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Verify each battery charger supplies* 400 amps for Batteries A and B and* 300 amps for Batteries C and D at* 125 V for 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.In accordance with the Surveillance Frequency Control Program SR 3.8.4.7 -----------------
NOTES--------------
- 1. The battery performance discharge test or the modified performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test in SR 3.8.4.7.2. This Surveillance shall not be performed in MODE 1, 2, 3, or 4.Verify battery capacity is adequate to supply, and 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 (continued)
PALO VERDE UNITS 1,2,3 3.8.4-3 AMENDMENT NO. 4-56, DC Sources -Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE I FREQUENCY SR 3.8.4.8 -----------------
NOTE-This Surveillance shall not be performed in MODE 1, 2, 3, or 4.Verify battery capacity is 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test.In accordance with the Surveillance Frequency Control Program AND 12 months when battery shows degradation or has reached 85%of the expected life with capacity< 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected life with capacity 100% of manufacturer's rating PALO VERDE UNITS 1,2,3 3.8.4-4 AMENDMENT NO. 4-59, Battery Cell Parameters 3.8.6 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Declare associated Immediately associated Completion battery inoperable.
Time of Condition A not met.OR One or more batteries with average electrolyte temperature of the representative cells< 60 0 F.OR One or more batteries with one or more battery cell parameters not within Category C limits.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet In accordance Table 3.8.6-1 Category A limits, with the Surveillance Frequency Control Program (continued)
PALO VERDE UNITS 1,2,3 3.8.6-2 AMENDMENT NO. ý44, Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify battery cell parameters meet In accordance with Table 3.8.6-1 Category B limits, the Surveillance Frequency Control Program AND Once within 7 days after battery discharge< 105 V AND Once within 7 days after battery overcharge
> 150 V SR 3.8.6.3 Verify average electrolyte temperature of In accordance representative cells is 60'F. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.8.6-3 AMENDMENT NO. 4-1-;,
Inverters
-Operating 3.8.7 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, frequency, In accordance and alignment to required AC vital with the instrument buses. Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.8.7-2 AMENDMENT NO.
Inverters
-Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)
A.2.4 Initiate action to Immediately restore required inverters to OPERABLE status.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage, frequency, In accordance and alignments to required AC vital with the instrument buses. Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.8.8-2 AMENDMENT NO.
Distribution Systems -Operating 3.8.9 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. One DC electrical C.1 Restore DC electrical 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> power distribution power distribution AND subsystems inoperable, subsystem to OPERABLE status. 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> from discovery of failure to meet LCO D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion AND Time not met.D.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> E. Two or more inoperable E.1 Enter LCO 3.0.3. Immediately distribution subsystems that result in a loss of safety function.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and In accordance voltage to required AC, DC, and AC vital with the instrument bus electrical power Surveillance distribution subsystems.
Frequency Control Program PALO VERDE UNITS 1,2,3 3.8.9-2 AMENDMENT NO. ý44, Distribution Systems -Shutdown 3.8.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)
A.2.4 Initiate actions to Immediately restore required AC, DC, and AC vital instrument bus electrical power distribution subsystems to OPERABLE status.AND A.2.5 Declare associated Immediately required shutdown cooling subsystem(s) inoperable and not in operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and In accordance voltage to required AC, DC, and AC vital with the instrument bus electrical power Surveillance distribution subsystems.
Frequency Control Program PALO VERDE UNITS 1,2,3 3.8.10-2 AMENDMENT NO. 44--ý.
Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 APPLICABILITY:
Boron concentrations of the Reactor Coolant System and the refueling canal shall be maintained within the limit specified in the COLR.MODE 6.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration A.1 Suspend CORE Immediately not within limit. ALTERATIONS.
AND A.2 Suspend positive Immediately reactivity additions.
AND A.3 Initiate action to Immediately restore boron concentration to within limit.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the In accordance limit specified in the COLR. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.1-1 AMENDMENT NO. ;4--ý,
Nuclear Instrumentation 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.9.2.2 -----------------
NOTE----------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION.
In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2,3 3.9.2-2 AMENDMENT NO. ;4-ý,
Containment Penetrations 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify each required containment In accordance penetration is in the required status. with the Surveillance Frequency Control Program SR 3.9.3.2 Verify each required containment purge and In accordance exhaust valve actuates to the isolation with the position on an actual or simulated Surveillance actuation signal. Frequency Control Program SR 3.9.3.3 Verify the capability to close the In accordance equipment hatch, if open with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.3-2 AMENDMENT NO. 44ý,
SDC and Coolant Circulation -High Water Level 3.9.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)
A.4 Close all containment 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> penetrations providing direct access from containment atmosphere to outside atmosphere.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify one SDC loop is operable and in In accordance operation.
with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.4-2 AMENDMENT NO. 44-ý,
SDC and Coolant Circulation
-Low Water Level 3.9.5 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. No SDC loop OPERABLE B.1 Suspend operations Immediately or in operation.
involving a reduction in reactor coolant boron concentration.
AND B.2 Initiate action to Immediately restore one SDC loop to OPERABLE status and to operation.
AND B.3 Close all 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> containment penetrations providing direct access from containment atmosphere to outside atmosphere.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify required SDC loops are OPERABLE and In accordance one SDC loop is in operation.
with the Surveillance Frequency Control Program SR 3.9.5.2 Verify correct breaker alignment and In accordance indicated power available to the required with the SDC pump that is not in operation.
Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.5-2 AMENDMENT NO.
Refueling Water Level-Fuel Assemblies 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Refueling Water Level-Fuel Assemblies LCO 3.9.6 APPLICABILITY:
Refueling water level shall be maintained 23 ft above the top of the reactor vessel flange.During movement of fuel assemblies within containment when either the fuel assemblies being moved or the fuel assemblies seated within the reactor vessel are irradiated.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling water level A.1 Suspend movement of Immediately not within limit, fuel assemblies within containment.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify refueling water level is 23 ft In accordance above the top of reactor vessel flange. with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.6-1 AMENDMENT NO. 44;,
Refueling Water Level-CEAs 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Refueling Water Level-CEAs LCO 3.9.7 APPLICABILITY:
Refueling water level shall be maintained 23 ft above the top of irradiated fuel assemblies seated within the reactor vessel.During movement of CEAs within the reactor vessel, when the fuel assemblies seated within the reactor vessel are irradiated.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling water level A.1 Suspend movement of Immediately not within limit. CEAs within the reactor vessel.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling water level is 23 ft In accordance above the top of irradiated fuel assemblies with the seated within the reactor vessel. Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.7-1 AMENDMENT NO.
Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.17 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 Essential Filtration System (CREFS), 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 whole body or its equivalent to any part of the body 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 in accordance with the testing methods and the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Determining Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.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 of one train of the CREFS, operating at the flow rate required by the VFTP, at a Frequency of 18 months on a-STAGGERED TEST BASIS. The results shall be trended and used as part of the periodic assessment of the CRE boundary.e. The quantitative limits on unfiltered air inleakage into the CRE shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph
- c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences.
- 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.(continued)
PALO VERDE UNITS 1.2.3 5.5-17 AMENDMENT NO. 44-ý.
Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.18 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. Charges of 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.PALO VERDE UNITS 1.2.3 5.5-18 AMENDMENT NO.
Attachment 5 Proposed Technical Specification Bases Changes (Based on Revision 54)Pages B 3.1.1-6 B3.3.3-10 B 3.4.8-3 B 3.6.6-7 B 3.8.1-42 B 3.1.2-9 B3.3.3-11 B 3.4.9-5 B 3.6.6-8 B 3.8.1-43 B 3.1.3-6 B3.3.3-12 B 3.4.9-6 B 3.7.4-5 B 3.8.1-44 B 3.1.5-10 B 3.3.4-13 B 3.4.11-5 B 3.7.5-8 B 3.8.1-45 B 3.1.5-11 B 3.3.4-14 B 3.4.12-4 B 3.7.5-9 B 3.8.1-46 B 3.1.6-5 B 3.3.4-15 B 3.4.13-9 B 3.7.5-10 B 3.8.3-6 B 3.1.7-8 B 3.3.5-26 B 3.4.13-10 B 3.7.6-4 B 3.8.3-7 B 3.1.7-9 B 3.3.5-27 B 3.4.14-7 B 3.7.7-4 B 3.8.3-9 B 3.1.8-5 B 3.3.5-28 B 3.4.14-8 B 3.7.7-5 B 3.8.4-6 B 3.1.9-5 B 3.3.5-29 B 3.4.15-5 B 3.7.8-4 B 3.8.4-7 B 3.1.9-6 B 3.3.6-19 B 3.4.15-6 B 3.7.9-3 B 3.8.4-8 B 3.1.10-5 B 3.3.6-21 B 3.4.16-5 B 3.7.10-4 B 3.8.4-9 B 3.2.1-7 B 3.3.7-8 B 3.4.16-6 B 3.7.11-7 B 3.8.4-10 B 3.2.1-8 B 3.3.7-9 B 3.4.17-5 B 3.7.11-8 B 3.8.6-3 B 3.2.2-7 B 3.3.8-6 B 3.4.17-6 B 3.7.12-4 B 3.8.6-4 B 3.2.3-8 B 3.3.8-7 B 3.5.1-9 B 3.7.13-4 B 3.8.7-5 B 3.2.3-9 B 3.3.8-8 B 3.5.1-10 B 3.7.13-5 B 3.8.8-4 B3.2.4-8 B 3.3.9-5 B 3.5.2-9 B 3.7.14-3 B 3.8.8-5 B 3.2.4-9 B 3.3.9-6 B 3.5.2-10 B 3.7.15-2 B 3.8.9-10 B 3.2.5-6 B 3.3.9-7 B 3.5.3-8 B 3.7.16-3 B 3.8.10-4 B3.3.1-40 B 3.3.10-19 B 3.5.3-9 B 3.8.1-23 B 3.9.1-4 B3.3.1-41 B 3.3.10-20 B 3.5.3-10 B 3.8.1-25 B 3.9.2-3 B3.3.1-42 B 3.3.11-6 B 3.5.5-8 B 3.8.1-26 B 3.9.2-4 B3.3.1-43 B 3.3.11-7 B 3.5.5-9 B 3.8.1-27 B 3.9.3-5 B3.3.1-44 B 3.3.12-5 B 3.5.6-4 B 3.8.1-28 B 3.9.3-6 B3.3.1-46 B 3.3.12-6 B 3.5.6-5 B 3.8.1-30 B 3.9.4-4 B3.3.1-47 B 3.4.1-5 B 3.6.2-8 B 3.8.1-32 B 3.9.5-4 B3.3.1-48 B 3.4.2-2 B 3.6.3-16 B 3.8.1-33 B 3.9.5-5 B3.3.1-49 B 3.4.3-7 B 3.6.3-17 B 3.8.1-34 B 3.9.6-3 B 3.3.2-13 B 3.4.4-4 B 3.6.3-18 B 3.8.1-36 B 3.9.7-3 B 3.3.2-14 B 3.4.5-4 B 3.6.3-19 B 3.8.1-38 Insert B 3.3.2-15 B 3.4.5-5 B 3.6.4-3 B 3.8.1-39 B 3.3.2-16 B 3.4.6-5 B 3.6.5-3 B 3.8.1-40 B 3.3.2-17 B 3.4.7-6 B 3.6.6-6 B 3.8.1-41 SDM -Reactor Trip Breakers Open B 3.1.1 BASES (continued)
SURVEILLANCE The Fr.qucn.y of 21 hours2.430556e-4 days <br />0.00583 hours <br />3.472222e-5 weeks <br />7.9905e-6 months <br /> is based on the g.n..ally slo-REQUIREMENTS change in requir. d boron c.nccntration, and also allows (continued) sufficicnt time for the operator to co.l. et the requ data, Which includcs perfoming a boron concentratio analysis, and complete the calculation.
When taking credit Insert 1 for on concentrton..
.in the reactivity balance calclatonthe frequency may have to be administrat?*i;el controlled to ensure th-at SDM does not go below theli t due to Xenon decay REFERENCES
- 1. 10 CFR 50. Appendix A, GDC 26.2. UPSAR. Section 15.1.3. UFSAR, Section 15.4.4. 10 CFR 100.PALO VERDE UNITS 1,2,3 B 3.1.1-6 REVISION 31 SDM -Reactor Trip Breakers Closed B 3.1.2 BASES SURVEILLANCE REQUIREMENTS SR 3.1.2.1, 3.1.2.2 and 3.1.2.3 (continued)
The --,Fru of hr-enc of 21" "ho ibaed-A the gc-erraly slew change in required boPrn concentration, And it A1l9WS suifficient time for the operator.
to co-llect thereqird data,....
-.h incd per-for.ming a boron .onentr.ation Inset ~ anaysis an co Plt the calculation.
When taking cr-edit forp xenon conccntration in the r-eactivity bal-ance cailculation, the frequency may have to hc administratively contrlld to cnsurc that SONI does notgobl:thlit du---c to X-eno decay.-REFERENCES
- 1. 10 CFR 50, Appendix A, GDC 26.2. UFSAR, Section 15.1.3. UFSAR, Section 15.4.4. 10 CFR 100 PAL-9 VERDE UNITS 1,2,3 B 3.1.2-9 REVISION 4 Reactivity Balance B 3.1.3 BASES SURVEILLANCE REQUIREMENTS SR 3.1.3.1 (continued) is performed prior to entering MODE 1 as an initial check on core conditions and design calculations at BOC. The SR is modified by three Notes. The first Note indicates that the normalization of predicted core reactivity to the measured value may take place within the first 60 effective full power days (EFPD) after each fuel loading. This allows sufficient time for core conditions to reach steady state, but prevents operation for a large fraction of the fuel cycle without establishing a benchmark for the design calculati The required subsequcnt Frcuenecy ef 31 EFPD, iii.. 50 -._ EFPD I- ftePr- enter-ing MODE !, is insert 1 aceptablc.
bhascd on the slew: Pate of corc Ghangcs duct fiir'1A drn Rtin~d thr' ppqnrrpcr nF nth indieater" (C'ra uthl Tilt) for pronmpt indiction of-an anomaly.Note, "only required after 60 EFPD," is added to the Frequency column to allow this.A REFERENCES
- 1. 10 CFR 50, Appendix A, GDC 26, GDC 28, and GDC 29.2. UFSAR, Section 15.PALO VERDE UNITS 1,2,3 B 3.1.3-6 REVISION 4 CEA Alignment B 3.1.5 BASES ACTIONS D.1 (continued) could result in a situation outside the design basis and immediate action would be required to prevent any potential fuel damage. Immediately opening the reactor trip breakers minimizes these effects.SURVEILLANCE REQUIREMENTS SR 3.1.5.1 Verification that individual CEA positions are within 6.6 inches (indicated reed switch positions) of all other CEAs in the group -at -a 1-2 hour-allows the operator to detect a CEA that is beginning to deviate from its expected positi The specified F.que..Y takes into during actual CEA mtAion, dep:at, n than igmm pediatly, be SR 3.1.5.2 OPERABILITY of at least two CEA position indicator channels is required to determine CEA positions, and thereby ensure compliance with the CEA alignment and insertion limits. The CEA full in and full out limits provide an additional independent means for determining the CEA positions when the CEAs are at either their fully inserted or fully withdrawn position Insertilj" -"SR 3.1.5.3 Verifying each full strength CEA is trippable would require that each CEA be tripped. In MODES 1 and 2 tripping each full strength CEA would result in radial or axial power tilts, or oscillations.
Therefore individual full strength CEAs are exercised ee-y- 9-2-dys to provide increased confidence that all full strength CEAs continue to be trippable, even if they are not regularly tripped. A movement of 5 inches is adequate to demonstrate motion without exceeding the alignment limit when only one full strength CEA is in Th 92 day Fr.qUe..Y operato in thecontrol room and otervailalenc bi tein pterformC mor frqently......ad to the d.t.rmination.
o OPERABILITY of the CEAs (Ref. 3). Between required (continued)
PALO VERDE UNITS 1,2,3 B 3.1.5-10 REVISION 62=
CEA Alignment B 3.1.5 BASES SURVEILLANCE REQUIREMENTS SR 3.1.5.3 (continued) performances of SR 3.1.5.3, if a CEA(s) is discovered to be immovable but remains trippable and aligned, the CEA is considered to be OPERABLE.
At anytime, if a CEA(s) is immovable, a determination of the trippability (OPERABILITY) of that CEA(s) must be made, and appropriate action taken.SR 3.1.5.4 Performance of a CHANNEL FUNCTIONAL TEST of each reed switch position transmitter channel ensures the channel is OPERABLE and capable of indicatin CEA osit Since this test sclectcd.
ýopcoaincidg ceient ,ith ref-welin tat ws c-m ctDDATI UTUaTVy p h ryei11ancc perfor.-d-, t a Frguccy o one cer 8 mnth.- Fur-thermore,th Frcgcncytake ino acountothr-factors, which deternminc the OPE111ILITY othCERcdS'ih dctonSystem.
I Insert 11--...01, Ui UJ..., u.... .~.. L..... ... UL ... ..LJ ...,.... .. ....pos#itio comparisn and s-ensr- val i datioen: and ce-- The CALIBPRTIONs for the CPCs (SR 3.3.1.9) and at1 -mnh intervalsadi nocrapn et SR 3.1.5.5 Verification of full strength CEA drop times determines that the maximum CEA drop time permitted is consistent with the assumed drop time used in the safety analysis (Ref. 3).Measuring drop times prior to reactor criticality, after reactor vessel head removal, ensures the reactor internals and CEDM will not interfere with CEA motion or drop time, and that no degradation in these systems has occurred that would adversely affect CEA motion or drop time. Individual CEAs whose drop times are greater than safety analysis assumptions are not OPERABLE.
This SR is performed prior to criticality due to the plant conditions needed to perform the SR and the potential for an unplanned plant transient if the Surveillance were performed with the reactor at power.(continued)
PALO VERDE UNITS 1,2,3 B 3.1.5-11 REVISION 6 Shutdown CEA Insertion Limits B 3.1.6 BASES (continued)
SURVEILLANCE SR 3.1.6.1 (continued)
REQUIREMENTS Shutdown CEAs are considered fully withdrawn when each shutdown CEA is positioned to meet one of the following conditions:
Condition 1: " Pulse Counter > 147.75 inches.and" At least one Reed Switch Position Transmitter (RSPT) -> 145.25 inches.OR Condition 2:* Upper Electrical Limit (UEL) position.Condition 1 necessitates that the Pulse Counter and at least one of the two Reed Switch Position Transmitters (RSPTs) be available to verify the position of each shutdown CEA. The Pulse Counter is a very accurate position indication system but is not as reliable (i.e., slip rod) as the other position indicating systems. The RSPTs are very reliable but are not as accurate as the Pulse Counter indicating system. Therefore, requiring these two systems together will account for instrument inaccuracies and reliability issues associated with these position indicators (instrument inaccuracies and the acceptability of these indicator limits are detailed in Reference 4).Additionally, a CEA at its UEL (Upper Electrical Limit)position alone provides an acceptable indication (accounting for inaccuracies) of CEA position to satisfy the condition for a CEA to be considered fully withdrawn.
A CEA at its UEL position will be > 147.75 inches withdrawn Sinccp thc shutdown CEAs are positioned manually by thc at FequcnY Of 12 husi~s adequate to en-sure that the the operator in the co.ntirol room foA the purpose of Insert 1 (continued)
PALO VERDE UNITS 1,2,3 B 3.1.6-5 REVISION 465 Regulating CEA Insertion Limits B 3.1.7 BASES ACTIONS C.1 (continued) discovered that the 5 day or 14 day EFPD limit has been exceeded.
This Completion Time is based on limiting the potential xenon redistribution, the low probability of an accident, and the steps required to complete the action.D.1 With the PDIL circuit inoperable, performing SR 3.1.7.1 within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and every 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> thereafter ensures improper CEA alignments are identified before unacceptable flux distributions occur.E.1 When a Required Action cannot be completed within the required Completion Time, a controlled shutdown should be commenced.
The allowed Completion Time of 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> is reasonable, based on operating experience, for reaching MODE 3 from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.1.7.1 With the PDIL alarm circuit OPERABLE, verification of each regulating CEA group position every !2 -he'rs, is sufficient to detect CEA positions that may approach the acceptable limits, and provides the operator with time to undertake the Required Action(s) should the sequence or insertion limits be found to be e The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> FF...u.ey alse takes in er o .e indie a' * .., d by, the P011 ;larnm.av.ailab to the operator in the control room. PDIL alarms are received on both the Plant Computer (PC) and the Core Monitoring Computer (CMC)/Core Operating Limit Supervisory System (COLSS) after the CMC/COLSS Upgrade.SR 3.1.7.1 is modified by a Note indicating that entry is allowed into MODE 2 without having performed the SR. This is necessary, since the unit must be in the applicable MODES in order to perform Surveillances that demonstrate the LCO limits are met.(continued)
PALO VERDE UNITS 1,2,3 B 3.1.7-8 REVISION &I Regulating CEA Insertion Limits B 3.1.7 BASES SURVEILLANCE REQUIREMENTS SR 3.1.7.2 Verification of the accumulated time of CEA group insertion between the long term steady state insertion limits and the transient insertion limits ensures the cumulative time limits are not exce The 21 hu ... c. .....the SR 3.1.7.3 Demonstrating the PDIL alarm circuit OPERABLE verifies that the PDIL alarm circuit is func
- The 31 day Frequen. YiJAI a-Q,,, --. ." n, ill an bei,.ng p'erf"opmed
.REFERENCES
- 1. 10 CFR 50, Appendix A, GDC 10 and GDC 26.2. 10 CFR 50.46.3. Regulatory Guide 1.77, Rev. 0, May 1974.4. UFSAR, Section 15.4.PALO VERDE UNITS 1,2,3 B 3.1.7-9 REVISION Part Strength CEA Insertion Limits B 3.1.8 BASES (continued)
SURVEILLANCE REQUIREMENTS SR 3.1.8.1 Verification of each part strength CEA group position evepy-12 hou-rs is sufficient to detect CEA positions that may approach the limits, and provide the operator with time to undertake the Required Action(s), should insertion limits be found to be exceed The 32 hour3.703704e-4 days <br />0.00889 hours <br />5.291005e-5 weeks <br />1.2176e-5 months <br /> frequency al. o takco into ilnserrtion limit aarm circuit and other information abou-t LCEA group pitinz .
to the in the control REFERENCES
- 1. 10 CFR 50. Appendix A, GDC 10 and GDC 26.2. 10 CFR 50.46.3. Regulatory Guide 1.77, Rev. 0, May 1974.4. UFSAR, Section 15.4.PALO VERDE UNITS 1,2,3 B 3.1.8-5 REVISION &
STE-SDM B 3.1.9 BASES (continued)
ACTIONS A.1 With any CEA not fully inserted and less than the minimum required reactivity equivalent available for insertion, or with all CEAs inserted and the reactor subcritical by less than the reactivity equivalent of the highest worth withdrawn CEA, restoration of the minimum shutdown reactivity requirements must be accomplished by increasing the RCS boron concentration.
The required Completion Time of 15 minutes for initiating boration allows the operator sufficient time to align the valves and start the boric acid pumps and is consistent with the Completion Time of LCO 3.1.2.In the determination of the required combination of boration flow rate and boron concentration, there is no unique requirement that must be satisfied.
Since it is imperative to raise the boron concentration of the RCS as soon as possible, the boron concentration should be a highly concentrated solution, such as that normally found in the refueling water tank. The operator should borate with the best source available for the plant conditions.
In determining the boration flow rate the time in core life must be considered.
For instance, the most difficult time in core life to increase the RCS boron concentration is at the beginning of cycle, when boron concentration may approach or exceed 2000 ppm. Assuming that a value of 1%Ak/k must be recovered and a boration flow rate of 26 gpm, it is possible to increase the boron concentration of the RCS by 100 ppm in less than 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> with a 4000 ppm source.If a boron worth of 10 pcm/ppm is assumed, this combination of parameters will increase the SDM by 1% Ak/k. These boration parameters of 26 gpm and 4000 ppm represent typical values and are provided for the purpose of offering a specific example.SURVEILLANCE SR 3.1.9.1 REQUIREMENTS Verification of the position of each partially or fully withdrawn full strength, or part strength CEA is necessary to ensure that the minimum negative reactivity requirements for insertion on a tri are -A -2 hour .y is I In s e rt 1 4 Y t"- -" ....* .., h a t e a h G E ^ p e oi .i e ig within the Rcc rtnce cr-i(tenriae (conti nued)PALO VERDE UNITS 1,2,3 B 3.1.9-5 REVISION 6-9 STE-SDM B 3.1.9 BASES (continued)
SR 3.1.9.2 Prior demonstration that each CEA to be withdrawn from the core during PHYSICS TESTS is capable of full insertion, when tripped from at least a 50% withdrawn position, ensures that the CEA will insert on a trip signal. The 7 day Frequency ensures that the CEAs are OPERABLE prior to reducing SDM requirements to less than the limits of LCO 3.1.2.SR 3.1.9.3 During MODE 3, verification that the reactor is subcritical by at least the reactivity equivalent of the highest estimated CEA worth ensures that the minimum negative reactivity requirements are preserved.
The negative reactivity requirements are verified by performing a reactivity balance calculation, considering the listed reactivity effects: a. RCS boron concentration:
- b. CEA positions:
- c. RCS average temperature;
- d. Fuel burnup based on gross thermal energy generation:
The Frequency 9f 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />sP- 4A ba-sed- on the generally slew change in rcquired b9oro concentration.
and- it a]]oe:s time for- the opcrato-r-to collect the rcquired Insert 1 REFERENCES
- 1. 10 CFR 50, Appendix B, Section XI.2. 10 CFR 50.59.3. Regulatory Guide 1.68, Revision 2, August 1978.4. ANSI/ANS-19.6.1-1985, December 13, 1985.5. UFSAR, Chapter 14.6. 10 CFR 50.46.7. UFSAR, Chapter 15.PALO VERDE UNITS 1,2,3 B 3.1.9-6 REVISION -
STE-MODES 1 and 2 B 3.1.10 BASES (continued)
ACTIONS A.1 If THERMAL POWER exceeds the test power plateau in MODE 1, THERMAL POWER must be reduced to restore the additional thermal margin provided by the reduction.
The 15 minute Completion Time ensures that prompt action shall be taken to reduce THERMAL POWER to within acceptable limits.B.1 and B.2 If Required Action A.1 cannot be completed within the required Completion Time, PHYSICS TESTS must be suspended within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. Allowing 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> for suspending PHYSICS TESTS allows the operator sufficient time to change any abnormal CEA configuration back to within the limits of LCO 3.1.5, LCO 3.1.6, and LCO 3.1.7. Suspension of PHYSICS TESTS exceptions requires restoration of each of the applicable LCOs to within specification.
SURVEILLANCE REQUIREMENTS SR 3.1.10.1 Verifying that THERMAL POWER is equal to or less than that allowed by the test power plateau, as specified in the PHYSICS TEST procedure and required by the safety analysis, ensures that adequate LHR and departure from nucleate boiling ratio margins are maintained while LCOs are suspen The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, siufficient, based upon ttE iI wra ofhpo-I-r -h-- ge a , d inRpeas-d wpe-atinal cntroels in plaec during PHYSIC TEST-!ontoin LHR SR 3.1.10.2 Verification of the position of each partially or fully withdrawn full strength or part strength CEA is necessary to ensure that the minimum negative reactivity requirements for insertion on a trip are pr r A h, .... ..Inser -----to ÷ .... lm,,i nr- (continued)
REVISION 64 PALO VERDE UNITS 1,2,3 B 3.1.10-5 LHR B 3.2.1 BASES ACTIONS C.1 (continued)
The allowed Completion Time of 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> is reasonable, based on operating experience, to reach 20% RTP in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.2.1.1 REQUIREMENTS With the COLSS out of service, the operator must monitor the LHR with any OPERABLE local power density A 2 hcuh Frequency~~~~~~~ i ...... .....nff, This SR is modified by a Note that states that the SR is applicable only when the COLSS is out of service.Continuous monitoring of the LHR is provided by the COLSS, which calculates core power and core power operating limits based on the LHR and continuously displays these limits to the operator.
A COLSS margin alarm is annunciated in the event that the THERMAL POWER exceeds the core power operating limit based on LHR. This SR is also modified by a Note that states that the SR is not required to be performed until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after MODE 1 with THERMAL POWER > 20% RTP.During plant startup (increase from 15-18% RTP), the plant dynamics associated with the downcomer to economizer swapover may result in a temporary power increase above 20%RTP. The 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after reaching 20% RTP is required for plant stabilization.
SR 3.2.1.2 Verification that the COLSS margin alarm actuates at a THERMAL POWER level equal to or less than the core power operating limit based on the LHR in units of kilowatts per foot ensures the operator is alerted when conditions approach the LHR operating limit.(continued)
PALO VERDE UNITS 1,2,3 B 3.2.1-7 REVISION LHR B 3.2.1 BASES SURVEILLANCE REQUIREMENTS SR 3.2.1.2 (continued)(continued)
The 31 day FrequcncY fop performance of this SR is con-msi-stent with the histo-rical_
testing frcqUency of r-eactor-protection And- monit-oring sySte-ms.
The uvilac Frequency for testing systems .. exten.ded to 92 days by CEN 327. Mo-nitoing system r:ere-not ,ddrese Insert 1 .-1--IdR>REFERENCES
- 1. UFSAR, Section 15.2. UFSAR, Section 6.3. CE-1 Correlation for DNBR.4. 10 CFR 50, Appendix A, GDC 10.5. 10 CFR 50.46.6. Regulatory Guide 1.77, Rev. 0, May 1974.7. 10 CFR 50, Appendix A, GDC 26.PALO VERDE UNITS 1,2,3 B 3.2.1-8 REVISION 0 F B 3.2.BASES SURVEILLANCE SR 3.2.2.1 REQUIREMENTS This periodic Surveillance is for determining, using the Incore Detector System, that FxY values are Fxy values used in the COLSS and CPCs. It ensures that the Fxy values used the Fy values after each fuel loading when THERMAL POWER is> 40% RTP, but prior to its exceeding 70% RTP, ensures that the core is properly loaded.REFERENCES
- 1. UFSAR, Section 15.2. UFSAR, Section 6.3. CE-1 Correlation for DNBR.4. 10 CFR 50, Appendix A, GDC 10.5. 10 CFR 50.46.6. Regulatory Guide 1.77, Rev. 0, May 1974.7. 10 CFR 50, Appendix A, GDC 26.PALO VERDE UNITS 1,2,3 B 3.2.2-7 REVISION 0 Tq B 3.2.BASES ACTIONS B.1, B.2, B.3, B.4, and B.5 (continued)
If Tq is restored prior to identifying and correcting the cause, the plant corrective action program will continue to evaluate the cause of the out of limit condition.
After a THERMAL POWER increase following restoration of Tq, operation may proceed provided the measured Tq is determined to remain within its specified limit at the increased THERMAL POWER level.The provision to allow discontinuation of the Surveillance after verifying that Tq is within its specified limit at least once per hour for 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> or until T is verified to be within its specified limit at a THERMAL kOWER 95% RTP provides an acceptable exit from this action after the measured Tq has been returned to an acceptable value.C.1 If the measured Tq cannot be restored or determined within its specified limit, core power must be reduced. Reduction of core power to 20% RTP ensures that the core is operating within its thermal limits and places the core in a conservative condition based on the trip setpoints generated by the CPCs, which assume a minimum core power of 20% RTP.Six hours is a reasonable time to reach 20% RTP in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.2.3.1 REQUIREMENTS Continuous monitoring of the measured Tq by the incore nuclear detectors is provided by the COLSS. A COLSS alarm is annunciated in the event that the measured Tq exceeds the value used in the CPCs.With the COLSS out of service, the operator must calculate T and verify that it is within its s eci The Insert 1] exceed the limits, of this LC" Alo th12 hourF F ueney pre t( sgon (conti nued)PALO VERDE UNITS 1,2,3 B 3.2.3-8 REVISION 4)
Tq B 3.2.3 BASES SURVEILLANCE SR 3.2.3.1 (continued)
REQUIREMENTS This SR is also modified by a Note that states that the SR is not required to be performed until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after MODE 1 with THERMAL POWER > 20% RTP. During plant startup (increase from 15-18% RTP), the plant dynamics associated with the downcomer to economizer swapover may result in a temporary power increase above 20% RTP. The 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after reaching 20% RTP is required for plant stabilization.
SR 3.2.3.2 Verification that the COLSS T alarm actuates at a value less than the value used in the CPCs ensures that the opeatorislleted Tq esrstapproahe s COL s accurateyidng____tifie Insert em -....... .. ....... ... ......protcio -and- monitor-ing systeams.
The S.urweillanc Fr-equency For testing protection systems was extended to 92 days by GEN 327. Monitoring systems. W ere. n addressed in UEl 327;thrfoe this Frequency rem-ains -at- 31 days.SR 3.2.3.3 Independent confirmation of the validity of the COLSS calculated I ensures that the COLSS accurately identifies T he31 day Frequency for performan-e-of thi-s SR is Frequency for testing protection systems was extended to 92 days by CEN 327. Monitoring system were no ddressed in GEN 3227; therefore-, thsFeunyremain-s at 321 days.(conti nued)PALO VERDE UNITS 1,2,3 B 3.2.3-9 REVISION 4 DNBR B 3.2.4 BASES ACTIONS C.1 (continued)
If the DNBR cannot be restored or determined within the allowed times of Conditions A and B, core power must be reduced. Reduction of core power to 20% RTP ensures that the core is operating within its thermal limits and places the core in a conservative condition based on trip setpoints generated by the CPCs, which assume a minimum core power of 20% RTP.The allowed Completion Time of 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> is reasonable, based on operating experience, to reach 20% RTP from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.2.4.1 REQUIREMENTS With the COLSS out of service, the operator must monitor the DNBR as indicated on all of the OPERABLE DNBR channels of the CPCs to verify that the DNBR is within the specified limits shown in t A 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.. Fre.u...Y 4 adequate toeult inan- ap iproch to ted DinB limit.This SR is modified by a Note that states that the SR is only applicable when the COLSS is out of service.Continuous monitoring of the DNBR is provided by the COLSS, which calculates core power and core power operating limits based on the DNBR and continuously displays these limits to the operator.
A COLSS margin alarm is annunciated in the event that the THERMAL POWER exceeds the core power operating limit based on the DNBR. This SR is also modified by a Note that states that the SR is not required to be performed until 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after MODE 1 with THERMAL POWER >20% RTP. During plant startup (increase from 15-18% RTP), the plant dynamics associated with the downcomer to economizer swapover may result in a temporary power increase above 20% RTP. The 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after reaching 20% RTP is required for plant stabilization.(continued)
PALO VERDE UNITS 1,2,3 B 3.2.4-8 REVISION 63 DNBR B 3.2.4 BASES SURVEILLANCE REQUIREMENTS (continued)
!insert 1 ---SR 3.2.4.2 Verification that the COLSS margin alarm actuates at a power level equal to or less than the core power operating limit, as calculated by the COLSS, based on the DNBR, ensures that the operator is alerted when operating conditions approach the DNBR 0 eratn
- inl The 31- day Frequency for ane-e9+ t46 L 4l -9I~ PzARs4 A 4~ 444~I~Ll 444P LI 44 1;4-OLr-4 A systems a ep ucncw, rL.. ;; _-._4- Q A" 49 of reactor protection RAnd mntrn............
F.r ..eqny for testing protec-tion ed to 92 days by CEN 32E7. Monitoring ddress-cd' in llCEN 327; the refo -Irer,-thi s.i stems was extena Sys tems were not a 1-requency remains at 31 days.REFERENCES
- 1. UFSAR, Chapter 15.2. UFSAR, Chapter 6.3. CE-1 Correlation for DNBR.4. 10 CFR 50, Appendix A, GDC 10.5. 10 CFR 50.46.6. Regulatory Guide 1.77, Rev. 0, May 1974.7. 10 CFR 50, Appendix A, GDC 26.PALO VERDE UNITS 1,2,3 B 3.2.4-9 REVISION 69 ASI B 3.2.5 BASES ACTIONS A.1 The ASI limits specified in the COLR ensure that the LOCA and loss of flow accident criteria assumed in the accident analyses remain valid. If the ASI exceeds its limit, a Completion Time of 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> is allowed to restore the ASI to within its specified limit. This duration gives the operator sufficient time to reposition the regulating or part strength CEAs to reduce the axial power imbalance.
The magnitude of any potential xenon oscillation is significantly reduced if the condition is not allowed to persist for more than 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.B.1 If the ASI is not restored to within its specified limits within the required Completion Time, the reactor continues to operate with an axial power distribution mismatch.Continued operation in this configuration induces an axial xenon oscillation, and results in increased LHGRs when the xenon redistributes.
Reducing thermal power to : 20% RTP reduces the maximum LHR to a value that does not exceed the fuel design limits if a design basis event occurs. The allowed Completion Time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is reasonable, based on operating experience, to reduce power in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.2.5.1 REQUIREMENTS The ASI can be monitored by both the incore (COLSS) and excore (CPC) neutron detector systems. The COLSS provides the operator with an alarm if an ASI limit is approached.
Verification of the ASI ever-y 2 heurs ensures that the operator is aware of changes in the ASI as they devel A Insertbuio or1A rv mechanimS malfunctionPh RAuscR[ Inseus1 ct A9, Which cAn be dicover (c before the (continued)
PALO VERDE UNITS 1,2,3 B 3.2.5-6 REVISION 92 RPS Instrumentation
-Operating B 3.3.1 BASES ACTIONS (continued)
E.1 Condition E is entered when the Required Action and associated Completion Time of Condition A, B, C, or D are not met.If the Required Actions associated with these Conditions cannot be completed within the required Completion Time, the reactor must be brought to a MODE where the Required Actions do not apply. The allowed Completion Time of 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> is reasonable, based on operating experience, for reaching the required MODE from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS The SRs for any particular RPS Function are found in the SR column of Table 3.3.1-1 for that Function.
Most Functions are subject to CHANNEL CHECK, CHANNEL FUNCTIONAL TEST, CHANNEL CALIBRATION, and response time testing.SR 3.3.1.1 Performance of the CHANNEL CHECK once every 12 hourz ensures that gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.
It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.(continued)
PALO VERDE UNITS 1,2,3 B 3.3.1-40 REVISION -59 RPS Instrumentation
-Operating B 3.3.1 BASES SURVEILLANCE SR 3.3.1.1 (continued)
REQUIREMENTS Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability.
If a channel is outside the criteria, it may be an indication that the transmitter or the signal processing equipment has drifted outside its limits. For clarification, a CHANNEL CHECK is a qualitative assessment of an instrument's behavior.Where possible, a numerical comparison between like instrument channels should be included but is not required for an acceptable CHANNEL CHECK performance.
The FrequenGy, about o-nr-ce. every shift, is ba-,-ased-on operating cxpcricncc th-at deosrtsthe rarity of-chWannc filu Sincee the probability of two rando failures in rdna nt- r-hhannels in any 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> p Aeid i R exrmly. 1 o, the CHANNI-EL CHECK minimixes the of loss of Proetv fucindet lr frdnAnt chn......
The R CHANNE CHECK supplements le-s formal, but mo f eq t, checks oef cha-R~hnnel OPERABILI TIY dur-ing normal oper-ational use o-f the dipasasoitdwith theLC[insert 1k In the case of RPS trips with multiple inputs, such as the DNBR and LPD inputs to the CPCs, a CHANNEL CHECK must be performed on all inputs.$SP 3.3.1.2 The RCS flew raeindicated by each CPC is ':ernified, as required by a Note, to be less than or equal to the actu-al RCS to-tal flow: rate, deemndby either using the reactor coolant pump differ-ential pr-essure instrumentationR or by calculatios, Ir.!y 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> when THERMAL--0% DTD The 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reaching 70% RTP is iner iization, data taking, and flow verification.
This check (and if necessary, the adjustment of the CPC addressable constant flow coefficients) ensures that the DNBR setpoint is conservatively adjusted with respect to actual flow indications, as determined by the Core Operating Limits Supervisory System (COLSS).The flow measurement uncertainty may be included in the BERR1 term in the CPC and is equal to or greater than 4%.(continued)
PALO VERDE UNITS 1,2,3 B 3.3.1-41 REVISION 63 RPS Instrumentation
-Operating B 3.3.1 BASES SURVEILLANCE SR 3.3.1.3 REQUIREMENTS The CPC System Event Log is checked every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> to monitor the CPC channel performance, including redundant features not required for the CPC to perform its safety related trip function.
The system event log provides a historical record of the last thirty detected CPC channel error conditions.
A detected error condition may not render a channel inoperable, unless it is accompanied by a CPC Fail indication.
SR 3.3.1.4 A daily calibration (heat balance) is performed when THERMAL POWER is t 20%. The Linear Power Level signal and the CPC addressable constant multipliers are adjusted to make the CPC AT power and nuclear power calculations agree with the calorimetric calculation if the absolute difference is b 2% when THERMAL POWER is r 80% RTP, and -0.5% to 10% when THERMAL POWER is between 20% and 80%. The value of 2% when THERMAL POWER is 80% RTP, and -0.5% to 10% when THERMAL POWER is between 20% and 80% is adequate because this value is assumed in the safety analysis.These checks (and, if necessary, the adjustment of the Linear Power Level signal and the CPC addressable constant coefficients) are adequate to ensure that the accuracy of these CPC calculations is maintained within the analyzed error margins. The power level must be > 20% RTP to obtain accurate data. At lower power levels, the accuracy of calorimetric data is questionable.(continued)
PALO VERDE UNITS 1,2,3 B 3.3.1-42 REVISION 63 RPS Instrumentation
-Operating B 3.3.1 BASES SURVEILLANCE SR 3.3.1.4 REQUIREMENTS The tolerance between 20% and 80% RTP is +10% to reduce the number of adjustments required as the power level increases.
The -0.5% tolerance between 20% and 80% RTP is based on the reduced accuracy of the calorimetric data inputs at low power levels. Performing a calorimetric calibration with a -0.5%tolerance at low power levels ensures the difference will remain within -2.0% when power is increased above 80% RTP.If a calorimetric calculation is performed above 80% RTP, it will use accurate inputs to the calorimetric calculation available at higher power levels. When the power level is decreased below 80% RTP an additional performance of the SR to the -0.5% to 10% tolerance is not required if the SR has been performed above 80% RTP. During any power ascension from below 80% to above 80% RTP, the calibration requirements of ITS SR 3.3.1.4 must be met (except during PHYSICS TESTS, as allowed by the Note in SR 3.3.1.4).
This is accomplished by performing SR 3.3.1.4 between 75% and 80% RTP during power ascension with an acceptance criteria of -0.5% to <2% to bound the requirements for both below and above 80% RTP.The Fregucncy of 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> is based on plant operating cxerencand takes; into account ind-icA-t-ion -and- alarms ocatd in tc~ contr] room t I detect dviiatiens in SThe Frequency is modified by a Note indicating this ielance need only be performed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reaching 20% RTP.The 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reaching 20% RTP is required for plant stabilization, data taking, and flow verification.
The secondary calorimetric is inaccurate at lower power levels.A second Note in the SR indicates the SR may be suspended during PHYSICS TESTS. The conditional suspension of the daily calibrations under strict administrative control is necessary to allow special testing to occur.(continued)
PALO VERDE UNITS 1,2,3 B 3.3.1-43 REVISION RPS Instrumentation
-Operating B 3.3.1 BASES SURVEILLANCE REQUIREMENTS SR 3.3.1.5 The RCS flow rate indicated by each CPC is verified to be less than or equal to the RCS total flow rate every-&4-day&.
The Note indicates the Surveillance is performed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after THERMAL POWER is 70% RTP. This check (and, if necessary, the adjustment of the CPC addressable flow constant coefficients) ensures that the DNBR setpoint is conservatively adjusted with respect to actual flow indications as determined either using the reactor coolant pump differential pressure instrumentation and the ultrasonic flow meter adjusted pump curves or by a calorimetric calclOatiLnn>
n .... t ....... i .... has Sh....insertn~ 1n3 -l~n -u -n --v -- *4 4eq .i ns dVif minimal and ehanges in actual flew r-ate -arc minimal evern SR 3.3.1.6 The three vertically mounted excore nuclear instrumentation detectors in each channel are used to determine APD for use in the DNBR and LPD calculations.
Because the detectors are mounted outside the reactor vessel, a portion of the signal from each detector is from core sections not adjacent to the detector.
This is termed shape annealing and is compensated for after every refueling by performing SR 3.3.1.11, which adjusts the gains of the three detector amplifiers for shape annealing.
SR 3.3.1.6 ensures that the preassigned gains are still proper. When power is < 15% the CPCs do not use the excore generated signals for axial flux shape information.
The Note allowing 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reaching 15%RTP is required for plant stabilization Th--1--I Insert 1" P-1 + A +I 12. -IiRzL IIM~. AX j~~i. P. RAMP111III SR 3.3.1.7 A CHANNEL FUNCTIONAL TEST on each channel 92 days to ensure the entire channel will is performed every perform its intended function when needed.Notes. Note 1 is a requirement addressable constant values are the CPC CHANNEL FUNCTIONAL TEST the CHANNEL FUNCTIONAL TEST for-High channels to be performed power drops below 1E-4% NRTP.The SR is modified by two to verify the correct CPC installed in the CPCs when is performed.
Note 2 allows the Logarithmic Power Level 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after logarithmic (conti nued)PALO VERDE UNITS 1,2,3 B 3.3.1-44 REVISION RPS Instrumentation
-Operating B 3.3.1 BASES SURVEILLANCE Trip Path Tests (continued)
REQUIREMENTS The Frcgucncy of 92 days is based- on the reliability-analysis presented in' to Ic repr-t CE 2,"RPS/EFA Ilnsert---'
1The CPC and CEAC channels and excore nuclear instrumentation channels are tested separately.
The excore channels use preassigned test signals to verify proper channel alignment.
The excore logarithmic channel test signal is inserted into the preamplifier input, so as to test the first active element downstream of the detector.The power range excore test signal is inserted at the drawer input, since there is no preamplifier.
The quarterly CPC CHANNEL FUNCTIONAL TEST is performed using software.
This software includes preassigned addressable constant values that may differ from the current values.Provisions are made to store the addressable constant values on a computer disk prior to testing and to reload them after testing. A Note is added to the Surveillance Requirements to verify that the CPC CHANNEL FUNCTIONAL TEST includes the correct values of addressable constants.
SR 3.3.1.8 A Note indicates that neutron detectors are excluded from CHANNEL CALIBR A CHUMPE CALIBRATION of the poe:er- range-Ilnser 1 I ~ e w-tl n ihntlra~ Rf ) The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.
CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive tests.CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the interval between surveillance interval extension analysis.
The requirements for this review are outlined in Reference 9.Operating experience has shown this Frequency to be satisfactory.
The detectors are excluded from CHANNEL (continued)
PALO VERDE UNITS 1,2,3 B 3.3. 1-46 REVISION 63 RPS Instrumentation
-Operating B 3.3.1 BASES SURVEILLANCE SR 3.3.1.8 (continued)
REQUIREMENTS CALIBRATION because they are passive devices with minimal drift and because of the difficulty of simulating a meaningful signal. Slow changes in detector sensitivity are compensated for by performing the da-1y calorimetric calibration (SR 3.3.1.4) and the monthly linear subchannel gain check (SR 3.3.1.6).
In addition, the associated control room indications are monitored by the operators.
SR 3.3.1.9 SR 3.3.1.9 is the performance of a CHANNEL CALIBRATION ever~y48-menths.
CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor. The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.
CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive tests. CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis.
The requirements for this review are outlined in Reference 9.The Frgu-nRy is based upon the assumption of an 18 month calibration intcrp-l for- the determination of the magnitude of equipment drift. in the setpoint analysis as w:ell as opeatngexper-ience -and- con-sistency with the typic-al 18 month fue! 1 P nlnsert 1--- ... .The Surveillance is modified by a Note to indicate that the 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. Slow changes in detector sensitivity are compensated for by performing the daily calorimetric calibration (SR 3.3.1.4) and the monthly linear subchannel gain check (SR 3.3.1.6).(continued)
PALO VERDE UNITS 1,2,3 B 3.3.1-47 REVISION 4 RPS Instrumentation
-Operating B 3.3.1 BASES SURVEILLANCE SR 3.3.1.10 A REQUIREMENTS (continued)
Ev.ery 18 months, a CHANNEL FUNCTIONAL TEST is performed on the CPCs. The CHANNEL FUNCTIONAL TEST shall include the injection of a signal as close to the sensors as practicable to verify OPERABILITY including alarm and trip Functions.
The bh-a-i-- for the 18R- month Frequency is th-at the CC-perform a continuou-s self monitorn fnton that cl.m4i.-atcs the n..ed for- fr-equen ANNEl FIUNTIONAL TSTS This- CHANNE-L-FUNCTIONAL TEST e"seIally
,- -.1 --e, thep monitoring function and checks for a small set of fai*ure moqdes that are u-ndetecap ytesefmntrn function.
Op ing experience has sho':n that undetected CP o CACfalue do not occr, i n given 18 month SR 3.3.1.11 The three excore detectors used by each CPC channel for axial flux distribution information are far enough from the core to be exposed to flux from all heights in the core, although it is desired that they only read their particular level. The CPCs adjust for this flux overlap by using the predetermined shape annealing matrix elements in the CPC software.After refueling, it is necessary to re-establish or verify the shape annealing matrix elements for the excore detectors based on more accurate incore detector readings.This is necessary because refueling could possibly produce a significant change in the shape annealing matrix coefficients.
Incore detectors are inaccurate at low power levels.THERMAL POWER should be significant but < 70% to perform an accurate axial shape calculation used to derive the shape annealing matrix elements.By restricting power to _< 70% until shape annealing matrix elements are verified, excessive local power peaks within the fuel are avoided. Operating experience has shown this Frequency to be acceptable.(continued)
PALO VERDE UNITS 1,2,3 B 3.3.1-48 REVISION -59 RPS Instrumentation
-Operating B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.12 SR 3.3.1.12 is a CHANNEL FUNCTIONAL TEST similar to SR 3.3.1.7, except SR 3.3.1.12 is applicable only to operating bypass functions and is performed once within 92 days prior to each startup. Proper operation of operating bypass permissives is critical during plant startup because the operating bypasses must be in place to allow startup operation and must be automatically removed at the appropriate points during power ascent to enable certain reactor trips. Consequently, the appropriate time to verify operating bypass removal function OPERABILITY is just prior to startup. The allowance to conduct this Surveillance within 92 days of startup is based on the reliability analysis presented in topical report CEN-327,"RPS/ESFAS Extended Test Interval Evaluation" (Ref. 9).Once the operating bypasses are removed, the bypasses must not fail in such a way that the associated trip Function gets inadvertently bypassed.
This feature is verified by the trip Function CHANNEL FUNCTIONAL TEST, SR 3.3.1.7.Therefore, further testing of the operating bypass function after startup is unnecessary.
SR 3.3.1.13 This SR ensures that the RPS RESPONSE TIMES are verified to be less than or equal to the maximum values assumed in the safety analysis.
Individual component response times are not modeled in the analyses.
The analyses model the overall or total elapsed time, from the point at which the parameter exceeds the trip setpoint value at the sensor to the point at which the RT RDsp.nse times areTAPP_-DIQ'r TFS:T Th4-s-[tInsert in th. intcrvA t.l bctwen of c-hannels in tIhe., "functin.4, The'-
o','f 18 mont,-Ihs is based upon operating e-eine, which has shown tha random failue oinstrumentation components c-au-sing serious response time degradation, but not ch-annel failure,-are infrequent occurence.
Repnetm testing may be pefome at power- on a single c~hannel o-r during plant outages when the equipment is not required-to- be operable.Testing may be perfermed-in one measurement or in overlappings~ns with verific-nation that all cmoet (continued)
PALO VERDE UNITS 1,2,3 B 3.3. 1-49 REVISION 63 RPS Instrumentation
-Shutdown B 3.3.2 BASES ACTIONS E.1 (continued)
If Required Actions associated with these Conditions cannot be completed within the required Completion Time, all RTCBs must be opened, placing the plant in a condition where the RPS trip channels are not required to be OPERABLE.
A Completion Time of 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> is a reasonable time to perform the Required Action, which maintains the risk at an acceptable level while having one or two channels inoperable.
SURVEILLANCE The SR's for any particular RPS function are found in the SR REQUIREMENTS column of Table 3.3.2-1 for that function.
The SRs are an extension of those listed in LCO 3.3.1, listed here because of their Applicability in these MODES.SR 3.3.2.1 SR 3.3.2.1 is the performance of a CHANNEL CHECK of each RPS channel. This SR is identical to SR 3.3.1.1. Only the Applicability differs.Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ensures that gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on another channel. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying 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 sensor or the signal processing equipment has drifted outside its limits. For clarification, a CHANNEL CHECK is a qualitative assessment of an instrument's behavior.
Where possible, a numerical comparison between like instrument channels should (continued)
PALO VERDE UNITS 1,2,3 B 3.3.2-13 REVISION 41 RPS Instrumentation
-Shutdown B 3.3.2 BASES SURVEILLANCE SR 3.3.2.1 (continued)
REQUIREMENTS be included but is not required for an acceptable CHANNEL CHECK performance.
The Lrguency.
about once eST ery shift, ic l basedx pn operating neutron hat dflMuxtats the rparity of cehannel failure.Sincel t le probabi ity of to randeo failun in rnedu ndant channels in any 12 houR period is extremely lol, the CcANNEL CHC inimizes the chance of loss of proetectivc function due tofalue f rdnat hnes TheCHNECEK supplment les; forzmal, but more frequent, checks of ch-anneel OPERABIITYý duing nori mal operational use of the displays A CHANNEL FUNCTIONAL TEST on each channel, except power range neutron flux, is performed evepy-92-.days to ensure the entire channel will perform its intended function when needed. This SR is identical to SR 3.311.7. Only the Applicability differs.The RPS CHANNEL FUNCTIONAL TEST consists of three overlapping tests as described in the UFSAR, Section 7.2 (Ref. 3). These tests verify that the RPS is capable of performing its intended function, from bistable input through the RTCBs.They include: Bistable Tests A test signal is superimposed on the input in one channel at a time to verify that the bistable trips within the specified tolerance around the setpoint.
This is done with the affected RPS channel trip channel bypassed.
Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis.
The requirements for this review are outlined in Reference 6.(continued)
PALO VERDE UNITS 1,2,3 B 3.3.2-14 REVISION &I RPS Instrumentation
-Shutdown B 3.3.2 BASES SURVEILLANCE Matrix Logic Tests REQUIREMENTS (continued)
Matrix Logic Tests are addressed in LCO 3.3.4. This test is performed one matrix at a time. It verifies that a coincidence in the two input channels for each Function removes power from the matrix relays. During testing, power is applied to the matrix relay test coils and prevents the matrix relay contacts from assuming their de-energized state.This test will detect any short circuits around the bistable contacts in the coincidence logic, such as may be caused by faulty bistable relay or trip channel bypass contacts.Trip Path Test Trip path (Initiation Logic) tests are addressed in LCO 3.3.4. These tests are similar to the Matrix Logic tests except that test power is withheld from one matrix relay at a time, allowing the initiation circuit to de-energize, opening the affected set of RTCBs. The RTCBs must then be closed prior to testing the other three initiation circuits, or a reactor trip may result.The F...uen.y of 92 days is based on the reliability analysis precscted in topical rcport CEN-327, "RP99FAS Extended Test--!mteryal Evaluation" (Ref. 6). The exvori use preassigned test ignals to verif pro.per. .hanel aign...ent.
The exore lo-itm-chne test sign-al ;"is inserted intop the pr-eamplifier input, so as toe t es-t t he fir-St -ac-tive element de'n-n'tre-am
&F det Inet1 -; .3. 2. 3 SR 3.3.2.3 is a CHANNEL FUNCTIONAL TEST similar to SR 3.3.2.2, except SR 3.3.2.3 is applicable only to operating bypass functions and is performed once within 92 days prior to each startup. This SR is identical to SR 3.3.1.12.
Only the Applicability differs.Proper operation of operating bypass permissives is critical during plant startup because the operating bypasses must be in place to allow startup operation and must be automatically removed at the appropriate points during power ascent to enable certain reactor trips. Consequently, the appropriate time to verify operating bypass removal function (continued)
PALO VERDE UNITS 1,2,3 B 3.3.2-15 REVISION 363 RPS Instrumentation
-Shutdown B 3.3.2 BASES SURVEILLANCE SR 3.3.2.3 (continued)
REQUIREMENTS OPERABILITY is just prior to startup. The allowance to conduct this Surveillance within 92 days of startup is based on the reliability analysis presented in topical report CEN-327, "RPS/ESFAS Extended Test Interval Evaluation" (Ref. 6). Once the operating bypasses are removed, the operating bypasses must not fail in such a way that the associated trip Function gets inadvertently bypassed.
This feature is verified by the trip Function CHANNEL FUNCTIONAL TEST, SR 3.3.2.2. Therefore, further testing of the operating bypass function after startup is unnecessary.
SR 3.3.2.4 SR 2 232.4 is the performanre of a CHllANNEL GALITQDATION everyThis SR is identical to SR 3.3.1.9. Only the Applicability differs.CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor (the sensor is excluded for the Logarithmic Power Level Function).
The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.
CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive tests. CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis.
The requirements for this review are outlined in Reference 6.The Frequency is based upon the assumption of an 18 month rc-aibratin inter,:al fop the detcrmination of the magnitude of cuipmnt drift. in the sctpoint analy-sis and- includcs epcrating experience-anR~d conRsi-stcncy w~ith the typical iInsert 1 Surveillance is modified by a Note to indicate that the L -J n neutron detectors are excluded from CHANNEL CALIBRATION because they are passive devices with minimal drift and (continued)
PALO VERDE UNITS 1,2,3 B 3.3.2-16 REVISION 35 RPS Instrumentation
-Shutdown B 3.3.2 BASES SURVEILLANCE SR 3.3.2.4 (continued)
REQUIREMENTS because of the difficulty of simulating a meaningful signal.Slow changes in detector sensitivity are compensated for by performing the daily calorimetric calibration (SR 3.3.1.4).SR 3.3.2.5 This SR ensures that the RPS RESPONSE TIMES are verified to be less than or equal to the maximum values assumed in the safety analysis.
Individual component response times are not modeled in the analyses.
The analyses model the overall or total elapsed time, from the point at which the parameter exceeds the trip setpoint value at the sensor to the point at which the RTCBs o.- Response times are condu-ctcd on an 1(3 _ WI T-CgT- 9A-STS Thi -;.....14-t A, the interval insert 1 r-r-----igtigen scc ive tPRU t a, ]:giv-en eha-nn 1f monhs w:here n is the number of channcls in the Function.
The 18sponth timeqmacy is based upon operaties efperien hia h hvarslappn Wth random failurhes of instrumentation i c oiong ent causing sensous response time degradation, but net hoannel failure, are iAllcquant ioccrrenes.
response time* teytin may be performed at power on a sigle chans velor t during plant outages when the equipment is oti reqired to be opePable.Testing may be perfornmed in oue asurement epo in Tverlapping segments, wfith 7eri ti on t hhat all components are tested.Response time may be verified by any series of sequential, overlapping or total channel measurements, including allocated sensor response time, such that the response time is verified.
Allocations for sensor response times may be obtained from records of test results, vendor test data, or vendor engineering specifications.
Topical Report CE NPSD-1167-A, "Elimination of Pressure Sensor Response Time Testing Requirements," (Ref. 7) provides the basis and methodology for using allocated sensor response times in the overall verification of the channel response time for specific sensors identified in the Topical Report. Response time verification for other sensor types must be demonstrated by test. The allocation of sensor response times must be verified prior to placing a new component in operation and reverified after maintenance that may adversely affect the sensor response time.(conti nued)PALO VERDE UNITS 1,2,3 B 3.3.2-17 REVISION 3 CEACs B 3.3.3 BASES SURVEILLANCE SR 3.3.3.1 REQUIREMENTS Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ensures that gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on another channel. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure: thus, it is key to verifying 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 sensor or the signal processing equipment has drifted outside its limits. For clarification, a CHANNEL CHECK is a qualitative assessment of an instrument's behavior.
Where possible, a numerical comparison between like instrument channels should be included but is not required for an acceptable CHANNEL CHECK performance.
The Frequenc-y, about: once cvcr-y shift, is based- on oper-ating expeienc t h-at demntae thM e r-arity of rchanncl failu-re.Since the probability of two r.andom failu res in redundant channels -in any 12 hourp CHANNEL HE"CK minimizes the chance of less of pr-otec-tive function The CWANNEL CHECK supplements less but more frequent, checks of cB during normal oper-ational 6ue ofthedsly associiated with the LCO SR 3.3.3.2 Deleted (continued)
PALO VERDE UNITS 1,2,3 B 3.3.3-10 REVISION 63 CEACs B 3.3.3 BASES SURVEILLANCE SR 3.3.3.3 REQUIREMENTS (continued)
CHANNEL FUNCTIONAL TEST on each CEAC channel is performed every d-2--aý-y to ensure the entire channel will perform its Freuecyof 92 days is bhased- on the rcali-ability anal"s#, presntedin topical report GEN 327. "RPS.'ESFAS ExtendednTer.,.,v,,,l E,,,aluation" 5)SR 3.3.3.4 SR 3.3.3.4 is the performance of a CHANNEL CALIBRATION every 1 4mn-thq.CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor. The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.
CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive surveillance.
CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis.
'The requirements for this review are outlined in Reference 5.The is based upon the assumption of an I1 month c-.alir-ation-inte,] in the dtermination of the magnitude.h of equipment drift. in the setpoint analysis and inczludes opeatngexperience -and- conAIsistenczy with the typica Every 18 months, a CHANNEL FUNCTIONAL TEST is performed on the CEACs. The CHANNEL FUNCTIONAL TEST shall include the injection of a signal as close to the sensors as practicable to verify OPERABILITY, including alarm and trip Functions.
continued)
PALO VERDE UNITS 1,2,3 B 3.3.3-11 REVISION 63 CEACs B 3.3.3 BASES SURVEILLANCE REQUIREMENTS SR 3.3.3.5 (continued)
Thc b--asis, for the 18 month Frequenc 4.. that thc CEACZ perform acntinuou; relf- monitoring function that eliinaes hc eedfor fr-equent CHANNEL FUNCTIONAL TESTS.This CHANEL FUNCTIONAL TEST essentially validates the self functio a. crheks for a s.mal. se of failure mod-es that arPe undetectable b)y the sel~f monRitoring fu~nction.
n xper has shown that. undteted CPC or CEAC REFERENCES
- 1. 10 CFR 50.2. 10 CFR 100.3. UFSAR, Section 7.2.4. NRC Safety Evaluation Report, July 15, 1994 5. CEN-327, June 2, 1986, including Supplement 1, March 3, 1989, and Calculation 13-JC-SB-200.
PALO VERDE UNITS 1,2,3 B 3.3.3-12 REVISION 63 RPS Logic and Trip Initiation B 3.3.4 BASES ACTIONS E.1 and E.2 (continued)
If the RTCB associated with the inoperable channel, or the redundant RTCB in the affected Trip Leg cannot be opened, the reactor must be shut down within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and all the RTCBs opened. A Completion Time of 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> is reasonable, based on operating experience, for reaching the required plant conditions from full power conditions in an orderly manner and without challenging plant systems and for opening RTCBs. All RTCBs should then be opened, placing the plant in a MODE where the LCO does not apply and ensuring no CEA withdrawal occurs.SURVEILLANCE SR 3.3.4.1 REQUIREMENTS A CHANNEL FUNCTIONAL TEST on each RPS Logic channel and Manual Trip channel is performed every-92-4ay6 to ensure the entire channel will perform its intended function when needed.The RPS CHANNEL FUNCTIONAL TEST consists of three overlapping tests as described in Reference
- 3. These tests verify that the RPS is capable of performing its intended function, from bistable input through the RTCBs. The first test, the bistable test, is addressed by SR 3.3.1.7 in LCO 3.3.1.This SR addresses the two tests associated with the RPS Logic: Matrix Logic and Trip Path.Matrix Logic Tests These tests are performed one matrix at a time. They verify that a coincidence in the two input channels for each Function removes power from the matrix relays. During testing, power is applied to the matrix relay test coils and prevents the matrix relay contacts from assuming their de-energized state. The Matrix Logic tests will detect any short circuits around the bistable contacts in the coincidence logic such as may be caused by faulty bistable relay or trip channel bypass contacts.(continued)
PALO VERDE UNITS 1,2,3 B 3.3.4-13 REVISION .9 RPS Logic and Trip Initiation B 3.3.4 BASES SURVEILLANCE Trip Path Tests REQUIREMENTS (continued)
These tests are similar to the Matrix Logic tests, except that test power is withheld from one matrix relay at a time, allowing the initiation circuit to de-energize, opening the affected RTCB. The RTCB must then be closed prior to testing the other three initiation circuits, or a reactor trip may result.During the Matrix Logic and Initiation Logic tests, power is applied to the Matrix relay tests coils. The test coils prevent an actuation during testing by preventing the Matrix relay contacts in the Initiation Logic from changing state during the test. This does not affect the Operability of the Initiation Logic since only one of the six logic combinations that are available to trip the Initiation Logic are affected during the test because only one Matrix Logic combination can be tested at any time. The remaining five matrix combinations available ensure that a trip in any three channels will de-energize all four Initiation paths.The Frequency of 92 days is based- on the reliability-analysis prcsentcd in topical rcpor-t GEN 327, "RPSA'SFAS Extenddedd Test Inltera _1 -40'a-atien"R (R.e.!insert 13]-SR 3-.3.4.2 Each RTCB is actuated by an undervoltage coil and a shunt trip coil. The system is designed so that either de-energizing the undervoltage coil or energizing the shunt trip coil will cause the circuit breaker to open. When an RTCB is opened, either during an automatic reactor trip or by using the manual push buttons in the control room, the undervoltage coil is de-energized and the shunt trip coil is energized.
This makes it impossible to determine if one of the coils or associated circuitry is defective.
Therefore, once every 18 months, and following maintenance or adjustment of the reactor trip breakers, a CHANNEL FUNCTIONAL TEST is performed that individually tests all four undervoltage coils and all four shunt trip coils.During undervoltage coil testing, the shunt trip coils must remain de-energized, preventing their operation.
Conversely, during shunt trip coil testing, the undervoltage coils must remain energized, preventing their operation.(continued)
PALO VERDE UNITS 1,2,3 B 3.3.4-14 REVISION 4 RPS Logic and Trip Initiation B 3.3.4 BASES SURVEILLANCE REQUIREMENTS SR 3.3.4.2 (continued)
This Surveillance ensures that every undervoltage coil and every shunt trip coil is capable of performing its intended function and that no single active failure of any RTCB component will prevent a r " e 1 " on operating experience that 1ha shown these ope s ...ally pass the Surpo.ilLancc when pcr'formcd at the Frcgucency of once evcry 18 moneths.SR 3.3.4.3 toverifv A CHANNEL FUNCTIONAL TEST on each RTCB is performed evepyay .... Thi-s verife proper operation of each RTCB. The RTCB must then be closed prior to testing the other three initiation circuits, or a Reactor T "T.he.-[Insert 1 F ....e. I Reep .... -32,,_ "Rpý 4PU^S Exten'ded T~÷ valuation" (Ref.- &).REFERENCES
- 1. 10 CFR 50, Appendix A.2. 10 CFR 100.3. UFSAR, Section 7.2.4. NRC Safety Evaluation Report, July 15, 1994.5. CEN-327, June 2, 1986, including Supplement 1, March 3, 1989, and Calculation 13-JC-SB-200.
PALO VERDE UNITS 1,2,3 B 3.3.4-15 REVISION 4 ESFAS Instrumentation B 3.3.5 BASES ACTIONS (continued)
E.1 and E.2 If the Required Actions and associated Completion Times of Condition A, B, C, or D 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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and to MODE 4 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. 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 3.3.5.1 REQUIREMENTS Performance of the CHANNEL CHECK oce every 12 hourz ensures that a gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.
It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
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. If the channels are within the criteria, it is an indication that the channels are OPERABLE.
For clarification, a CHANNEL CHECK is a qualitative assessment of an instrument's behavior.
Where possible, a numerical comparison between like instrument channels should be included but is not required for an acceptable CHANNEL CHECK performance.(continued)
PALO VERDE UNITS 1,2,3 B 3.3.5-26 REVISION &I ESFAS Instrumentation B 3.3.5 BASES SURVEILLANCE SR 3.3.5.1 (continued)
REQUIREMENTS The Frcgucncy, about once evcr-y shift, is based on opcrating-exprincetht dmota-ties channel failure is rnare. Si n-e the bility of te ailures in redundant channels in any 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> periodif;:
heCANLCEC iiie the chance of los-s of pr-etective function due to f-ailure of redundrnt chanel16.
The- CHANE CECK supplements less frmal bt mor frequent, chec-ks of channel OPER-ABIL1ITY duignrmal oper-ation-al u-se of displays as-soc-iated with IInsert 1 R 3...A CHANNEL FUNCTIONAL TEST is performed every- 2-day-s to ensure the entire channel will perform its intended function when needed.The CHANNEL FUNCTIONAL TEST is part of an overlapping test sequence similar to that employed in the RPS. This sequence, consisting of SR 3.3.5.2, SR 3.3.6.1, and SR 3.3.6.2, tests the entire ESFAS from the bistable input through the actuation of the individual subgroup relays.These overlapping tests are described in Reference 1.SR 3.3.5.2 and SR 2.3.61 arc normally performed together and- M "SR 3.3.6.2 verifies that the , of_ actuating their Insert ive ESF components when de-energized.
These tests verify that the ESFAS is capable of performing its intended function, from bistable input through the actuated components.
SRs 3.3.6.1 and 3.3.6.2 are addressed in LCO 3.3.6. SR 3.3.5.2 includes bistable tests.A test signal is superimposed on the input in one channel at a time to verify that the bistable trips within the specified tolerance around the setpoint.
This is done with the affected RPS trip channel bypassed.
Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.(continued)
PALO VERDE UNITS 1,2,3 B 3.3.5-27 REVISION -363 ESFAS Instrumentation B 3.3.5 BASES SURVEILLANCE SR 3.3.5.2 (continued)
REQUIREMENTS The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis.
The requirements for this review are outlined in Reference 9.SR 3.3.5.3 CHANNEL CALIBRATION is a complete check of the instrument channel including the detector and the bypass removal functions.
The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.
CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive surveillances.
CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis.
The requirements for this review are outlined in Reference 9.The 18 month fregucncY is based on operating experience whic h~ zh~:nthese Gomponcnts usually pass the Sur~i1Tncc~hc pcforcdAn the 18 month FrcgquencY.
With proper- precautions th1e c-ha-nncl c-1ibt Gan be per-formed This Surveillance ensures that the train actuation response times are within the maximum values assumed in the safety analyses.Response time testing acceptance criteria are included in Reference 1.Response time may be verified by any series of sequential, overlapping or total channel measurements, including allocated sensor response ti.me, such that the response time is verified.
Allocations for sensor response times may be obtained from records of test results, vendor test data, or vendor engineering specifications.
Topical Report CE NPSD-1167-A, "Elimination of Pressure Sensor Response Time (continued)
PALO VERDE UNITS 1,2,3 B 3.3.5-28 REVISION 3 ESFAS Instrumentation B 3.3.5 BASES SURVEILLANCE SR 3.3.5.4 (continued)
REQUIREMENTS Testing Requirements," (Ref. 10) provides the basis and methodology for using allocated sensor response times in the overall verification of the channel response time for specific sensors identified in the Topical Report. Response time verification for other sensor types must be demonstrated by test. The allocation of sensor response times must be verified prior to placing a new component in operation and re-verified after maintenance that may adversely affect the sensor response time.ESF RESPONSR TIME tests, are. .onduted on a STAGERED TEST BASI of nce every 108 month-s. The 318 month Frcgency i conr-Rsi"stenRt with thc i.dstry refueling cy-cle aRndl i-s based upon plant operating expeine ihic-h shows1 th-at ser-ious r-esponse time degradation, but not channel failure, SR 3.3.5.5 is a CHANNEL FUNCTIONAL TEST similar to SR 3.3.5.2, except SR 3.3.5.5 is performed within 92 days prior to startup and is only applicable to operating bypass functions.
Since the Pressurizer Pressure -Low operating bypass is identical for both the RPS and ESFAS, this is the same Surveillance performed for the RPS in SR 3.3.1.13.The CHANNEL FUNCTIONAL TEST for proper operation of the operating bypass permissives is critical during plant heatups because the bypasses may be in place prior to entering MODE 3 but must be removed at the appropriate points during plant startup to enable the ESFAS Function.Consequently, just prior to startup is the appropriate time to verify operating bypass function OPERABILITY.
Once the operating bypasses are removed, the bypasses must not fail in such a way that the associated ESFAS Function is inappropriately bypassed.
This feature is verified by SR 3.3.5.2.The allowance to conduct this test with 92 days of startup is based on the reliability analysis presented in topical report CEN-327, "RPS/ESFAS Extended Test Interval Evaluation" (Ref. 9).(conti nued)PALO VERDE UNITS 1,2,3 B 3.3.5-29 REVISION 3 ESFAS Logic and Manual Trip B 3.3.6 BASES ACTIONS F.1 and F.2 (continued)
If the Required Actions and associated Completion Times for SIAS, CIAS, or RAS are 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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and to MODE 5 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. If the Required Actions and associated Completion Times for SIAS, CIAS, or RAS Matrix Logic are not met this Action may be exited when the plant is brought to MODE 4 since the LCO does not apply in MODE 4. 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 3.3.6.1 REQUIREMENTS A CHANNEL FUNCTIONAL TEST is performed every-92 days to ensure the entire channel will perform its intended function when needed.The CHANNEL FUNCTIONAL TEST is part of an overlapping test sequence similar to that employed in the RPS. This sequence, consisting of SR 3.3.5.2, SR 3.3.6.1, and SR 3.3.6.2, tests the entire ESFAS from the bistable input through the actuation of the individual subgroup relays.These overlapping tests are described in Reference 1.SR 3.3.5.2 and SR 3.3.6.1 are normally performed together and in conjunction with ESFAS testing. SR 3.3.6.2 verifies that the subgroup relays are capable of actuating their respective ESF components when de-energized.
These tests verify that the ESFAS is capable of performing its intended function, from bistable input through the actuated components.
SR 3.3.5.2 is addressed in LCO 3.3.5.SR 3.3.6.1 includes Matrix Logic tests and trip path (Initiation Logic) tests, and Manual Actuation Tests.(continued)
PALO VERDE UNITS 1,2,3 B 3.3.6-19 REVISION 4 ESFAS Logic and Manual Trip B 3.3.6 BASES SURVEILLANCE Trip Path (Initiation Logic) Tests (continued)
During the Matrix Logic and Initiation Logic test, power is applied to the Matrix relay test coils. The test coils prevent an actuation during testing by preventing the Matrix relay contacts in the Initiation Logic from changing state during the test. This does not affect the Operability of the Initiation Logic since only one of the six logic combinations that are available to trip the Initiation Logic are affected during the test because only one Matrix Logic combination can be tested at any time.The remaining five matrix combinations available ensure that a trip in any three channels will de-energize all four Initiation paths.Manual Trip Tests This test verifies that the manual trip handswitches are capable of opening contacts in the Actuation Logic as designed.Thc Fr.quen.y Of 92 dayS is ba sed on the reliability Individual ESFAS subgroup relays must also be tested, one at a time, to verify the individual ESFAS components will actuate when required.
Proper operation of the individual subgroup relays is verified by de-energizing these relays one at a time using an ARC mounted test circuit. Proper operation of each component actuated by the individual relays is thus verified without the need to actuate the entire ESFAS function.The Q months Staggered Test Freq.ue2ncy, is -b-edd on ogprati-',ng exper-ienc and en.ures in a l relG, problems cron be detected-within this time frame. Considering the large number of si-m;lr relays in the ARC, and the similarity in the ir use, a l arge test sample c-an be assembled to verif-y IInsert .... ....... too oeE S subgroup relays fail per Unit in a 12-month period, an evaluation should be performed to determine the adequacy of the surveillance interval.
The evaluation should consider the design, maintenance, and (continued)
PALO VERDE UNITS 1,2,3 B 3.3.6-21 REVISION -
DG -LOVS B 3.3.7 BASES SURVEILLANCE The following SRs apply to each DG -LOVS Function.REQUIREMENTS SR 3.3.7.1 Performance of the CHANNEL CHECK nce every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 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 shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.
A CHANNEL CHECK consists of verifying all relay status lights on the control board are lit. CHANNEL CHECK will detect gross channel failure: thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the plant staff. If the channels are within the criteria, it is an indication that the channels are OPERABLE.
For clarification, a CHANNEL CHECK is a qualitative assessment of an instrument's behavior.
Where possible, a numerical comparison between like instrument channels should be included but is not required for an acceptable CHANNEL CHECK performance.
The Frequency, about oncer-- eavervy shift, is based up operating experiencethat demontratnesq ch-ne l failuei rare. H iAN rNCe the proEbability of to rmando-rm ,ailu-e,,s in redundahnti channels in any 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> period is extremely low, the CHANNEL CHECK minimizes; the chancep of loss of proetective funct-ion due to filu;4,wreP of rdndant c-hannelsR The CHANNEirL CHECK. Wupements.
less formal, but more frequent, checks of channel OP 6--ifERAIITY duignral oper-ational use of the A CHANNEL FUNCTIONAL TEST is performed evr 9mnh to ensure that the entire channel will perform its intended function when needed.The Frequency Of 18 monAthsA is based on plant operating-exprinc wih egrdtoA c-hannel O-PER-ABIL1ITY aind drift-, w:hich demntates-that falue f mor-e thanm one channmel o-f a given Function ~n any 18 months Frequency is a rape event.(continued)
PALO VERDE UNITS 1,2,3 B 3.3.7-8 REVISION 61 DG -LOVS B 3.3.7 BASES SURVEILLANCE SR 3.3.7.2 (continued)
REQUIREMENTS Any setpoint adj-utment
-hall be cnrstent with the-a:sum.tirnr~-;r( G-uI-plan- "-~f-; (-6'l-trD-i';-- [insert 1 :::ý an as left values must also be recorded and reviewed for consistency.
SR 3.3.7.3 SR 3.3.7.3 is the performance of a CHANNEL CALIBRATION every!9 months. The CHANNEL CALIBRATION verifies the accuracy of each component within the instrument channel. This includes calibration of the Loss of Voltage and Degraded Voltage relays and demonstrates that the equipment falls within the specified operating characteristics defined by the manufacturer.
The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.
CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive surveillances to ensure the instrument channel remains operational.
CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.
Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency.
The setpoints, as well as the response to a Loss of Voltage and Degraded Voltage test, shall include a single point verification that the trip occurs within the required delay time, as shown in Ref The Frequency is bascd upon th ýf~ 8 ýmceth calibration interviial fo-r- t-he Insert 1 ......e magnitude of equi pment d.r.i.ft-i.n the sctpein~t analysis.REFERENCES
- 1. UFSAR, Section 8.3 2. UFSAR, Chapter 15.3. Controlled Dwg. Relay Setpoint Sheets.4. 10 CFR 50, Appendix A, GDC 21.5. Calculation 13-EC-PB-202
- 6. Calculations 01, 02, 03-EC-MA-221 PALO VERDE UNITS 1,2,3 B 3.3.7-9 REVISION CPIAS B 3.3.8 BASES SURVEILLANCE SR 3.3.8.1 REQUIREMENTS Performance of the CHANNEL CHECK orce every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ensures that a gross failure of instrumentation has not occurred on the required radiation monitor channels used in the CPIAS.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.
It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure: thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
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 transmitter or the signal processing equipment has drifted outside its limit. For clarification, a CHANNEL CHECK is a qualitative assessment of an instrument's behavior.
Where possible, a numerical comparison between like instrument channels should be included but is not required for an acceptable CHANNEL CHECK performance.
The Frequency, about once every shift, is based on operating experience that deosrtsthe rarity Of c-hannel-failurme.S~inc-e thek probability of two rdandoam fdailure-s in red-undant c-h-annel-in aRy 12 period is low, the- CPUNANEI CHECK miniize the chance of loss of protective function due toe fa4lr o r.edundant The CHANNEL CHECK suppl ements less for-mal , but more f requent-, check;-iis of channel OPERATILITY during normal oper-ational use o4f the-displays associated with the LC. required insert 1J ...A CHANNEL FUNCTIONAL TEST is performed on each required containment radiation monitoring channel (RU-37 and RU-38)to ensure the entire channel will perform its intended f uncti oL Te Frequency of 92 days is based on plant-chane........
o ag.intio.n.
in any 92 day requenc.y is a (continued)
PALO VERDE UNITS 1,2,3 B 3.3.8-6 REVISION CPIAS B 3.3.8 BASES SURVEILLANCE SR 3.3.8.3 REQUIREMENTS (continued)
Proper operation of the individual actuation relays is verified by actuating these relays during the CHANNEL FUNCTIONAL TEST of the Actuation Logic every 18 menths.This will actuate the Function, operating all associated equipment.
Proper operation of the equipment actuated by each train on thannel of a. ..e Funcetio during ....n...m In s e rt 1 a ndL! T d,, r i f t , ,.h i h d ......÷- .m-'A h a t÷ .l .. ..I w e 18 month in a] i... ..a rare event. A Note to the SR indicates that this Surveillance includes verification of operation for each actuation relay.SR 3.3.8.4 CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor. The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.
CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive surveillances.
CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.Thp, 1R m h CD-aPy 4- b6e- en rplaRt experiece w-#1th r-egard to- chwanne! OPEPZRB!L!-TY4 t IInsert 1m (continued)
PALO VERDE UNITS 1,2,3 B 3.3.8-7 REVISION 4 CPIAS B 3.3.8 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.8.5 A Every 18 menths, a CHANNEL FUNCTIONAL TEST is performed on the CPIAS Manual Trip channel.This test verifies that the trip handswitches are capable of opening contacts in the Actuation Logic as designed, de-energizing the initiation relays and providing manual actuation of the Funcuc The 18 m .nth Frequency
- 4. ..d Insert .-_ .....the.. ..illane when p .f.r.med at a .qun.y t oc -er 18 rvei .-.... ..REFERENCES
- 1. UFSAR, Chapter 15.2. 10 CFR 100.3. "Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants," NUREG-75/087, Revision 1, 1978, Section 6.2.4, Branch Technical Position CSB 6-4, "Containment Purging During Normal Plant Operation." PALO VERDE UNITS 1,2,3 B 3.3.8-8 REVISION 44 CREFAS B 3.3.9 BASES SURVEILLANCE SR 3.3.9.1 REQUIREMENTS Performance of the CHANNEL CHECK ence every 12 heurs ensures that a gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.
It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
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 transmitter or the signal processing equipment has drifted outside its limit. For clarification, a CHANNEL CHECK is a qualitative assessment of an instrument's behavior.
Where possible, a numerical comparison between like instrument channels should be included but is not required for an acceptable CHANNEL CHECK performance.
The Frequenczy, about once euery shift, is bhased- on operating-Sine teprbability of tw:o r-andom failur-es in r-e-dundant.
chýan-neZlsin any 12 hour- proislthCHNLCECKU minimizes the c-hance of loss. of proetective function due to failure.of hannel.. The CHANNEL CHECK supplements; less formal, but more frequent, checks of chann.....el..
I normal operational use.e of the I nsert SR 3.3.9.2 A CHANNEL FUNCTIONAL TEST is performed on each required control room radiation monitoring channel (RU-29 and RU-30)to ensure the entire channel will perform its intended function.The Frequency of 92 days is based 9 lateeaig CpCl-nCC withi Few"r 4;. W-Fr-.EAAi 4-4-*I1I RflU Grl, whic demnstrtes hat ail re of.or than one channel of-a givn Fuctio in any 92 isna r FO evet.Insert (continued)
PALO VERDE UNITS 1,2,3 B 3.3.9-5 REVISION ~1 PALO VERDE UNITS 1,2,3 B 3.3.9-5 REVISION 64 CREFAS B 3.3.9 BASES SURVEILLANCE SR 3.3.9.3 REQUIREMENTS (continued)
Proper operation of the individual actuation relays is verified by de-energizing these relays during the CHANNEL FUNCTIONAL TEST of the Actuation Logic every 19 menths.This will actuate the Function, operating all associated equipment.
Proper operation of the equipment actuated by each train is thus verified.The Gf 18 monlthsl is based on plant opcIati.....icnc W.h ..... to Ph.nn.l OPERABILITY, which d emontrate-s that failurc of mor-1 than one chnel oif -a-es is Surveillance includes verification of insert 1operation for each actuation relay.Note 2 indicates that relays that cannot be tested at power are excepted from the Surveillance Requirement while at power. These relays must, however, be tested during each entry into MODE 5 exceeding 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> unless they have been tested within the previous 6 months. At PVNGS all of the actuation relays can be tested at power.SR 3.3.9.4 CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor. The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.
CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive surveillances.
CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.The Frequency is based upon the assumption of an 18 month calibration interval forthe derM...inatioAn.
oonitiue (conti nued)PALO VERDE UNITS 1,2,3 B 3.3.9-6 REVISION 4 CREFAS B 3.3.9 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.9.5 A Every 18 months, a CHANNEL FUNCTIONAL TEST is performed on the manual CREFAS actuation circuitry.
This test verifies that the trip handswitches are capable of opening contacts in the Actuation Logic as designed, de-energizing the actuation relays and providing Manual Trip of the functio-Tk^ 10 mnn *k Crni-n-i 4 k kcA 4.. .L...r -f n- nn n-insert 1]-Insert-F_ -I --I I "'..r.,-fft -_ im... .ruwl flsCcRelonfts usually, pass the-v I Survepillance when per-formcd-at a Frcequcncy of once every SR 3.3.9.6 This Surveillance ensures that the train actuation respons times are less than the maximum times assumed in the analyses.
Response time testing criteria are included in Refe-ren. Response Time te.sts arc , A-endutd on a Tet asiS of once per 18 monthsR. The 18 month+Freqencyis based upon plant operating experience, wuhich Sh AWS thait rdmfRailures of. instrumentation components e causing serious response time degradation, but not channel failure, are infrequent occurnrenc-es.
Testing of the final actuating deices, hihmake up the bulk of the response time, is included inthSueilneesng REFERENCES
- 1. UFSAR, Chapter 15.2. 10 CFR 50, Appendix A, GDC 19.3. UFSAR, Chapter 7.PALO VERDE UNITS 1,2,3 B 3.3.9-7 REVISION 4 PAM Instrumentation B 3.3.10 BASES ACTIONS F.1 (continued)
Alternate means of monitoring Reactor Vessel Water Level, RCS Activity, and Containment Area Radiation have been developed and tested. These alternate means may be temporarily installed if the normal PAM channel cannot be restored to OPERABLE status within the allotted time. If these alternate means are used, the Required Action is not to shut down the plant, but rather to follow the directions of Specification 5.6.6. The report provided to the NRC should discuss whether 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 A Note at the beginning of the SR table specifies that REQUIREMENTS the following SRs apply to each PAM instrumentation Function found in Table 3.3.10-1.SR 3.3.10.1 Performance of the CHANNEL CHECK ne e.very 31 days, ensures that a gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.
It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of 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. If the channels are within the criteria, it is an indication that the channels are OPERABLE.
For clarification, a CHANNEL CHECK is a qualitative assessment of an instrument's behavior.Where possible, a numerical comparison between like instrument channels should be included but is not required for an acceptable CHANNEL CHECK performance. (continued)
PALO VERDE UNITS 1,2,3 B 3.3.10-19 REVISION &I PAM Instrumentation B 3.3.10 BASES SURVEILLANCE REQUIREMENTS SR 3.3.10.1 (continued)
If the channels are normally off scale during times when surveillance is required, the CHANNEL CHECK will only verify that they are off scale in the same direction.
Current loop channels are verified to be reading at the bottom of the range and not failed downscale.
Thcre ..qun.y of 31 days i s based upon plant experience with rcgard to cha~nnl OPERABILITY and drift, which demonstrates that failure of more than onc Ghnclo a given Function in any 31 day interval is a rare e~The CHANNEL CHECK supplcments lcss formal, but more frequent, cheeks of channel during norma] operation1 of the displays aoiated with this L-C-Gs required-insert 11 -_____3.3._1C._
A CHANNEL CALIBRATION is performed every 18 months or approximately every refue.ing.
CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor. The Surveillance verifies the channel responds to the measured parameter within the necessary range and accuracy.
A Note excludes the neutron detectors from the CHANNEL CALIBRATION.
For the Containment Area Radiation instrumentation, CHANNEL CALIBRATION as described in UFSAR Sections 18.II.F.1.3 and 11.5.2.1.6.2 will be performed.
a The calibration of the Containment Isolation Valve (CIV)position indication channels will consist of verification that the position indication changes from not-closed to closed when the valve is actuated to its isolation position by SR 3.6.3.7. The position switch is the sensor for the CIV position indication channels.The Frequency is based upon operating experience an~d consistency with the typical industry refueling cycle and, is justified by the assumption of an 18 month calibration interval for the determination of the magnitude of-equipment drift Insert 1 PALO VERDE UNITS 1,2,3.B 3.3.10-20 REVISION _W Remote Shutdown System B 3.3.11 BASES ACTIONS C.1 and C.2 (continued)
If the Required Action and associated Completion Time of Condition A are 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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and to MODE 4 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. The allowed Completion Times are reasonable, based on operating experience, to reach the required MODE from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.3.11.1 REQUIREMENTS Performance of the CHANNEL CHECK G;e e--e--y-34 days ensures that a gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.
It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A CHANNEL CHECK will detect gross channel failure: thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability.
If a channel is outside the criteria, it may be an indication that the 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.
For clarification, a CHANNEL CHECK is a qualitative assessment of an instrument's behavior.
Where possible, a numerical comparison between like instrument channels should be included but is not required for an acceptable CHANNEL CHECK performance.
If the channels are normally off scale during times when surveillance is required, the CHANNEL CHECK will only verify that they are offscale in the same direction.
Current loop channels are verified to be reading at the bottom of the range and not failed downscale.
The FrequencY Of 31 day6 is based on plant operating expenienec-w:ith rcgard- to c-hannel1 OPER-ABILITY1 and drift, which dcmongtratcs.
that Fa iu oF more than Anc channel of a given Functiontin any Insert(conti nued)PALO VERDE UNITS 1,2,3 B 3.3.11-6 REVISION 61 Remote Shutdown System B 3.3.11 BASES SURVEILLANCE SR 3.3.11.2 REQUIREMENTS (continued)
SR 3.3.11.2 verifies that each required Remote Shutdown System transfer switch and control circuit performs its intended function.
The intended functions are: 1) To isolate the circuit from the control room.2) To provide the capability to operate the equipment from the remote shutdown location.This verification is performed from the remote shutdown panel and locally, as appropriate.
Operation of the equipment from the remote shutdown panel is not necessary.
The Surveillance can be satisfied by performance of a continuity check. This will ensure that if the control room becomes inaccessible, the plant can be brought to and maintained in MODE 3 from the remote shutdown panel and the local control statio The 18 month Frequn.c.
is hbasd on Iar- wn-r t i'° .....d- ti A-..unplan ne tran.sient i.f the S.urvi]]...a nce we re performed with the reactrat powe. Operating experienc-e ddemo-nstrates that Remo Shutdoiw System cont Prl o -m-l l hannel s m fVal toi pass the Surveillance when performed -at a Frequency of once every 18 months.SR 3.3.11.3 CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor. The Surveillance verifies that the channel responds to the measured parameter within the necessary range and accuracy.The 18 month Frequency is based on the need to perform this Surveillance under.. t conditions that appy .during a plant od the potential for an unplanned transient if the IInsert 1_t REFERENCES
- 1. 10 CFR 50, Appendix A, GDC 19.2. 10 CFR 50, Appendix R.PALO VERDE UNITS 1,2,3 B 3.3.11-7 REVISION ,54 Boron Dilution Alarm System (BDAS)B 3.3.12 BASES (continued)
SURVEILLANCE REQUIREMENTS SR 3.3.12.1 S-R 2.2.12.1 is the perf~forance Of a CHANNEL CHECK on eac-h..... hannel every 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.
It is based upon the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure: thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the plant staff and should be based on a combination of the channel instrument uncertainties.
If a channel is outside of the criteria, it may be an indication that the transmitter or the signal processing equipment has drifted outside of its limits. If the channels are within the criteria, it is an indication that the channels are OPERABLE.
For clarification, a CHANEL CHECK is a qualitative assessment of an instrument's behavior.
Where possible, a numerical comparison between like instrument channels should be included but is not required for an acceptable CHANNEL CHECK performance.
The Frequency, about on, e .every shift, is based- o operating experience that demonstrates th rarity of c nAiI Since teprbability of two random failures; in reduindant chanel inany 12 hourpero seteeylw HNE CHEC minmizs th chnce f lss of proetective funcntion supplements less feorZmal b- frqet, checks o-f ch-anel nperational use This SR is modified by a Note that states the CHANNEL CHECK is not required to be performed until 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after neutron flux is within the startup range. Neutron flux is defined to be within the startup range following a reactor shutdown when reactor power is 2E-6% NRTP or less.(continued)
PALO VERDE UNITS 1,2,3 B 3.3.12-5 REVISION &I Boron Dilution Alarm System (BDAS)B 3.3.12 BASES SURVEILLANCE SR 3.3.12.2 REQUIREMENTS (continued)
A CHANNEL FUNCTIONAL TEST is performed every-92--
dy to ensure that the BDAS is capable of properly alerting the operator to a boron dilution event. Internal excore startup channel test circuitry is used to feed preadjusted test signals into the excore startup channel to verify the proper neutron flux indication is received at the BDAS.The 4.equ.n.y is based o operating exper.ience with regard to channel OPERABTILITY and drift-, 4h~ic~h demonstrteq that faiu o mo ha one chnnel in any 92 day Frequeny i s a Pape--y .This SR is modified by a Note that states the FUNCTONAL TEST is not required to be performed Iuntil 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after neutron flux is within the startup range. The 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is based on allowing a reasonable time to perform the testing following a plant shutdown.
Neutron flux is defined to be within the startup range following a reactor shutdown when reactor power is 2E-6% NRTP or less.The CHANNEL FUNCTIONAL TEST of the BDAS consists of online tests including verification of the control room alarm.SR 3.3.12.3 SR 3.3.12.3 is the performance of a CHANNEL CALIBRATION.
A-CANNIIEI C.ALIBRTATION is perfor.med every 18 mnths. The Surveillance is a complete check and readjustment of the excore startup channel from the input through to the BDAS.The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational.
This SR is modified by a Note to indicate that it is not necessary to test the detector, because generating a meaningful test signal is difficult:
the detectors are of simple construction, and any failures in the detectors will be apparent as a change in channel out_ , Insert 1 REFERENCES
- 1. UFSAR, Chapter 7 and Chapter 15.PALO VERDE UNITS 1,2,3 B 3.3.12-6 REVISION ra RCS Pressure, Temperature, and Flow DNB Limits B 3.4.1 BASES (continued)
SURVEILLANCE SR 3.4.1.1 REQUIREMENTS Since Required Action G1 *all.ows a Completi"n Time of 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to restore parameters that- ac not. within .limt, th 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Sureilance Frequency for pressurizer pressure is uffcict t enurethat the pressure can be rctrdt a noral loperation, steady state condition changcs and other cxpcctcd transient operations.
The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> interval has been shown by operating prac sufficient to regularly assess fo poetal degradation and i~nser 1t"S 3/1.Since Required -Action- 01 -allows a Completion Timeo 2nhours" to rsoe parameters that are net WASith limits,.the 12Shour Sureillance Frequency for cold leg temperature is uficintto cnsure that the WC coolant temperature can beastoremntof aS nlowrmal peration, steady state condition following load changes and other expected transient operations.
The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> interval has been shown by operating practice to be sufficient to regularly asss o potential degradation and to verify operation is wi PALO RED UIS123. 4. 1.1- REIIO3 The 3122 hour0.0361 days <br />0.867 hours <br />0.00516 weeks <br />0.00119 months <br /> SuvilneFrequency for RCS total flwrt is performed using the installed flow instrumentatin Th 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Frequency has been shown by operating expeinet be sufficient to assess fo ptnial degradation and to mo! fied by a Note that only requires performance of this SR in MODE 1. The Note is necessary to allow measurement of RCS flow rate at normal operating conditions at power with all RCPs running.REFERENCES
- 1. UFSAR, Section 15.PALO VERDE UNITS 1,2,3 B 3.4.1-5 REVISION Q RCS Minimum Temperature for Criticality B 3.4.2 BASES (continued)
APPLICABILITY The reactor has been designed and analyzed to be critical in MODES 1 and 2 only and in accordance with this specification.
Criticality is not permitted in any other MODE. Therefore, this LCO is applicable in MODE 1, and MODE 2 when Keff 1.0. Monitoring is required at or below a TCOld of 550 0 F. The no load temperature of 565°F is maintained by the Steam Bypass Control System.ACTIONS A.1 If Tcold is below 545 0 F, 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 30 minutes.Rapid reactor shutdown can be readily and practically achieved within a 30 minute period. The allowed time reflects the ability to perform this action and to maintain the plant within the analyzed range.S R URVEILLANCE SR 3.4.2.1 EQUIREMENTS
_ _eidica lly Tcold is required to be verified _> 545°F once within 30 minutes after any RCS loop Tcold < 550°F and every 30-minu"tes thereaft212.e, The 39 in,,t ti.m. pcried is reactor is critical and temperature is below 550 0 F. A second Frequency requires Tcold to be verified within 30 minutes of reaching criticality.
This will require repeated performance of SR 3.4.2.1 since a reactor startup takes longer than 30 minutes. The 30 minute time period is frequent enough to prevent inadvertent violation of the LCO.REFERENCES
- 1. UFSAR, Section 15.PALO VERDE UNITS 1,2,3 B 3.4.2-2 REVISION -
RCS P/T Limits B 3.4.3 BASES ACTIONS C.1 and C.2 (continued)
Besides restoring operation to within limits, an evaluation is required to determine if RCS operation can continue.
The evaluation must verify that the RCPB integrity remains acceptable and must be completed before continuing operation.
Several methods may be used, including comparison with pre-analyzed transients in the stress analyses, new analyses, or inspection of the components.
ASME Code,Section XI, Appendix E (Ref. 6), may be used to support the evaluation.
However, its use is restricted to evaluation of the vessel beltline.The Completion Time of prior to entering MODE 4 forces the evaluation prior to entering a MODE where temperature and pressure can be significantly increased.
The evaluation for a mild violation is possible within several days, but more severe violations may require special, event specific stress analyses or inspections.
Condition C is modified by a Note requiring Required Action C.2 to 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 3.4.3.1 REQUIREMENTS Verification that operation is within the PTLR limits is required every 30 min-tes when RCS pressure and temperature conditions are undergoing planned ch, i iInsert 1 I- ieJi.~ a _vaiilal tI aoio C tts ~ o i temperature rate Ao changc limits arc sp'"ificd in homr-ly inremcnt-R 30 milut permits assessment and'i corrt:iton Surveillance for heatup, cooldown, or ISLH testing may discontinued when the definition given in the relevant procedure for ending the activity is satisfied.
be plant (continued)
PALO VERDE UNITS 1,2,3 B 3.4.3-7 REVISION 62 RCS Loops -MODES 1 and 2 B 3.4.4 BASES SURVEILLANCE REQUIREMENTS SR 3.4.4.1 This SR requires verification every !2 he,-rs that the required number of RCS loops are in operation and circulating reactor coolant. Verification includes flow rate, temperature, or pump status monitoring, which help to ensure that forced flow is providing heat removal while maintaining the margin The Fr..uc..y of 12 h.ur.JInsert I P-- "~r-uLI1 arl ses"s degraý--Ri" -and-. .....n wi-hi zafety analyscz assumptionz.
In addition, control roo indic4-atin and- all ar.m.. wi lly i"ndicatc loop "tat REFERENCES
- 1. UFSAR, Section 15.PALO VERDE UNITS 1,2,3 B 3.4.4-4 REVISION 4 RCS Loops -MODE 3 B 3.4.5 BASES ACTIONS (continued)
C.1 and C.2 If no RCS loop is OPERABLE or in operation, all operations involving a reduction of RCS boron concentration must be immediately suspended.
This is necessary because boron dilution requires forced circulation for proper homogenization.
Action to restore one RCS loop to OPERABLE status and operation shall be initiated immediately and continued until one RCS loop is restored to OPERABLE status and operation.
The immediate Completion Times reflect the importance of maintaining operation for decay heat removal.SURVEILLANCE REQUIREMENTS SR 3.4.5.1 This SR requires verification every 12 heurs that the required number of RCS loops are in operation and circulating Reactor Coolant. Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing heat. .T.e-Insert 1 ... ..en+ .-9 r-eoulaprv aess deapadatien and verify I I I insert 1 opepation within safety analyscs assumptions.
1R addition, cntrol roomind'icaion
`nd alar-ms -ill- nrMA]]y indicaitc SR 3.4.5.2 This SR requires verification every 12 heous that the secondary side water level in each SG is 25% wide range.An adequate SG water level is required in order to have a heat sink for removal of the core decay heat from the reactor cool Thc 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> intprnwil Wghas R ben hownby-nnr~r~aetiete te be rýiffi-R 4 t t'e "igu'lrll' asss&-(continued)
PALO VERDE UNITS 1,2,3 B 3.4.5-4 REVISION RCS Loops -MODE 3 B 3.4.5 BASES SURVEILLANCE REQUIREMENTS (continued)
Iinsert " SR 3.4.5.3 Verification that the required number of RCPs are OPERABLE ensures that the single failure criterion is met and that an additional RCS loop can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation.
Verification is performed by verifying proper breaker alignment and power availability to the required RNCPs The Frequency of 7 dai's is cozidcd reaon- al,,, in ee;;tpels available and has he I i I I q I zno~ toPe aeeeptablC By eper-ating cxpericncc.
REFERENCES PVNGS Calculation 13-JC-SH-0200, Section 2.9 PALO VERDE UNITS 1,2,3 B 3.4.5-5 REVISION 6 RCS Loops -MODE 4 B 3.4.6 BASES SURVEILLANCE REQUIREMENTS SR 3.4.6.1 This SR requires verification every 12 he'urs that one required loop or train is in operation and circulating reactor coolant at a flow rate of greater than or equal t 4000 gpm. This ensures forced flow is providing heat removal. Verification includes flow rate, temperature, oi pump status m ..The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> FrcgucncY haS ben 0 r I insert 1 sbe.... -, appat-JLiRi pr-aetqee LU heC s.u1-ftie~
te reqIL U iar-asscss RCS loop In, additior,, control room indication and alaFrmS Will oremally indicatc loop status.SR 3.4.6.2 This SR requires verification every 12 hou-rs of secondary side water level in the required SG(s) _ 25% wide range. A adequate SG water level is required in order to have a heat sink for removal of the core decay heat from the reactor cool......
The 12 hAur int.r..al har ..h.W by operation F Insert 1 a6d verify opcration within safety analyses assumptions SR 3.4.6.3 Verification that the required pump is OPERABLE ensures that an additional RCS loop or SDC train can be placed in operation, if needed to maintain decay heat removal and reactor coolant circulation.
Verification is performed by verifying proper breaker alignment and power available to the required .4-ýo The Frcgquency of 7 days is considcred Insertl an ha benshown to bhe acceptable by oper-ating-REFERENCES
- 1. PVNGS Operating License Amendments 52, 38 and 24 for Units 1, 2 and 3, respectively, and associated NRC Safety Evaluation dated July 25, 1990.2. Not used.3. PVNGS Calculation 13-JC-SH-0200, Section 2.9.PALO VERDE UNITS 1,2.3 B 3.4.6-5 REVISION 662-RCS Loops -MODE 5, Loops Filled B 3.4.7 BASES (continued)
SURVEILLANCE REQUIREMENTS SR 3.4.7.1 This SR requires verification every 12 he'rs that one SDC train is in operation and circulating reactor coolant at a flow rate of greater than or equal to 3780 gpm. Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing decay heat r:ý The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Frequency s been sh.w. by .pcrating tc assess d.gr.adation Ind dityi o n iy within safety analyses assumptions Un .dditinn r-ontr-l room iniato .;d 4hr-mg. u.411* i* i I I ora Y inaicatcP 4oo9 StatuS.The SDC flow is established to ensure that core outlet temperature is maintained sufficiently below saturation to allow time for swapover to the standby SDC train should the operating train be lost.SR 3.4.7.2 Verifying the SGs are OPERABLE by ensuring their secondary side water levels are _> 25% wide range level ensures that redundant heat removal paths are available if the second SDC train is inoperable.
The Surveillance is required to be performed when the LCO requirement is being met by use of the SGs. If both SDC trains are OPERABLE, this SR is notTh 12 hA,,p IFr, a,,.en,,hy has -been shown., b,,
In se rt 1 =a n ve ri f .. .'.. ..i m'A.. .. i -saf ety anal y se as... ..... .ti o ns SR 3.4.7.3 Verification that the second SDC train is OPERABLE ensures that redundant paths for decay heat removal are available.
The requirement also ensures that the additional train can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation.
Verification is performed by verifying proper breaker alignment and power available to the required pumps. The Surveillance is required to be performed when the LCO requirement is being met by one of two SDC trains, e.g., both SGs have < 25% wide range water 1ev. The Frequency of 7 days i donsidered reasonab n view of other ad-.in.. ..... con.trols Insert Ixeiece (continued)
REVISION 4 PALO VERDE UNITS 1,2,3 B 3.4.7-6 RCS Loops -MODE 5, Loops Not Filled B 3.4.8 BASES ACTIONS A.1 If a SDC train is inoperable, redundancy for heat removal is lost. Action must be initiated immediately to restore a second train to OPERABLE status. The Completion Time reflects the importance of maintaining the availability of two paths for heat removal.B.1 and B.2 If no SDC train is OPERABLE or in operation, except as provided in NOTE 1, all operations involving the reduction of RCS boron concentration must be suspended.
Action to restore one SDC train to OPERABLE status and operation must be initiated immediately.
Boron dilution requires forced circulation for proper mixing and the margin to criticality must not be reduced in this type of operation.
The immediate Completion Time reflects the importance of maintaining operation for decay heat removal.SURVEILLANCE SR 3.4.8.1 REQU I REMENTS This SR requires verification every 2 ..h..s that one SDC train is in operation and circulating reactor coolant at a flow rate of greater than or equal to 3780 gpm. Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing decay heat removjaJ, The 12 hourP FregucncY has been shewn by eperating Insert 1 anayse
.. .. .....--ions.SR 3.4.8.2 Verification that the required number of trains are OPERABLE ensures that redundant paths for heat removal are available and that an additional train can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation.
Verification is performed by verifying proper breaker alignment and indicated power available to the required u The Frcgucncy of 7 days is eonsidcrcd Woi ,, Pl.v in pp Af: .tpr vp i rAt-iR ;iv i1i REFERENCES PVNGS Calculation 13-JC-SH-0200, Section 2.9.PALO VERDE UNITS 1,2,3 B 3.4.8-3 REVISION 6 Pressurizer B 3.4.9 BASES ACTIONS (continued)
B.1 If one required group of pressurizer heaters is inoperable, restoration is required within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. The Completion Time of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is reasonable considering that a demand caused by loss of offsite power would be unlikely in this period. Pressure control may be maintained during this time using normal station powered heaters.C.1 and C.2 If one required group of pressurizer heaters is inoperable and cannot be restored within the allowed Completion Time of Required Action B.1, 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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and to MODE 4 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. The Completion Time of 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> is reasonable, based on operating experience, to reach MODE 3 from full power in an orderly manner and without challenging safety systems. Similarly, the Completion Time of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is reasonable, based on operating experience, to reach MODE 4 from full power in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.4.9.1 REQU I REMENTS This Surveillance ensures that during steady state operation, pressurizer water level is maintained below the nominal upper limit to provide a minimum space for a steam bubble. The Surveillance is performed by observing the indlicatedl Tyeý 112 int,,,, va been- by..k... , insert 1 Fe. f -r.W. deviatio .... rif ..... +pe "-ae is within safetyn nz. Alrm- arca .la, l-blc for early dcte et in o-R f -abnor-m-a level indiecationz-.(continued)
PALO VERDE UNITS 1,2,3 B 3.4.9-5 REVISION 4 Pressurizer B 3.4.9 BASES SURVEILLANCE REQUIREMENTS SR 3.4.9.2 (continued)
The Surveillance is satisfied when the power supplies are demonstrated to be capable of producing the minimum power and the associated pressurizer heaters are verified to be at their design rating. (This may be done by testing the power supply output and by performing an electrical check on heater element continuit "Th Frcgucncy of insert 1 -nd hll been shown b epience to be acccpbble.
REFERENCES
- 1. NUREG-0737, November 1980.PALO VERDE UNITS 1,2,3 B 3.4.9-6 REVISION G Pressurizer Safety Valves-MODE 4 B 3.4.11 BASES (continued)
SURVEILLANCE SR 3.4.11.1 REQUIREMENTS SRs are specified in the Inservice Testing Program.Pressurizer safety valves are to be tested in accordance with the requirements of the ASME OM Code (Ref. 2), which provides the activities and the Frequency necessary to satisfy the SRs. No additional requirements are specified.
The pressurizer safety valve setpoint is +3%, -1% for OPERABILITY:
however, the valves are reset to +/- 1% during the Surveillance to allow for drift (Ref. 3). The lift setting pressure shall correspond to ambient conditions of the valve at nominal operating temperature and pressure.SR 3.4.11.2 SR 3.4.11.2 requires that therequired Shutdown Cooling System suction line relief lve is OPERABLE by verifying its open pathway condition a,- Once every 1_2 hours6 for -a AWalve th-at is unlocked, not_,ealc d, ootherwi se not secured open in the Avent pahway, or--b,- Oncse every 31 days for -a vWalve th-at is locGked, seale.en mo i fied by a Note that requires performance only if a Shutdown Cooling System suction line relief valve is being used for overpressure protection.
The Frequencies consider operating experience with mispositioning of unlocked and locked pathway vent valves.SR 3.4.11.3 SRs are specified in the Inservice Testing Program.Shutdown Cooling System suction line relief valves are to be tested in accordance with the requirements of the ASME OM Code (Ref. 2), which provides the activities and the Frequency necessary to satisfy the SRs. The Shutdown Cooling System suction line relief valve setpoint is 467 psig.(conti nued)PALO VERDE UNITS 1,2,3 B 3.4.11-5 REVISION 64 Pressurizer Vents B 3.4.12 BASES B.1 If all pressurizer vent paths are inoperable, then restore at least one pressurizer vent path to OPERABLE status. The Completion Time of 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> is reasonable to allow time to correct the situation, yet emphasize the importance of restoring at least one pressurizer vent path. If at least one pressurizer vent path is not restored to OPERABLE within the Completion Time, then Action C is entered.C.1 If the required Actions, A and B, cannot be met within the associated Completion Times, the plant must be brought to a MODE in which the requirement does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, and to MODE 4 with RCS pressure < 385 psia within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. 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.SURVEILLANCE SR 3.4.12.1 REQUIREMENTS SR 3.4.12.1 requires complete cycling of each pressurizer vent path valve. The vent valves must be cycled from the control room to demonstrate their operability.
Pressurizer vent path valve cycling demonstrates its fu The be performed in Mode 5 or Mode 6.SR 3.4.12.2 SR 3.4.12.2 requires verification of flow through each pressurizer vent path. Verification of pressurizer vent path flow demonstrates its fThe of Insert 1 GGW patrp test must be performed in Mode 5 or Mode 6.(conti nued)PALO VERDE UNITS 1,2,3 B 3.4.12-4 REVISION 4 LTOP System B 3.4.13 BASES ACTIONS B.1 (continued)(continued)
Cooling System suction line relief valve failures without exposure to a lengthy period with only one Shutdown Cooling System suction line relief valve OPERABLE to protect against overpressure events.C.1 If two required Shutdown Cooling System suction line relief valves are inoperable, or if a Required Action and the associated Completion Time of Condition A or B are not met, the RCS must be depressurized and a vent established within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />. The vent must be sized at least 16 square inches to ensure the flow capacity is greater than that required for the worst case mass input transient reasonable during the applicable MODES. This action protects the RCPB from a low temperature overpressure event and a possible brittle failure of the reactor vessel. For personnel safety considerations, the RCS cold leg temperature must be reduced to less than 200°F prior to venting.The Completion Time of 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> to depressurize and vent the RCS is based on the time required to place the plant in this condition and the relatively low probability of an overpressure event during this time period due to increased operator awareness of administrative control requirements.
SURVEILLANCE SR 3.4.13.1 and 3.4.13.2 REQUIREMENTS SR 3.4.13.1 and SR 3.4.13.2 require verifying that the RCS vent is open _> 16 square inches or that the Shutdown Coolip System suction line relief valves be aligned to provi .overpressure protection for the RCS is pro by verifying its open pathway condition SI. .-ApA,.,v, C niRg System nu C ,,s- .-n 4 n ,l ,, n , n -. ,,ml pnr-,.L., , Once every 1-2 for -valve th.at 4s w-lkd, seldo thris o scrd open in the- 40ent b-,- Once every 31 days for- ,, Wa,,1,, tha.lt i9 ,loked, sealed, or othcRiise securoedt open in the vent pathway.RG&-VeR#a-.- Once every 1-2 hoursP- for a vent pathway that is unlocked, not sealed, or other;si-se not secur-ed open (conti nued)PALO VERDE UNITS 1.2,3 B 3.4.13-9 REVISION 42-LTOP System B 3.4.13 BASES SURVEILLANCE SR 3.4.13.1 and 3.4.13.2 (continued)
REQUIREMENTS b I.- Onoc every 31 days for a vent pathw':ay that l lockId.se le , or- n~ ,,,r-is q e u 22 , eer .the specified flow capacity, it Insert I requires removing all pressurizer safety valves, or similarly establishing a vent by opening the pressurizer manway (Ref. 11). The vent path(s) must be above the level of reactor coolant, so as not to drain the RCS when open.The passive vent arrangement must only be open (vent pathway exists) to be OPERABLE.
These Surveillances need only be performed if the vent or the Shutdown Cooling System suction line relief valves are being used to satisfy the requirements of this LCO. The Frequencies consider operating experience with mispositioning of unlocked and locked pathway vent valves, and passive pathway obstructions.
SR 3.4.13.3 SRs are specified in the Inservice Testing Program.Shutdown Cooling System suction line relief valves are to be tested in accordance with the requirements of the ASME OM Code (Ref. 10), which provides the activities and the Frequency necessary to satisfy the SRs. The Shutdown Cooling System suction line relief valve set point is 467 psig.REFERENCES
- 1. 10 CFR 50, Appendix G.2. Generic Letter 88-11.3. UFSAR, Section 15.4. 10 CFR 50.46.5. 10 CFR 50, Appendix K.6. Generic Letter 90-06.7. UFSAR, Section 5.2.(continued)
PALO VERDE UNITS 1,2,3 B 3.4.13-10 REVISION 64 RCS Operational LEAKAGE B 3.4.14 BASES SURVEILLANCE SR 3.4.14.1 (continued)
REQU IREMENTS An early warning of pressure boundary LEAKAGE or unidentified LEAKAGE is provided by the automatic systems that monitor the containment atmosphere radioactivity and the containment sump level. These leakage detection systems are specified in LCO 3.4.16, "RCS Leakage Detection Instrumentation." Note 2 states that this SR is not applicable to primary to secondary LEAKAGE because LEAKAGE of 150 gallons per day cannot be measured accurately by an RCS water inventory balance.The 72 houpr F ,guency iS a eason-able interwal te txrnd LEAiKAGE -and rnecognizes the impor-tance of early leakage detec-tion in the pr-evention of accnidents This SR verifies that primary to secondary LEAKAGE is less than or equal to 150 gallons per day through any one SG.Satisfying the primary to secondary LEAKAGE limit ensures that the operational LEAKAGE performance criterion in the Steam Generator Program is met. If this SR is not met, compliance with LCO 3.4.18, "Steam Generator Tube Integrity," should be evaluated.
The 150 gallons per day limit is measured at room temperature as described in Reference
- 8. The operational LEAKAGE rate limit applies to LEAKAGE through any one SG. If it is not practical to assign the LEAKAGE to an individual SG, all the primary to secondary LEAKAGE should be conservatively assumed to be from one SG.The Surveillance is modified by a Note which states that the Surveillance is not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after establishment of steady state operation.
This means that once steady state operating conditions are established, 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is allowed for completing the Surveillance.
When required by the Frequency, and after steady state operating conditions are established, the surveillance must be completed prior to the end of 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> of steady state operation.
If steady state operating conditions have not been established for 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, this surveillance is not required until steady state operation is established for 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. This SR is not required to be completed prior to changing MODES if steady state operation (continued)
PALO VERDE UNITS 1,2,3 B 3.4.14-7 REVISION 39 RCS Operational LEAKAGE B 3.4.14 BASES SURVEILLANCE SR 3.4.14.2 (continued)
REQUIREMENTS has not been established for 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> allowance provides sufficient time to collect and process all necessary data after stable plant conditions are established.
Further discussion of SR note format is found in Section 1.4, Frequency.
The Note allows for SR 3.4.14.2 nonperformance due to planned or unplanned transients.
This Note is not intended to allow transients solely for the purpose of avoiding SR 3.4.14.2 performance.
For RCS primary to secondary LEAKAGE determination, steady state is defined as stable RCS pressure, temperature, power level, pressurizer and makeup tank levels, makeup and letdown, and RCP seal injection and return flows.The Surepillan-e Frequency Of 7i2 hors is a Geasonable intergal to trend primary to secndary LMAy9GE -and reco SizeR te tance of ealy leakage detectonit prevention of accpiddents.
The primar-y to secondary LEZAK~rG 4r dctcrmincd using continu -proess radiation monitors or radiochemical grab sampling in accordanea w:ith the EPRI REFERENCES
- 1. 10 CFR 50, Appendix A, GDC 30.2. Regulatory Guide 1.45, May 1913.3. UFSAR, Section 15.6.4. UFSAR, Section 6.4.5. 10 CFR Part 100.6. 10 CFR 50, Appendix A, GDC19.7. NEI 97-06, "Steam Generator Program Guidelines." 8. EPRI, "Pressurized Water Reactor Primary-to-Secondary Leak Guidelines." PALO VERDE UNITS 1,2,3 B 3.4.14-8 REVISION 39 RCS PIV Leakage B 3.4.15 BASES SURVEILLANCE REQUIREMENTS
!insert 1 ----SR 3.4.15.1 (continued)
For the two PIVs in series, the leakage requirement applies to each valve individually and not to the combined leakage across both valves. If the PIVs are not individually leakage tested, one valve may have failed completely and not be detected if the other valve in series meets the leakage requirement.
In this situation, the protection provided by redundant valves would be lost.Testing is to be performed every 9 months, but may be extended up to 18 months, a typical refueling cyc.ic, if the plant does not go into MODE 5 for at least7tTy The* 2. o .oy allowed by the AmepicMechanic.al Engineers (ASME) ON Code (Rcf. 7), and i basd onthe eedt perform the Sur-yeillan-e under-conitins hatappy during a plant outage and the potntalfor an unqplanned tranisienit if the Surweillanqce wer pefomed withthrecoatpe.
In addition, testing must be performed once after the valve has been opened by flow or exercised to ensure tight reseating.
PIVs disturbed in the performance of this Surveillance should also be tested unless documentation shows that an infinite testing loop cannot practically be avoided. Testing must be performed within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after the valve has been reseated.
Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> is a reasonable and practical time limit for performing this test after opening or reseating a valve.The SDC PIVs excepted in two of the three FREQUENCIES are UV-651, UV-652, UV-653, and UV-654, due to position indication of the valves in the control room.Although not explicitly required by SR 3.4.15.1, performance of leakage testing to verify leakage is below the specified limit must be performed prior to returning a valve to service following maintenance, repair or replacement work on the valve in order to demonstrate operability.
The leakage limit is to be met at the RCS pressure associated with MODES 1 and 2. This permits leakage testing at high differential pressures with stable conditions not possible in the MODES with lower pressures.(continued)
PALO VERDE UNITS 1.2,3 B 3.4.15-5 REVISION -54 RCS PIV Leakage B 3.4.15 BASES SURVEILLANCE REQUIREMENTS SR 3.4.15.1 (continued)
Entry into MODES 3 and 4 is allowed to establish the necessary differential pressures and stable conditions to allow for performance of this Surveillance.
The Note that allows this provision is complimentary to the Frequency of prior to entry into MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months. In addition, this Surveillance is not required to be performed on the SDC System when the SDC System is aligned to the RCS in the shutdown cooling mode of operation.
PIVs contained in the SDC shutdown cooling flow path must be leakage rate tested after SDC is secured and stable unit conditions and the necessary differential pressures are established.
SR 3.4.15.2 Verifying that the SDC open permissive interlocks are OPERABLE, when tested as described in Reference 10, ensures that RCS pressure will not pressurize the SDC system beyond 125% of its design pressure of 485 psig. The interlock setpoint that prevents the valves from being opened is set so the actual RCS pressure must be <410 psia to open the valves. This setpoint ensures the SDC design pressure will not be exceeded and the SDC relief valves (Reference
- 9) will not lI The IS mgifth PpgeG ...... baStd t hP APeed- to-bascd on considerati-V V of th e ndesig n that aIpi y confiýrmig oprtn xper-ience of the equipment.(continued)
PALO VERDE UNITS 1,2,3 B 3.4.15-6 REVISION 35 RCS Leakage Detection Instrumentation B 3.4.16 BASES (continued)
ACTIONS (continued)
C.1 If any Required Action of Condition A or B cannot be met 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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and to MODE 5 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. 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.D.1 If all required monitors are inoperable, no automatic means of monitoring leakage are available and immediate plant shutdown in accordance with LCO 3.0.3 is required.SURVEILLANCE REQUIREMENTS SR 3.4.16.1 SR 3.4.16.1 requires the performance of a CHANNEL CHECK of the required containment atmosphere radioactivity monitors.The check gives reasonable confidence the channel is operating pr ..... Ppqee .... 12.. hours- -is basd..insert 1 Gnr al o ditions.SR 3.4.16.2 SR 3.4.16.2 requires the performance of a CHANNEL FUNCTIONAL TEST of the required containment atmosphere radioactivity monitors.
The test ensures that the monitor can perform its function in the desired manner. The test verifies the alarm setpoint and relative accuracy of the instrument strin The alarm setpoints for the containment building atmosphere monitor (RU-1) are: particulate gaseous 2.3 x 10-6 pCi/cc CS-137 6.6 x 10-2 pCi/cc Xe-133 (continued)
PALO VERDE UNITS 1,2,3 B 3.4. 16-5 REVISION 4 RCS Leakage Detection Instrumentation B 3.4.16 BASES (continued)
SURVEILLANCE SR 3.4.16.3, SR 3.4.16.4 REQUIREMENTS (continued)
These SRs require the performance of a CHANNEL CALIBRATION for each of the RCS leakage detection instrumentation channels.
The calibration verifies the accuracy of the instrument string, including the instruments located inside containme The F=P ..u..y of 18 months is a typica~l and1 Pesiep insert thi Oprain cpcieccha sy is acceptable.
REFERENCES
- 1. 10 CFR 50, Appendix A, Section IV, GDC 30.2. Regulatory Guide 1.45.3. UFSAR, Section 5.2.5.PALO VERDE UNITS 1,2,3 B 3.4.16-6 REVISION 0 RCS Specific Activity B 3.4.17 BASES (continued)
SURVEILLANCE SR 3.4.17.1 REQUIREMENTS The Surveillance requires performing a gamma isotopic analysis as a measure of the gross specific activity of the reactor coolant at lea-st on.e pe 7 days. While basically a quantitative measure of radionuclides with half lives longer than 15 minutes, excluding iodines, this measurement is the sum of the degassed gamma activities and the gaseous gamma activities in the sample taken. This Surveillance provides an indication of any increase in gross specific activity.Trending the results of this Surveillance allows proper remedial action to be taken before reaching the LCO limit under normal operating conditions.
The Surveillance is applicable in MODES 1 and 2, and in MODE 3 with RCS cold leg temperature at least 0 The 7 day rq..u.cny c.nsidcrs SR 3.4.17.2 This Surveillance is performed to ensure iodine remains within limit during normal operation and following fast power changes when fuel failure is more ag .Iner.... 1 chny5nges in t.h.e iod-ine activity level considering 9ross activity is monitored every 7 days.. The 14 day surveillance frequency is modified by the Note "Only required to be performed in MODE 1." This is acceptable because the level of fission products generated in MODES 2 and 3 is much less than in MODE 1. The Frequency, between 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> and 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after a power change of 15% RTP within a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period, is established because the iodine levels peak during this time following fuel failure; samples at other times would provide inaccurate results. One sample is sufficient if the plant has gone through a shutdown or if the transient is complete in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.SR 3.4.17.2 14 day Frequency is modified by a Note which requires the Surveillance to only be performed in MODE 1.This is required because the level of fission products generated in other MODES is much less. Also, fuel failures associated with fast power changes is more apt to occur in MODE 1 than in MODES 2 or 3.(continued)
PALO VERDE UNITS 1,2,3 B 3.4.17-5 REVISION 0 RCS Specific Activity B 3.4.17 BASES SURVEILLANCE REQUIREMENTS SR 3.4.17.3 (continued)
A radiochemical analysis for E determination is required every 181 days (6 with the plant operating in MODE 1 equilibrium conditions.
The E determination directly relates to the LCO and is required to verify plant operation within the specified gross activity LCO limit. The analysis for E is a measurement of the average energies per disintegration for isotopes with half lives longer than 15 minutes, excludin i The F..guency of 184 days IInsert 1 .........= ....This SR has been modified by a Note that indicates sampling is required to be performed within 31 days after 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> should the 184 day Frequency interval be exceeded.
Further discussion of SR Note format is found in Section 1.4.Frequency.
equilibrium skewed by a This ensures the radioactive materials are at so the analysis for E is representative and not crud burst or other similar abnormal event.REFERENCES
- 1. 10 CFR 100.11, 1973.2. UFSAR, Section 15.6.3.PALO VERDE UNITS 1,2,3 B 3.4.17-6 REVISION SITs-Operating B 3.5.1 BASES (continued)
SURVEILLANCE SR 3.5.1.1 REQUIREMENTS Verification every 12 he'-rs that each SIT isolation valve is fully open, as indicated in the control room, ensures that SITs are available for injection and ensures timely discovery if a valve should be partially closed. If an isolation valve is not fully open, the rate of injection to the RCS would be reduced. Although a motor operated valve should not change position with power removed, a closed valve could result in not meeting accident analysis assumpti 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Frc..qu..
is considcred .easonabic Insert 1 Wl -4 l il- hA_9_l e i ..-.Soal -;I- tie .A v-;Iwe.SR 3.5.1.2 and SR 3.5.1.3 SIT borated water volume and nitrogen cover pressure should be verified to be within specified limits every -2 hm'-rs in order to ensure adequate i njectio Due-Wptoe Insert 1 p su.,iient time to ident-fy changes bcfor thclimits -are rcacRhcd.
Opcratingeprec a IshGIwn this Frqec t e propiatc for early detection and correction of off normal trends.SR 3.5.1.4 Thirty-one days is reasonable for verification to determine that each SIT's boron concentration is within the required limits, because the static design of the SITs limits the ways in which the concentration can b2e The 31 day I-- /I ,I. "1[" ,I-- I Verificationame ofHa boron cnnttinbpefrng AP cIlculeti, n based onm level inceVs, ia bo roln conentatin, nd astsamler-esults, or- by sampling the affetedSIT w~ithin 6 hour-s. whenewcr R SIT is drained to mai n c n b identify whether inekg ha case w reductioA-n i n bo eroý_n. co--nc.r-e nt ra tioen toA helem: the required limit. It is not nercessaray to verify born cncetraionif the ad-ded- water is from the RWT-, because the wat-r containdin the RlIIT i6 within t h SIT boronR concntration r-equir-ements." This is consistent with t lhe-of, NURIEG 1366 5)(continued)
PALO VERDE UNITS 1,2,3 B 3.5.1-9 REVISION 0 SITs-Operating B 3.5.1 BASES (continued)
SURVEILLANCE REQUIREMENTS SR 3.5.1.5 (continued)
Verification every-31-day&
that power is removed from each SIT. isolation valve operator ensures that an active failure could not result in the undetected closure of a SIT motor operated isolation valve. If this were to occur, only two SITs would be available for injection, given a single failure coincident with Snc instalatio
..nd insert IcoNdaducted under administratie control, the 31 day Frequency IMas chIe bto F poide add itbionial -a-ssurancm-e that power is SR 3.5.2.5 allows power to be supplied to the motor operated isolation valves when RCS pressure is < 1500 psia, thus allowing operational flexibility by avoiding unnecessary delays to manipulate the breakers during unit startups or shutdowns.
Even with power supplied to the valves, inadvertent closure is prevented by the RCS pressure interlock associated with the valves. Should closure of a valve occur in spite of the interlock, the SI signal provided to the valves would open a closed valve in the event of a LOCA. At RCS pressures above the valve auto-open interlock, the maximum pressure at which the SIAS open signal will open the valves is limited by the valve operator differential pressure design capability.
REFERENCES
- 1. IEEE Standard 279-1971.2. UFSAR, Section 6.3. 10 CFR 50.46.4. UFSAR, Chapter 15.5. NUREG-1366, "Improvements to Technical Specifications Surveillance Requirements," December 1992.6. CE NPSD-994, "CEOG Joint Applications Report for Safety Injection Tank AOT/STI Extension," May 1995.7. UFSAR Section 7.6.2.2.2.
- 8. TRM T3.5 (ECCS): TSR 3.5.200.4 PALO VERDE UNITS 1,2,3 B 3.5.1-10 REVISION 63 SITs -Shutdown B 3.5.2 BASES SURVEILLANCE REQUIREMENTS SR 3.5.2.1 Verification every !2 he-rs that each required SIT isolation valve is fully open when pressurizer pressure is _> 430 psia as indicated in the control room. ensures that the required SITs are available for injection and ensures timely discovery if a valve should be partially closed. If a required isolation valve is not fully open, the rate of injection to the RCS would be reduced. Although a motor operated valve should not change position with power removed, a closed valve could result in not meeting accident analysis ^ .... A 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> F .equencyi.
Pc. -id I Insert 1 1--- PA a.~~uri~nrrt~
othe all:uiM4AIF uIIrI-.Lr'JLI_.41.;
__RI~U~ [ure tetn~klhodo a Mi s;ositioncd isolAation A_;he.SR 3.5.2.2 and SR 3.5.2.3 Borated water volume and nitrogen cover pressure for the required SITs should be verified to be within specified limits every 12 he'.-'s in order to ensure adequate injection durin Due to the static design of the SITs, a 12 In s e rt , + .------4:. -. ..h p th p l i mi t- .... .. .. -h pd*Operating exeineha-s Shown this Frequency to be approepr-iatc for early detection and cr-rrection of off normal t~ends.SR 3.5.2.4 Thirty-one days is reasonable for verification to determine that each required SIT's boron concentration is within the required limits, because the static design of the SITs limits the ways in which the concentration can be chanye perIformi n a ca-cuatio based on increase.
RCS born concentratio, and last sample results, or sampling the affcte SIT within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> whenever aR SIT is drpained to maintaimn contained berated water l e'vel will. identi fy .whether inleakage has cau-sed a redu-ction in beron concentration to" belo t..he r.quire 4,limi.+ It is not necessary to verify bdfrom the RTu, (conti nued)PALO VERDE UNITS 1,2,3 B 3.5.2-9 REVISION -
SITs -Shutdown B 3.5.2 BASES SURVEILLANCE SR 3.5.2.4 (continued)
REQUIREMENTS beca'use the ..ater. contincd in the RIT igs withi thc SIT boro conentrtion rcquircr ts." This; is conSiStent With the rcommndatons f NUHREG 136 (Ref1.SR 3.5.2.5 Verification every-41 day.& that power is removed from each required SIT isolation valve operator when the pressurizer pressure is 1500 psia ensures that an active failure could not result in the undetected closure of a SIT motor operated isolation valve. If this were to occur, two less than the required SITs would be available for injection, given a single failure coincident with a LOCA.Since installation and remo'eal of power to the SIT iseolation valve is eonducted " admi tr-*4"e control,-the 31 day Frequency was chosen to ppevide -ad-ditionRal Slnser 11 --1 SR allows power to be supplied to the motor operated isolation valves when pressurizer pressure is < 1500 psia, thus allowing operational flexibility by avoiding unnecessary delays to manipulate the breakers during unit startups or shutdowns.
Even with power supplied to the valves, inadvertent closure is prevented by the RCS pressure interlock associated with the valves. Should closure of a valve occur in spite of the interlock, the SI signal provided to the valves would open a closed valve in the event of a LOCA. At RCS pressures above the valve auto-open interlock, the maximum pressure at which the SIAS open signal will open the. valves is limited by the valve operator differential pressure design capability.
REFERENCES
- 1. IEEE Standard 279-1971.2. 10 CFR 50.46.3. UFSAR, Chapter 15.4. NUREG-1366, "Improvements to Technical Specifications Surveillance Requirements," December 1992.5. CE NPSD-994, "CEOG Joint Applications Report for Safety Injection Tank AOT/STI Extension," May 1995.6. UFSAR Section 7.6.2.2.2 7. TRM T3.5 (ECCS): TSR 3.5.200.4 PALO VERDE UNITS 1,2,3 B 3.5.2-10 REVISION 5 ECCS -Operating B 3.5.3 BASES SURVEILLANCE SR 3.5.3.1 REQUIREMENTS 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 actuation signal is allowed to be in a nonaccident position provided the valve automatically repositions within the proper stroke time. This Surveillance does not require any testing or valve manipulation.
Rather, it involves verification that those valves capable of being mispositioned are in the correct position.The 31 day -i ppropri-ate the ,,alve are operated unde prcd ralcntronl and an improper-vale position would ony feca ngetrain.
Thi-s Fr-equenc-y has, been shownl to bepacceptable through operating InsertI SR 3.5.3.2 With the exception of systems in operation, the ECCS pumps are normally in a standby, nonoperating mode. As such, flow path piping has the potential to develop voids and pockets of entrained gases. The method of ensuring that any voids or pockets of gases are removed from the ECCS piping is to vent the accessible discharge piping high points, which is controlled by PVNGS procedures.
Maintaining the piping from the ECCS pumps to the RCS full of water ensures that the system will perform properly, injecting its full capacity into the RCS upon demand. This will also prevent water hammer, pump cavitation, and pumping of noncondensible gas (e.g., air, nitrogen, or hydrogen) into the reactor vessel following an SIAS or dur .. The 31 day Frequency takes int RtAeg u naueof ga cuua ioni Insertpip ng and the adequacy of the procedural controls6 go-erning system operation.(continued)
PALO VERDE UNITS 1,2,3 B 3.5.3-8 REVISION -
ECCS -Operating B 3.5.3 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.3.3 Periodic surveillance testing of ECCS pumps to detect gross degradation caused by impeller structural damage or other hydraulic component problems is required by the ASME OM Code. This type of testing may be accomplished by measuring the pump developed head at only one point of the pump characteristic curve. This verifies both that the measured performance is within an acceptable tolerance of the original pump baseline performance and that the performance at the test flow is greater than or equal to the performance assumed in the unit safety analysis.
SRs are specified in the Inservice Testing Program, which encompasses the ASME OM Code (Ref. 7). The frequency of this SR is in accordance with the Inservice Testing Program.SR 3.5.3.4. SR 3.5.3.5, and SR 3.5.3.6 These SRs demonstrate that each automatic ECCS valve actuates to the required position on an actual or simulated SIAS and on an RAS, that each ECCS pump starts on receipt of an actual or simulated SIAS, and that the LPSI pumps stop on receipt of an actual or simulated RAS. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative control The 18 menth Frequency is based on that apply duping a plant outage and the potential for unplanned transients if thc S-rurvillan-es were per-formed nith the r eator thpower Th I18 month Pre is also acceptable based on consideration of the design reliability (and confirnmingq operating experience) of the equipment.
The-actutio1loic is tested as part of the Engineered Safety Featu eAtuation System (ESFAS) testing, and equipment 4ArFoRm~nc ig monitorcd aq nart of the 1n1;er-;sir-Thq*Ana PF299pam.~
r-.I The following valve actuations must be verified at least oncmpe on an actual or simulated recirculation actuation signal, the containment sump isolation valves open, and the HPSI, LPSI and CS minimum bypass recirculation flow line isolation valves and combined SI mini flow valve close.(continued)
PALO VERDE UNITS 1,2,3 B 3.5.3-9 REVISION 64 ECCS -Operating B 3.5.3 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.3.7 Realignment of valves in the flow path on an SIAS is necessary for proper ECCS performance.
The safety injection valves have stops to position them properly so that flow is restricted to a ruptured cold leg, ensuring that the other cold legs receive at least the re uir T4"&-These valves are also monitored in accordance with the requirements of 10 CFR 50.65 (Ref. 5).Insert 1 -SR 3.5.3.8 Periodic inspection of the containment sump ensures that it is unrestricted and stays 1i.n proper o '"'Sur-'-i!laine under the conditions that apply during an outage, on the need- te have c to the location, and onq the poeta for- unplanned transients; if: the Surweillance-were per-foredd w'it~h the r eactor at pow:er. Thi s Fr-equency i suficintto detec~t -abnorm-al d-egr-adation and is cofrmed by operating experience.
REFERENCES
- 1. 10 CFR 50, Appendix A, GDC 35.2. 10 CFR 50.46.3. UFSAR, Chapter 6.4. NRC Memorandum to V. Stello, Jr.,"Recommended Interim Revisions to Components," December 1, 1975.from R. L. Baer, LCOs for ECCS 5. 10 CFR 50.65.6. Combustion Engineering Owners Group Joint Applications Report for Low Pressure Safety Injection System AOT Extension, CE NPSD-995, dated May 1995, as submitted to NRC in APS letter no. 102-03392, dated June 13, 1995, with updates described in letter no. 102-04250 dated February 26, 1999. Also see TS amendment no. 124 dated February 1, 2000.7. ASME Code for Operation and Maintenance of Nuclear Power Plants.PALO VERDE UNITS 1,2,3 B 3.5.3-10 REVISION -54 RWT B 3.5.5 BASES ACTIONS B.1 With RWT borated water volume not within limits, it must be returned to within limits within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. In this condition, neither the ECCS nor Containment Spray System can perform their design functions:
therefore, prompt action must be taken to restore the tank to OPERABLE status or to place the unit in a MODE in which these systems are not required.
The allowed Completion Time of 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to restore the RWT to OPERABLE status is based on this condition since the contents of the tank are not available for injection and core cooling.C.1 and C.2 If the RWT cannot be restored to OPERABLE status 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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and to MODE 5 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. 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 3.5.5.1 REQUIREMENTS RWT borated water temperature shall be verified every 24 heiurg to be within the limits assumed in the accident anal s This Frcgucncy has been sheimn to he zuifflicict to The SR is modified by a Note that eliminates the requirement to perform this Surveillance when ambient air temperatures are within the operating temperature limits of the RWT. With ambient temperatures within this range, the RWT temperature should not exceed the limits.(continued)
PALO VERDE UNITS 1,2,3 B 3.5.5-8 REVISION 6-$
RWT B 3.5.5 BASES SURVEILLANCE REQUIREMENTS
[Insert 1 ---SR 3.5.5.2 The RWT water vo accordance with a sufficient ini and to support c-7 da , F. equency lume level shall be verified ever-y--7-dy&
in Figure 3.5.5-1. This Frequency ensures that tial water supply is available for injection ontinued ESF pump operation on Sinr-c thc RIAT vonumc 4. nor-mally stable and a I.... L.... Ar ^ in the Control Room, a S -.. I -I-is p.wppvpiat an:.J IIJ.., LJCCFI ~.IIJ~II LU LJC accctao? tnrougn eper-ating cxpcr-icncc.
g V g SR 3.5.5.3 Boron concentration of the RWT shall be verified every 7-days to be within the required range. This Frequency ensures that the reactor will remain subcritical following a LOCA and the boron precipitation in the core will not occur earlier than predicted.
Further, it ensures that the resulting sump pH will be maintained in an acceptable range such that the effect of chloride and caustic stress corrosion on mechanical systems and components will be minimiTedp, inee ¢ RIITI ,,lw,1 4s. ne- l stab I, a 7 day..........
is ... ... R÷,=~ ..hwn t-hpnngh I .....r ...Z. ..... ...... ..... .. .. ...hag Insert I ..1 ........ ex e ie e to be .. aee p hl e .REFERENCES
- 1. UFSAR, Chapter 6 and Chapter 15.2. Engineering Calculation 13-JC-CH-0209 PALO VERDE UNITS 1,2,3 B 3.5.5-9 REVISION -51 TSP B 3.5.6 BASES ACTIONS (continued)
B.1 and B.2 If the TSP cannot be restored within limits within the Completion Time of Required Action A.1, the plant must be brought to a MODE in which the LCO does not apply. The specified Completion Times for reaching MODES 3 and 4 are those used throughout the Technical Specifications:
they were chosen to allow reaching the specified conditions from full power in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.5.6.1 1 verification Periodic determination of the volume of TSP in containmey<
must be performed due to the possibility of leaking v; ;es and components in the containment building that couJ! cause dissolution of the TSP during normal operation.
A F-r-ene,-ef 1 4meonth is required to determine visually that a minimum of 524 cubic feet is contained in the TSP baskets (Ref. 1). This requirement ensures that there is an adequate volume of TSP to adjust the pH of the post LOCA sump solution to a value 7.0.The periodic .er-ificati"n is required every 18 months, sincc acpess toe is6 only feasiblc during outages,~nt1 nnrm~i run e-"nIr~ ~rn ~cflrt1uiIr'd mr IX mnnrfl'Opertin exerincehas, show tAýhis Swpveillanpp Frequency acceptabl, due, to he mrgin h i the velme of TSP plaed in SR 3.5.6.2 Testing ensures that the solubility and buffering ability of the TSP is not degraded after exposure to the containment environment.
A representative sample of 3.36 grams +/- 0.005 grams of anhydrous TSP (corrected for moisture content) is collected from one or more of the baskets in containment.
The sample is submerged in 1.0 +/- 0.005 liter (total volume)of 4280 to 4400 ppm boric acid solution at a temperature of 1351F +/- 91F. Without agitation, the solution pH should rise to greater than or equal to 7.0 within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. Solution pH is measured at 77 0 F +/- 9 0 F and rounded to the nearest tenth of a pH unit.(continued)
PALO VERDE UNITS 1,2,3 B 3.5.6-4 REVISION 2-4 TSP B 3.5.6 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.6.2 (continued)
The sample weight and volume correspond to the design minimum concentration of TSP expected post LOCA in the containment sump. The limiting concentration occurs when the LCO minimum TSP volume of 524 cubic feet, weighing about 25,325 pounds at the installed bulk density, is dissolved into the maximum recirculation fluid mass of approximately 7,690,750 pounds, which is about 920,000 gallons at room temperature.
The boron concentration of the test water is the highest possible with the maximum expected recirculation sump volume.Agitation of the test solution is prohibited since an adequate standard for the agitation intensity cannot be specified.
The test time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is necessary to allow time for the dissolved TSP to naturally diffuse through the sample solution.
In the post LOCA containment sump, rapid mixing would occur, significantly decreasing the actual amount of time before the required pH is achieved.
This ensures compliance with UFSAR Section 6.1.1.2 which requires containment sump pH to be greater than or equal to 7.0 and less than or equal to 8.5 within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after a Recirculation Actuation Signal (RAS).The temperature of 135 +/- 9 0 F was chosen for the borated water solution because that is the minimum temperature expected at the inlet of the shutdown cooling heat exchangers during the initial phase of this accident when the TSP is dissolved into solution.REFERENCES
- 1. PVNGS operating license amendment numbers 110, 102 and 82 for Units 1, 2 and 3, respectively, and associated NRC Safety Evaluation dated December 10, 1996.PALO VERDE UNITS 1,2,3 B 3.5.6-5 REVISION -W Containment Air Locks B 3.6.2 BASES SURVEILLANCE REQUIREMENTS SR 3.6.2.1 (continued)
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 which is applicable to SR 3.6.1.1. This ensures that air lock leakage is properly accounted for in determining the combined Type Band C containment leakage rate.SR 3.6.2.2 The air lock interlock is designed to prevent simultaneous opening of both doors in a single air lock. Since both the inner and outer doors of an air lock are designed to withstand the maximum expected post accident containment pressure, closure of either door will support containment OPERABILITY.
Thus, the door interlock feature supports containment OPERABILITY while the air lock is being used for personnel transit into and out of containment.
Periodic testing of this interlock demonstrates that the interlock will function as designed and that simultaneous opening of the inner and outer doors will not inadvertently occur. Due to the purely mechanical nature of this interlock, and given that the interlock mechanism is not normally challenged when containment is used for entry and exit (procedures require strict adherence to single door opening), this test is only undder the cond-itions that apply dur-ing a plant outage, anid the potential for- loss of containment OPERABILITY if the Suryeillance were per-for m e d w:i the reco ?tpoF. The 24 month Frequency forP the interlock is justified based on gener-ic-oper-ating exein. The Frequency is based on engieerng udgentandis considered adequate given that theQ inter-lock is not challenged during the use of the-REFERENCES
- 1. 10 CFR 50, Appendix J, Option B.2. UFSAR, Section 3.8.3. UFSAR, Section 6.2.4. UFSAR, Section 15.6 PALO VERDE UNITS 1,2,3 B 3.6.2-8 REVISION 4 Containment Isolation Valves B 3.6.3 BASES I42 inchI SURVEILLANCE SR 3.6.3.1 REQUIREMENTS Ea=h required-42 i .. timent pur-ge valv:e is required to-containment i/not caused by an inadvertent or spurious opening of a ontainment purge valve. Detailed analysis of the refueling purge valves failed to conclusively demonstrate their ability to close during a LOCA in time to limit offsite doses. Therefore, these valves are required to be in the sealed closed position during MODES 1, 2, 3, and 4. A required containment purge valve that is sealed closed must have motive power to the valve operator removed. This can be accomplished by de-energizing the source of electric power.In this application, the term "sealed" has no connotation of leak tight The ..egu.nc.y is a result. of an NRC tm,- F ,,, ,ee i is u ,,24 (Ref 4), r-l, e ..Insert I cture valve use dur.ing unit operation+.
This SR is not required to be met while in Condition D of this LCO.This is reasonable since the penetration flow path would be isolated.SR 3.6.3.2 This SR ensures that the power access purge valves are closed as required or, if open, open for an allowable reason. If a purge valve is open in violation of this SR, the valve is considered inoperable.
If the inoperable valve is not otherwise known to have excessive leakage when closed, it is not considered to have leakage outside of limits. The SR is not required to be met when the purge valves are open for pressure control, ALARA or air quality considerations for personnel entry, or for Surveillances that require the valves to be open. The power access purge valves are capable of closing in the environment following a LOCA. Therefore, these valves are allowed to be open for limited periods of tim The31 day Freuec is coitent :th other Insert 1IR2----3 (conti nued)PALO VERDE UNITS 1,2,3 B 3.6.3-16 REVISION 49 Containment Isolation Valves B 3.6.3 BASES SURVEILLANCE REQUIREMENTS (continued)
[Insert 1 -----'SR 3.6.3.3 This SR requires verification that each containment isolation manual valve and blind flange located outside 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 containment boundary is within design limits. This SR does not require any testing or valve manipulation.
Rather, it involves verification, through a system walkdown, that those containment isolation valves outside containment and capable of being mispositioned are in the correct nosii Sinc v..ifi.ation of valve position i'~ LU 1LAMeflt iso1atien valyesg outside cnaneti relatively easy,' th 31 Fe y engineering judgment and was c-hosnt povide addcd assur-ance of the correct position.
Containment isolation valves that are open under administrative controls are not required to meet the SR during the time the valves are open. 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.The Note applies to valves and blind flanges located in high radiation areas and allows these devices to be verified closed by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted during MODES 1, 2, 3, 4 and for ALARA reasons. Therefore, the probability of misalignment of these containment isolation valves, once they have been verified to be in the proper position, is small.SR 3.6.3.4 This SR requires verification that each containment isolation manual valve and blind flange located inside 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 containment boundary is within design limits. For containment isolation valves inside containment, the Frequency of "prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days" is appropriate, since these containment isolation valves are operated under (continued)
PALO VERDE UNITS 1,2,3 B 3.6.3-17 REVISION 2-7 Containment Isolation Valves B 3.6.3 BASES SURVEILLANCE SR 3.6.3.4 (continued)
REQU I REMENTS administrative controls and the probability of their misalignment is low. Containment isolation valves that are open under administrative controls are not required to meet the SR during the time that they are open. 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.The Note allows valves and blind flanges located in high radiation areas to be verified closed by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted during MODES 1, 2, 3 and 4 for ALARA reasons. Therefore, the probability of misalignment of these containment isolation valves, once they have been verified to be in their proper position, is small.SR 3.6.3.5 Verifying that the isolation time of each required automatic power operated containment isolation valve is within limits is required to demonstrate OPERABILITY.
The isolation time test ensures the valve will isolate in a time period less than or equal to that assumed in the safety analysis.
The isolation time and Frequency of this SR are in accordance with the Inservice Testing Program.SR 3.6.3.6 For required containment purge valves with resilient seals, additional leakage rate testing beyond the test requirements of 10 CFR 50, Appendix J, Option B (Ref. 5), is required to ensure OPERABILITY.
Industry operating experience has demonstrated that this type of seal has the potential to degrade in a shorter time period than do oth " t "c" Insert 1. ..,, ,. ., l i. ., 4- h l- J.L -h rU4- .....containment and- the environmcnt), a Frequency of 184 days wa-s isuB 20- "Containment Leakage Due to Se-al Deterior-ation" (continued)
PALO VERDE UNITS 1,2,3 B 3.6.3-18 REVISION 44 Containment Isolation Valves B 3.6.3 BASES SURVEILLANCE SR 3.6.3.6 (continued)
REQUIREMENTS Additionally, this SR must be performed within 92 days after opening the valve. The 92 day Frequency was chosen recognizing that cycling the valve could introduce additional seal degradation (beyond that occurring to a valve that has not been opened). Thus, decreasing the interval .(f-2emi-48 is a prudent measure after a valve has been opened.SR 3.6.3.7 Required automatic containment isolation valves close on a containment isolation signal to prevent leakage of radioactive material from containment following a DBA. This SR ensures each required automatic containment isolation valve will actuate to its isolation position on an actual or simulated actuation signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controg, ,s* The IS merthc ............
Wa ....epe GGA ....18 month Frequenccy.
Thcreorc th Fr...............
coclde to ~ ~ ~ b be-fre accptbl from~ a reiaiit tadoit REFERENCES
- 1. UFSAR Section 6.2.4.2. UFSAR, Section 6.2.6.3. Generic Issue B-20.4. Generic Issue B-24.5. 10 CFR 50, Appendix J. Option B.6. 10 CFR 50, Appendix A 7. CL Design Basis Manual 8. CRDR 106542 9. CRDR 2326591 PALO VERDE UNITS 1,2,3 B 3.6.3-19 REVISION 43 Containment Pressure B 3.6.4 BASES ACTIONS A.1 When containment pressure is not within the limits of the LCO, containment pressure must be restored to within these limits within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. The Required Action is necessary to return operation to within the bounds of the containment analysis.
The 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Completion Time is consistent with the ACTIONS of LCO 3.6.1, "Containment," which requires that containment be restored to OPERABLE status within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.B.1 and B.2 If containment pressure cannot be restored to within limits within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and to MODE 5 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. 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 3.6.4.1 REQUIREMENTS Verifying that containment pressure is within limits ensures that operation remains within the limits assumed in the accident analv .The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thi, SR was Insert experieneRP related to trending Of containment ppe~surze.-ariations during the applicable MODES. Furthermore, the 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Frunc- iz adequate in ew,, of other ind-atioens
.'ailabale in the contiro] room, including alar-ms, to aertthe epcrator to -an abnorma] con-tainmcnt prczzure REFERENCES
- 1. UFSAR, Section 6.2.1 2. UPSAR, Section 7.2 3. Calculation 13-JC-HC-201 PALO VERDE UNITS 1,2,3 B 3.6.4-3 REVISION -
Containment Air T emperature B 3.6.5 BASES (continued)
ACTIONS A.1 When containment average air temperature is not within the limit of the LCO, it must be restored to within limit within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />. This Required Action is necessary to return operation to within the bounds of the containment analysis.The 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Completion Time is acceptable considering the sensitivity of the analysis to variations in this parameter and provides sufficient time to correct minor problems.B.1 and B.2 If the containment average air temperature cannot be restored to within its 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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and to MODE 5 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. 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 REQUIREMENTS SR 3.6.5.1 Verifying that containment average air temperature is within the LCO limit ensures that containment operation remains within the limit assumed for the containment analyses.
In order to determine the containment average air temperature, an arithmetic average is calculated using measurements taken at locations within the containment selected to provide a representative sample of the overall containment at I insert Da~ea-n-crIo~zer~a zeo r Atczo temperature increaz (due to the large YAo1uMe of containment).
Fur-ther-more, the 21 hour-- Frequency is considcrcd adequate in A'e o ther i~nd4pAicaionAs Rv-a iaIl -ini thecntrol-room, i ncl1udi ng ala rms , toalrtthe opcr-ater-to ;n abhnor-ml containment temperature-(continued)
PALO VERDE UNITS 1,2,3 B 3.6.5-3 REVISION 49 Containment Spray System B 3.6.6 BASES ACTIONS B.1 and B2 (continued)
If the inoperable containment spray train cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and to MODE 4 with RCS pressure < 385 psia within 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br />. The allowed Completion Time of 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems. The extended interval to reach MODE 4 with RCS pressure < 385 psia allows additional time for the restoration of the containment spray train and is reasonable when considering that the driving force for a release of radioactive material from the Reactor Coolant System is reduced in MODE 3.C.1 With two containment spray trains inoperable, the unit is in a condition outside the accident analysis.
Therefore, LCO 3.0.3 must be entered immediately.
SURVEILLANCE SR 3.6.6.1 REQUIREMENTS Verifying the correct alignment for manual, power operated, and automatic valves in the containment spray flow path provides assurance that the proper flow paths will exist for Containment Spray System operation (positioned to take suction from the RWT on a containment spray actuation test signal [CSAS]). 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 being secured. This SR also 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 verifying, through a system walkdown, that those valves outside containment and capable of potentially being mispositioned are in the correct position.(insecit (continued)
PALO VERDE UNITS 1,2,3 B 3.6.6-6 REVISION 4 Containment Spray System B 3.6.6 BASES SURVEILLANCE SR 3.6.6.2 REQUIREMENTS (continued)
Verifying that the containment spray header piping is full of water to the 113 ft level minimizes the time required to fill the header. This ensures that spray flow will be admitted to the containment atmosphere within the time frame assumed in the containment analysis.
The analyses shows that the header may be filled with unborated water which helps to reduce boron plate out due " hajd .nd the lo. probability o a sigifian degradation of water- lcvcl in the piping occurpring between zur'cillanccz.
The value of 113 ft is an indicated value which accounts for instrument uncertainty.
SR 3.6.6.3 Verifying that each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head ensures that spray pump performance has not degraded during the cycle. Flow and differential pressure are normal tests of centrifugal pump performance required by the ASME OM Code (Ref. 6). Since the containment spray pumps cannot be tested with flow through the spray headers, they are tested on recirculation flow (either full flow or miniflow as conditions permit). This test is indicative of overall performance.
Such inservice inspections confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance.
The Frequency of this SR is in accordance with the Inservice Testing Program.(continued)
PALO VERDE UNITS 1,2,3 B 3.6.6-7 REVISION 54 Containment Spray System B 3.6.6 BASES SURVEILLANCE REQUIREMENTS
[Insert 1 ]---SR 3.6.6.4 and SR 3.6.6.5 (continued)
These SRs verify that each automatic containment spray valve actuates to its correct position and that each containment spray pump starts upon receipt of an actual or simulated safety injection actuation signal, recirculation actuation signal and containment spray actuation signal as applicable.
This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative contr The-4T meRth--dý @, ... .h." t...ese 4-ce under he condition tht ply during a plant ouad the ptnt A or- a nplanned tr.an.sient if the Su~I IanIC-(~:r perforrmed-wi th the rc-ac-tor at poe.Operating exeineh-as show:n th-at these componentS usua!lY pasthe Surveillances-when per-fore-Pd at the 18 month-u uu Mu vwu~ u eRG I vu Wuu S GA Wi hPia wu Iacccptable frmarlaiiystandpoint.
The surveillance of containment sump isolation valves is also required by SR 3.5.3.5. A single surveillance may be used to satisfy both requirements.
SR 3.6.6.6 Unobstructed flow headers and nozzles are determined by either flow testing or visual inspection.
With the containment spray inlet valves closed and the spray header drained of any solution, low pressure air or smoke can be blown through test connections.
Performance of this SR demonstrates that each spray nozzle is unobstructed and provides assurance that spray coverage of the containment during an accident is not deg ue to the passive (conti nued)PALO VERDE UNITS 1,2,3 B 3.6.6-8 REVISION 49 ADVs B 3.7.4 BASES ACTIONS C.1 and C.2 If the ADV lines cannot be restored to OPERABLE status within the associated Completion Time, 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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, and in MODE 4, without reliance on the steam generator for heat removal, within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. 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 REQUIREMENTS
[Insert1 SR 3.7.4.1 To perform a controlled cooldown of the RCS, the ADVs must be able to be opened and throttled through their full range.This SR ensures the ADVs are tested through a full control cycle at least once per fuel cycle. Performance of inservice testing or use of an ADV during a unit cooldown may satisfy this reqjrew n ...-,, cxpcri .... hz Csbw +at't-h iiOMPOPntz Usually pass thc- SR 1APhcn p r-~FFL formedu J abI bi- *8 MORtHr rucqucilcY.
i repefere, LiIe quencby iz dbbeprba-e 0 fdrom a !remElabilit:y btan1mrdpoint REFERENCES
- 1. UFSAR, Section 10.3.PALO VERDE UNITS 1,2,3 B 3.7.4-5 REVISION 9g AFW System B 3.7.5 BASES ACTIONS E.1 (continued)
Required Action E.1 is modified by a Note indicating that all required MODE changes or power reductions are suspended until one AFW train is restored to OPERABLE status.Completion Times are also suspended at the time the Condition is entered. The Completion Time is resumed with the time remaining when the Condition was entered upon restoration of one AFW train to OPERABLE status.With one AFW train inoperable, action must be taken to immediately restore the inoperable train to OPERABLE status or to immediately verify, by administrative means, the OPERABILITY of a second train. LCO 3.0.3 is not applicable, as it could force the unit into a less safe condition.
In MODE 4, either the reactor coolant pumps or the SDC loops can be used to provide forced circulation as discussed in LCO 3.4.6, "RCS Loops -MODE 4." SURVEILLANCE SR 3.7.5.1 REQUIREMENTS Verifying the correct alignment for manual, power operated, and automatic valves in the AFW water and steam supply flow paths provides assurance that the proper flow paths exist for AFW 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.
This SR also does not apply to valves that cannot be inadvertently misaligned, such as check valves. This Surveillance does not require any testing or valve manipulations:
rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position.The 31 day Frequcnczy is based on engineering judgment, is conistntwith the procedural controls goenn a9 Verifying that each AFW pump's developed head at the flow test point is greater than or equal to the required developed head ensures that AFW pump performance has not degraded during the cycle. Flow and differential head are (continued)
PALO VERDE UNITS 1,2,3 B 3.7.5-8 REVISION .
AFW System B 3.7.5 BASES SURVEILLANCE REQUIREMENTS SR 3.7.5.2 (continued) normal tests of pump performance required by the ASME OM Code (Ref. 2). Because it is undesirable to introduce cold AFW into the steam generators while they are operating, this testing may be performed on recirculation flow. This test confirms one point on the pump design curve and can be indicative of overall performance.
Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance.
Performance of inservice testing, discussed in the ASME OM Code, (Ref. 2), at 3 month intervals satisfies this requirement.
This SR is modified by a Note indicating that the SR should be deferred until suitable test conditions are established.
Normal operating pressure is established in the steam generators when RCS temperature reaches 532 0 F, this corresponds to a Psat of 900 psia. This deferral is required because there is an insufficient steam pressure to perform the test.SR 3.7.5.3 This SR ensures that AFW can be delivered to the appropriate steam generator, in the event of any accident or transient that generates an AFAS signal, by demonstrating that each automatic valve in the flow path actuates to its correct position on an actual or simulated actuation signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.
This SR is not required for the non-essential train since there are no automatic valves which receivt at The 18 month Frequency is basPd OR bhAsed- on th esg eliability and opcr-ating exper-ience of te equpment.This SR is modified by a Note indicating that the SR should be deferred until suitable test conditions have been established.
Normal operating pressure is established in the steam generators when RCS temperature reaches 532 0 F, this corresponds to a Psat of 900 psia. This deferral is required because there is an insufficient steam pressure to perform the test.(continued)
PALO VERDE UNITS 1,2,3 B 3.7.5-9 REVISION -54 AFW System B 3.7.5 BASES SURVEILLANCE SR 3.7.5.3 (continued)
REQUIREMENTS Also, this SR is modified by a Note that states the SR is not required in MODE 4. In MODE 4, the required AFW train is already aligned and operating.
SR 3.7.5.4 This SR ensures that the essential AFW pumps will start in the event of any accident or transient that generates an AFAS signal by demonstrating that each essential AFW pump starts automatically on an actual or simulated actuation siThe 18- month Frequenczy is based An the need to trnen d if the Suiteil tan e coned i ith the resetre at pNorm. The 18 mngth Frequeney is aeceptable, based onp the designeliability and opcrating experience of the equi4pment.
The non-essential AFW pump does not automatically activate and is not subject to this SR.This SR is modified by two Notes. Note 1 indicates that the SR be deferred until suitable test conditions are established.
Normal operating pressure is established in the steam generators when RCS temperature reaches 532 0 F, this corresponds to a P~,, of 900 psia. This deferral is required because there is insufficient steam pressure to perform the test. Note 2 states that the SR is not required in MODE 4. In MODE 4, the required pump is already operating and the autostart function is not required.SR 3.7.5.5 This SR ensures that the AFW System is properly aligned by verifying the flow path from each essential AFW pump to each steam generator prior to entering MODE 2 operation, after 30 days in MODE 5 or 6. OPERABILITY of essential AFW flow paths must be verified before sufficient core heat is generated that would require the operation of the AFW System during a subsequent shutdown.
The Frequency is reasonable, based on engineering judgment, and administrative controls to ensure that flow paths remain OPERABLE.(continued)
PALO VERDE UNITS 1,2,3 B 3.7.5-10 REVISION 4 CST B 3.7.6 BASES ACTIONS (continued)
B.l and B.2 If the CST cannot be restored to OPERABLE status within the associated Completion Time, 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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, and in MODE 4, without reliance on steam generator for heat removal, within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. 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 REQUIREMENTS SR 3.7.6.1 This SR verifies that the CST contains the required volume of cooling water. (This level ! 29.5 ft (300.000 galltonsýS iInsert 1"" affect the rCT kinentory between c.he.ks The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> F u ncis cnusidercd adequate in vien W onf o nther u indic-ationAs in. the control room, including alar-m, to alert the operator to abnorm-al CSTU levealdeito.
REFERENCES
- 1. UFSAR, Section 9.2.6.2. UFSAR, Chapter 6.3. UFSAR, Chapter 15.4. NRC Standard Review Plan Branch Technical Position (BTP) RSB 5-1.PALO VERDE UNITS 1,2,3 B 3.7.6-4 REVISION 64 EW System B 3.7.7 BASES B.1 and B.2 (continued)
The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.SURVEILLANCE SR 3.7.7.1 REQUIREMENTS Verifying the correct alignment for manual, power operated, and automatic valves in the EW flow path provides assurance that the proper flow paths exist for EW 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.
This SR also does not apply to valves that cannot be inadvertently misaligned, such as check valves. This Surveillance does not require any testing or valve manipulation:
rather, it involves verification that those valves capable of potentially being mispositioned are in their correct position.This SR is modified by a Note indicating that the isolation of the EW components or systems renders those components or systems inoperable but does not necessarily affect the OPERABILITY of the EW System. Isolation of the EW System to the Essential Chiller, while rendering the Essential Chiller inoperable, is acceptable and does not impact the OPERABILITY of the EW System. Isolation of the EW System to the SDC system heat exchanger is not acceptable and would render both the EW System and the SDC system inoperable (Ref. 3). The EW System is inoperable in this situation because it is operating outside of the acceptable limits of the system.The 31 day Frequency is based on engineering judgment, is cons-i-stent with the procedural controls go~enn PaVe] -ne -SR 3.7.7.2 This SR verifies proper automatic operation of the EW valves on an actual or simulated actuation signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under (continued)
PALO VERDE UNITS 1,2,3 B 3.7.7-4 REVISION -
EW System B 3.7.7 BASES SURVEILLANCE REQUIREMENTS IInsert I [-SR 3.7.7.2 (continued) administrative control-,> .peratingq
.xpcri.n. e has -shown th't u~ua1v -thp Surveill.,nce whr:n pcrfo....-at the 18 month Frequency. .Thccforce, the Frequenc iz acccpt-ablc from -R reli-ability standpoit SR 3.7.7.3 This SR verifies proper automatic operation of the EW on an actual or simulated actuation si -pera itng v,.pumps ilnsert '1 ]- u-e Therefore, thc Frequency is EGcceptabc from a rc.liability REFERENCES
- 1. UFSAR, Section 9.2.2.2. UFSAR, Section 9.2.1.3. CRDR 980794 PALO VERDE UNITS 1,2,3 B 3.7.7-5 REVISION -
ESPS B 3.7.8 BASES SURVEILLANCE SR 3.7.8.1 (continued)
REQUIREMENTS Surveillance 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 is modified by a Note indicating that the isolation of the ESPS components or systems renders those components or systems inoperable but does not necessarily affect the OPERABILITY of the ESPS. Isolation of the ESPS to the Diesel Generator (DG) cooler(s), while rendering the DG inoperable, is acceptable and does not impact the OPERABILITY of the ESPS. Isolation of the ESPS to the essential cooling water heat exchanger is not acceptable and would render both the Essential Cooling Water System and the ESPS inoperable (Ref. 3). The ESPS is inoperable in this situation because it is operating outside of the acceptable limits of the system.The 31 day Frequenc-y is based on engineering judgment, i4 cositetwith the proccdural controls 9ocnn .a PVc S',R 31.77.8.2 The SR verifies proper automatic operation of the ESPS pumps 1on an a.ctual or simulated act " " .ip SInsert S1rvei!!ane
,-a 'e n rfermed at the 18 month Frequency, Thrfrthe Frequency is a~cceptable fro-m -a re-li-ability REFERENCES
- 1. UFSAR, Section 9.2.1.2. UFSAR, Section 5.4.7.3. CRDR 980795 PALO VERDE UNITS 1,2,3 B 3.7.8-4 REVISION -
UHS B 3.7.9 BASES SURVEILLANCE REQUIREMENTS SR 3.7.9.1 This SR verifies adequate long term (26 days) cooling can be maintained with no makeup. The level specified also ensures sufficient NPSH is available for operatin th iInsert t~hetr-en"idig efth ar-am~e-t~e-r ariations during.....t I thWe Oppliai OE.Ti SR Ycrifies th-at thcesal (that -:h4c 'I n bc dcpctcd -atcr lc'.'cl of cach ESP is >12ft. A usable water depth of 12 feet requires 13'-6" of actual water depth. The implementing procedure requires the operator to verify that the level is greater than or equal to 13'-6" measured locally at the spray pond or 14'indicated in the control room using installed instrumentation.
The difference is a result of instrument uncertainty.
SR 3.7.9.2 This SR verifies that the ESPS is available to cool the EW System to at least its maximum design temperature within the maximum accident or normal design heat loads for 26 days The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Fec.ucncy is based on S...X.p. ...ie.e .rc....tcd to the trcn.di.ng of the insert p1r.ee .ariatin during the applicable MOnEs. Thi.-s SA yprzifics that. the UHS w:ater- temperatur-e is 89 0 F, asr-indcatd i th cotro rom.This Value includ-e-s allow':ance for u.-ncertai nti es.REFERENCES
- 1. UFSAR, Section 9.2.5.2. Regulatory Guide 1.27.PALO VERDE UNITS 1,2,3 B 3.7.9-3 REVISION 44 EC System B 3.7.10 BASES SURVEILLANCE SR 3.7.10.1 (continued)
REQUIREMENTS The isolation of the EC System from other components or systems renders those components or systems inoperable, but does not necessarily affect the OPERABILITY of the EC System. Isolation of the EC System to any single EC supplied cooling coil, while rendering the cooling coil inoperable, is acceptable and does not impact the OPERABILITY of the EC System. Isolation of the EC System to any additional cooling coil is not acceptable without an engineering evaluation and an operability determination for that configuration (Ref. 2). The EC System is inoperable in this situation, unless it has been specifically evaluated, because it is operating outside of the acceptable limits of the system.The 31 day Frcgucnc-y is based on enginccring judgment, is con-si-stenAt with the procc~dural controls goerin4vle This SR verifies proper automatic operation of the EC System components and that the EC pumps will start in the event of any accident or transient that generates an applicable ESFAS signal. This SR also ensures that each automatic valve in the flow paths actuates to its correct position on an actual or simulated ESFAS signal.The 18 month Fre..u.ny is based on the Reed to perform this Survillncundr-the coAndition tt pply dur-ing a unit outae ad te ptenialfor -an unplanned tr-an-sient if the Sur.elln...e were performed
,.th th .e.to at power. The 18 month Frqunc ibseonprang experi;enc-e and REFERENCES
- 1. UFSAR, Section 9.2.9.2. CRDR 980796 PALO VERDE UNITS 1,2,3 B 3.7.10-4 REVISION -
CREFS B 3.7.11 BASES ACTIONS E.1 and E.2 (continued)
An alternative to Required Action E.1 is to immediately suspend activities that could result in a release of radioactivity that might require isolation of the CRE. This places the unit in a condition that minimizes the accident risk. This does not preclude the movement of fuel to a safe position.F.1 and F.2 If two CREFS trains become inoperable for reasons other than an inoperable CRE boundary or one or more CREFS trains become inoperable due to an inoperable CRE boundary, during Mode 5 or 6, or during the movement of irradiated fuel assemblies, immediate action must be taken to suspend activities that could release radioactivity that might enter the CRE. The Required Actions place the unit in a condition that minimizes accident risk. These actions do not preclude movement of fuel assemblies to safe positions.
G.1 If both CREFS trains are inoperable in MODE 1, 2, 3, or 4 for reasons other than an inoperable CRE boundary (i.e., Condition B), the CREFS may not be capable of performing the intended function and the unit is in a condition outside the accident analyses.
Therefore, LCO 3.0.3 must be entered immediately.
SURVEILLANCE SR 3.7.11.1 REQUIREMENTS Standby systems should be checked periodically to ensure that they function properly.
Since the environment and normal operating conditions on this system are not severe, testing each train once every month provides an adequate check on this system.Monthly operations for 15 minutes to demonstrate the function of the system d ) "[Insert 1vi- Z-- (conti nued)PALO VERDE UNITS 1,2,3 B 3.7.11-7 REVISION 94 CREFS B 3.7.11 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.7.11.2 This SR verifies that the required CREFS testing is performed in accordance with the Ventilation Filter Testing Program (VFTP). The CREFS filter tests are in accordance with Regulatory Guide 1.52 (Ref. 5). The VFTP includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations).
Specific test Frequencies and additional information are discussed in detail in the VFTP.SR 3.7.11.3 This SR verifies that each CREFS train starts and operates on an actual or simulated actuation signal. This includes verification that the system is automatically placed into a filtration mode of operation with flow through the HEPA filters and charcoal adsorber b.... Frequency of In s e r t 1 m"- --............ ....f u l ..SR 3.7.11.4 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.The CRE is considered habitable when the radiological dose of CRE occupants calculated in the licensing basis analyses of DBA consequences is no more than 5 rem whole body or its equivalent to any part of the body and the CRE occupants are protected from hazardous chemicals and smoke. This SR verifies that the unfiltered air inleakage into the CRE is no greater than the flow rate assumed in the licensing basis analyses of DBA consequences.
When unfiltered air inleakage is greater than the assumed flow rate, Condition B must be entered. Required Action B.3 allows time to restore the CRE boundary to OPERABLE status provided mitigating actions can ensure that the CRE remains within the licensing basis habitability limits for the occupants following an accident.Compensatory measures are discussed in Regulatory Guide 1.196, Section C.2.7.3, (Ref 6) which endorses, with exceptions, NEI 99-03, Section 8.4 and Appendix F (Ref. 7).(continued)
PALO VERDE UNITS 1,2,3 B 3.7.11-8 REVISION 6 CREATCS B 3.7.12 BASES (continued)
ACTIONS F.1 (continued)
If both CREATCS trains are inoperable in MODE 1, 2, 3, or 4, the CREATCS may not be capable of performing the intended function and the unit is in a condition outside the accident analysis.
Therefore, LCO 3.0.3 must be entered immediately SURVEILLANCE REQUIREMENTS SR 3.7.12.1 This SR verifies that the heat removal capability of the system is sufficient to meet design requirements.
This SR consists of a combination of testing and calc.Latins->
A"-[Insert 1j ------rl --era'da-' Z o --h RDIAT"S -le. and .is t -vp-@Gtd or this time period.REFERENCES
- 1. UFSAR, Section 9.4.PALO VERDE UNITS 1,2,3 B 3.7.12-4 REVISION 4 ESF PREACS B 3.7.13 BASES SURVEILLANCE SR 3.7.13.1 REQUIREMENTS Standby systems should be checked periodically to ensure that they function properly.
Since the environment and normal operating conditions on this system are not severe, testing each train once a month provides an adequate check on this system.Monthly operations for 15 minutes demonstrates the function of the system. There is not expected to be any moisture buildup on the adsorbers and HEPA filters due to the low humidity at PVNGS (Ref The 31 dy -Frequency is trai redudn y %he andthet, SR 3.7.13.2 This SR verifies that the required ESF PREACS testing is performed in accordance with the Ventilation Filter Testing Program (VFTP). The ECCS PREACS filter tests are in accordance with Regulatory Guide 1.52 (Ref. 4). The VFTP includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations).
Specific test frequencies and additional information are discussed in detail in the VFTP.SR 3.7.13.3 This SR verifies that each ESF PREACS train starts and operates on an actual or simulated actua .Tile SR 3.7.13.4 This SR verifies the integrity of the ESF envelope.
The ability of the ESF envelope to maintain a negative pressure, with respect to potentially uncontaminated adjacent areas, is periodically tested to verify proper function of the ESF PREACS. During the post accident mode of operation, the ESF PREACS is designed to maintain a slight negative pressure in the ESF envelope with respect to adjacent areas to prevent unfiltered LEAKAGE. For the purposes of testing, the term (continued)
PALO VERDE UNITS 1,2,3 B 3.7.13-4 REVISION 4 ESF PREACS B 3.7.13 BASES SURVEILLANCE REQUIREMENTS SR 3.7.13.4 (continued)
'measurable negative pressure" is defined as 10 times the minimum instrument reading. The ESF PREACS is designed to maintain this negative pressure at a flow rate of 6,000 cfm +/- 10% from the ESF env. Th Frequency of insert 1O S~t T WtF l th LI FI u i Uztr pr~pevde 4I theIiLI on~~~~ I.. Rf )This test is conducrted with the tests, foAr fiter penetr nion thus, an 18 month Frequency, on a STAGGERED TF:ST RASIS i" r'nng Zia.cnt wit 4thar filtr.atian Qc;REFERENCES
- 1. UFSAR, Section 6.5.1.2. UFSAR, Section 9.4.2.3. UFSAR, Section 15.6.5.4. Regulatory Guide 1.52 (Rev. 2).5. 10 CFR 100.11.6. NUREG-0800, Section 6.5.1, Rev. 2, July 1981.7. UFSAR, Section 1.8 PALO VERDE UNITS 1,2,3 B 3.7.13-5 REVISION 4 Fuel Storage Pool Water Level B 3.7.14 BASES SURVEILLANCE SR 3.7.14.1 REQUIREMENTS This SR verifies sufficient fuel storage pool water is available in the event of a fuel handling accident.
The water level in the fuel storage pool must be checked periodica
'The 7 day F... u.... ... -.ppep.i.t.
- b. us.acccptable, based @A eperating exer en.During refueling operations, the pool is at equilibrium with that the level in the refueling canal accordance with LCO 3.9.6, "RefuE Assemblies".
level in the fuel storage of the refueling canal, and is checked daily inýling Water Level-Fuel REFERENCES
- 1. UFSAR, Section 9.1.2.2. UFSAR, Section 9.1.3.3. UFSAR, Section 15.7.4.4. Regulatory Guide 1.25 5. 10 FR 100.11.PALO VERDE UNITS 1,2,3 B 3.7.14-3 REVISION 24 Fuel Storage Pool Boron Concentration B 3.7.15 BASES ACTIONS A.1 and A.2 The Required Actions are modified by a Note indicating that LCO 3.0.3 does not apply.When the concentration of boron in the spent fuel pool is less than required, immediate action must be taken to preclude an accident from happening or to mitigate the consequences of an accident in progress.
This is most efficiently achieved by immediately suspending the movement of fuel assemblies.
This does not preclude the movement of fuel assemblies to a safe position.
In addition, action must be immediately initiated to restore boron concentration to within limit.If moving fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not specify any action. If moving fuel assemblies while in MODE 1, 2, 3, or 4, the fuel movement is independent of reactor operation.
Therefore, inability to suspend movement of fuel assemblies is not sufficient reason to require a reactor shutdown.SURVEILLANCE REQUIREMENTS SR 3.7.15.1 This SR verifies that the concentration of boron in the spent fuel pool is within the required limit. As long as this SR is met, the analyzed incidents are full, a insert .A wat-r- i1- ..t.d to take plac, ever a ho pf time REFERENCES
- 1. UFSAR, Section 9.1.2.2. PVNGS Operating License Amendments 82, 69 and 54 for Units 1, 2 and 3, respectively, and associated NRC Safety Evaluation dated September 30, 1994.3. 13-N-001-1900-1221-1, "Palo Verde Spent Fuel Pool Criticality Analysis," ABB calculation A-PV-FE-0106, revision 3, dated January 15, 1999.PALO VERDE UNITS 1,2,3 B 3.7.15-2 REVISION Secondary Speci fi c Acti vi ty B 3.7.16 BASES APPLICABILITY In MODES 1, 2, 3, and 4, the limits on secondary specific activity apply due to the potential for secondary steam releases to the atmosphere.
In MODES 5 and 6, the steam generators are not being used for heat removal. Both the RCS and steam generators are depressurized, and primary to secondary LEAKAGE is minimal.Therefore, monitoring of secondary specific activity is not required.ACTIONS A.1 and A.2 DOSE EQUIVALENT 1-131 exceeding the allowable value in the secondary coolant, is an indication of a problem in the RCS, and contributes to increased post accident doses. If secondary specific activity cannot be restored to within limits in the associated Completion Time, 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 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, and in MODE 5 within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. 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 REQUIREMENTS SR 3.7.16.1 This SR ensures that the secondary specific activity is within the limits of the accident analysis.
A gamma isotope analysis of the secondary coolant, which determines DOSE EQUIVALENT 1-131, confirms the validity of the safety analysis assumptions as to the source terms in post accident releases.
It also serves to identify and trend any unusual isotopic concentrations that might indicate changes in rator cooln to aivity or cLz :1 th, CeOnlimit j5bsdonr-5 neesw ted f theneve (continued)
REVISION 4 PALO VERDE UNITS 1,2,3 B 3.7.16-3 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
The required steady state frequency range for the DG is 60 +0.7/-0.3 Hz to be consistent with the safety analysis to provide adequate safety injection flow. In accordance with the guidance provided in Regulatory Guide 1.9 (Ref. 3), where steady state conditions do not exist (i.e., transients), the frequency range should be restored to within +/- 2% of the 60 Hz nominal frequency (58.8 Hz to 61.2 Hz) and the voltage range should be restored to within +/- 10%of the 4160 volts nominal voltage (3740 volts to 4580 volts). The timed start is satisfied when the DG achieves at least 3740 volts and 58.8 Hz. At these values, the DG output breaker permissives are satisfied, and on detection of bus undervoltage or loss of power, the DG breakers would close, reenergizing its respective ESF bus.Steady state and transient voltage and frequency limits have not been adjusted for instrument accuracy.
Error values for specific instruments are established by plant staff to derive the indicated values for the steady state and transient voltage and frequency limits.Specific MODE restraints have been footnoted where applicable to each 18 month SR. The reason for "This Surveillance shall not be performed in MODE 1 or 2" is that during operation with the reactor critical, performance of this SR could cause perturbations to the EDS that could challenge continued steady state operation and, as a result, unit safety systems; or that performing the SR would remove a required DG from service. The reason for "This Surveillance shall not be performed in MODE 1, 2, 3, or 4" is that performing this SR would remove a required offsite circuit from service, perturb the EDS, and challenge safety systems.SR 3.8.1.1 This SR assures proper circuit continuity for the offsite AC electrical power supply to the onsite distribution network and indicated 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.appropriaeidpnec f offsi. te circuits is m.. aiec.insert W4" "t-e .-"' oper.. o. being aware of it ndbcueits tatu is displayed 4n the control r eom (conti nued)PALO VERDE UNITS 1,2,3 B 3.8.1-23 REVISION -W AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.2 and SR 3.8.1.7 (continued)
REQUIREMENTS SR 3.8.1.7 requires that, at a 184 day Frc......., the DG starts from standby conditions with the engine at normal keep-warm conditions and achieves required voltage and frequency within 10 seconds, and subsequently achieves steady state required voltage and frequency ranges. The 10 second start requirement supports the assumptions of the design basis LOCA analysis in the FSAR, Chapter 15 (Ref. 5).A minimum voltage and frequency is specified rather than an upper and a lower limit because a diesel engine acceleration at full fuel (such as during a fast start) is likely to"overshoot" the upper limit initially and then go through several oscillations prior to a voltage and frequency within the stated upper and lower bounds. The time to reach"steady state" could exceed 10 seconds, and be cause to fail the SR. However, on an actual emergency start, the EDG would reach minimum voltage and frequency in 10 seconds at which time it would be loaded. Application of the load will dampen the oscillations.
Therefore, only specifying the minimum voltage and frequency (at which the EDG can accept load) demonstrates the necessary capability of the EDG to satisfy safety requirements without including a potential for failing the Surveillance.
Error values for specific instruments are established to derive indicated values in test procedures.
While reaching minimum voltage and frequency (at which the DG can accept load) in 10 seconds is an immediate test of OPERABILITY, the ability of the governor and voltage regulator to achieve steady state operation, and the time to do so are important indicators of continued OPERABILITY.
Therefore, the time to achieve steady state voltage and frequency will be monitored as a function of continued OPERABILITY.
The 10 second start requirement is not applicable to SR 3.8.1.2 (see Note 3) when a modified start procedure as described above is used. If a modified start is not used, 10 second start requirement of SR 3.8.1.7 applies. The existing design for a CSAS actuation signal does not provide an emergency mode start to the DG. A CSAS actuation signal cannot occur until after a SIAS actuation signal has already been generated.(continued)
PALO VERDE UNITS 1,2,3 B 3.8.1-25 REVISION 94 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.2 and SR 3.8.1.7 (continued)
REQUIREMENTS Since SR 3.8.1.7 requires a 10 second start, it is more restrictive than SR 3.8.1.2, and it may be performed in lieu of SR 3.8.1.2. This is the intent of Note 1 of SR 3.8.1.2.The noprma] 31 day FrcquencY for SR 3 R
- I812 is consistPnt with Regulatoy Guide. 19 (Rcf. 3). The 181 day F.pqleGuy for SR 3.8.1.7 is; a ruin3ld testing consistent w:ih Genepric Lettcr- 81-15 (Ref. 7). Thesc Fr-equcnciWs provi e cquate assur-ance of OG PER1BLIY w:hile This Surveillance verifies that the DGs are capable of synchronizing with the offsite electrical system and accepting loads of 90 to 100 percent (4950 -5500 kW) of the continuous rating of the DG. Consistent with the guidance provided in the Regulatory Guide 1.9 (Ref. 3) load-run test description, the 4950 -5500 kW band will demonstrate 90 to 100 percent of the continuous rating of the DG. The load band (4950 -5500 kW) is meant as guidance to avoid routine overloading of the engine. Loads in excess of this band for special testing may be performed within the guidance of the generator capability curve.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.The normal 31 day Frequency for this Sui-rveillan-e is Insert 1 J This SR is modified by four Notes. Note 1 indicates 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 states that momentary transients because of changing bus loads do not invalidate this test. Note 3 indicates that this Surveillance should be conducted on only one DG at a time in order to avoid common cause failures that might result from offsite circuit or grid perturbations.
Note 4 stipulates a prerequisite requirement for performance of this SR. A successful DG start must precede this test to credit satisfactory performance.(continued)
PALO VERDE UNITS 1,2,3 B 3.8.1-26 REVISION -W AC Sources -Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.1.4 This SR verifies that there is enough usable fuel oil in the DG Day Tank to run the diesel generator at full load for a minimum of 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> plus 10%. The surveillance is on fuel level since there is no direct indicator of volume. Level is read in feet on the Main Control Board indicators or in equivalent units on local DG instrumentation.
The source for the run-time requirement is the UFSAR Sec. 1.8 and Question 9A.9 commitment to ANSI N195-1976.
That standard refers to the level at which fuel is automatically added to the tank. For the DG Day Tanks the "pump start" level is above the SR and so is additionally conservative.
The 31 day Frequency iS adequate to assure that a suffic-ient supply of fuel o-il is availablie, since low level -alarm; arp provided and unit opcrators wouwld bhe _awarc of any large uss 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. Removal of water from the fuel oil day 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, ground water, 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. sy,. The Surveill IanceFeqecs ar e establis6hed by I se r G u d 1. 7 3D Q ý T h i .s D i ,, InsentenIaF e The presence of water does not necessarily represent failure of this SR provided the accumulated water is removed during the performance of this Surveillance.(conti nued)PALO VERDE UNITS 1,2,3 B 3.8.1-27 REVISION -54 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS SR 3.8.1.6 This Surveillance demonstrates that each required fuel oil transfer pump operates and transfers fuel oil from its associated storage tank to its associated day tank. This is required to support 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.Since the design Of the fal tr.fer. SY.Stem i9 ..uc.h that pumps will operate automatically in order to maintain an adequate ,v. :oum -of fuel. -o I in i" the day tank duin or--In et1SR 3.8.1.7 See SR 3.8.1.2.SR 3.8.1.8 I Insert 'I Transfer of each 4.16 kV ESF bus power supply from the normal offsite circuit to the alternate offsite circuit demonstrates the OPERABILITY of the alternate circuit distribution network tha.et, during operto-ion with r-ato the uncorcitic-alprforance required to perform the Surbillante, and- is intendcd to be condistetwith expecytedm t uel chYle lengths. opieating aexperie hasi sona that thsreset compents usually pasts the SR wh perfo rmed at the 1r month prfouencgy.
Therefore,ihe Frequenc was cnudaed to alefrom -a reliabllity This SR is modified by a Note. The reason for the Note is that during operation with the reactor critical, performance of this SR could cause perturbations to the electrical distribution systems that could challenge continued steady state operation and, as a result, unit 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 reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated (continued)
PALO VERDE UNITS 1,2,3 B 3.8.1-28 REVISION A4-AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.9 (continued)
REQUIREMENTS The time, voltage, and frequency tolerances specified in this SR are derived from Regulatory Guide 1.9 (Ref. 3)recommendations for response during load sequence intervals.
The 3 seconds specified is equal to 60% of a typical 5 second load sequence interval associated with sequencing of the largest load. The voltage and frequency specified are consistent with the design range of the equipment powered by the DG. SR 3.8.1.9.a corresponds to the maximum frequency excursion, while SR 3.8.1.9.b and SR 3.8.1.9.c are the voltage and frequency values the system must meet, within three seconds, following load rejection.
Error values for specific instruments are established to derive indicated values in test roc The 18 month Frequency i-;riesitst;
.... Fe nd-tien ef Reo'ulater-y Guide ilnsert 1 This SR is modified by a Note. The reason for the Note is that performing this SR would remove a required offsite circuit from service, perturb the EDS, and challenge safety systems. This SR is performed in emergency mode (not paralleled to the grid) ensuring that the DG is tested under load conditions that are as close to design basis conditions as possible.
This restriction from normally performing the surveillance in Mode 1, 2, 3, or 4 is further amplified to allow the surveillance to be performed for the purpose of reestablishing 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 that 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 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 a plant shutdown and startup to determine that plant safety is maintained or enhanced when the surveillance is performed in MODE 1, 2, 3, or 4. Risk insights or deterministic methods may be used for this assessment.(continued)
PALO VERDE UNITS 1,2,3 B 3.8. 1-30 REVISION 64 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.10 (continued)
REQUIREMENTS In order to ensure that the DG is tested under load conditions that are as close to design basis conditions as possible, testing is performed using design basis kW loading and maximum kVAR loading permitted during testing. These loads represent the inductive loading that the DG would experience to the extent practicable and is consistent with the guidance of Regulatory Guide 1.9 (Ref. 3). Consistent with the guidance provided in the Regulatory Guide 1.9 full-load rejection test description, the 4950 -5500 kW band will demonstrate the DG's capability to reject a load equal to 90 to 100 percent of its continuous rating. Error values for specific instruments are established to derive indicated values in test procedures.
Administrative limits have been placed upon the Class 1E 4160 V buses due to high voltage concerns.
As a result power factors deviating much from unity are currently not possible when the DG runs parallel to the grid while the plant is shutdown.
To the extent practicable, VARs will be provided by the DG during this SR.The 18 month Frequency i& cOnS istent with the r-eco-emmcnda-tionR-of Reguaitorny Guide 1.8 (Ref. 3) and is intend-ed to be Insert .is SR is modified by a Note. This Note ensures that the DG is tested under load conditions that are as close to design basis conditions as possible.
When synchronized with offsite power, testing should be performed at a lagging power factor of 0.89. This power factor is representative of the actual inductive loading a DG would see under design basis accident conditions.
This power factor should be able to be achieved when performing this SR at power and synchronized with offsite power by transferring house loads from the auxiliary transformer to the startup transformer in order to lower the Class 1E bus voltage. Under certain conditions, however, Note 2 allows the surveillance to be conducted at a power factor other than 0.89. These conditions occur when grid voltage is high, and the additional field excitation needed to get the power factor to 0.89 results in voltages on the emergency busses that are too high. This would occur when performing this SR while shutdown and the loads on the startup transformer are too light to lower the voltage sufficiently to achieve a 0.89 power factor. Under these conditions, the power factor (continued)
PALO VERDE UNITS 1,2,3 B 3.8.1-32 REVISION 5 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.10 (continued)
REQUIREMENTS should be maintained as close as practicable to 0.89 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 of 0.89 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 as practicable to 0.89 without exceeding DG excitation limits.The following compensatory measures shall be implemented prior to the performance of this SR in MODE 1 or 2: a. Weather conditions will be assessed, and the SR will not be scheduled when severe weather conditions and/or unstable grid conditions are predicted or present.b. No discretionary maintenance activities will be scheduled in the APS switchyard or the unit's 13.8 kV power supply lines and transformers which could cause a line outage or challenge offsite power availability to the unit performing this SR.c. All activity, including access, in the Salt River Project (SRP) switchyard shall be closely monitored and controlled.
Discretionary maintenance within the switchyard that could challenge offsite power supply availability will be evaluated in accordance with 10 CFR 50.65(a)(4) and managed on a graded approach according to risk significance.
This S must be prformed-at a lagging p mmer factor of~ 089atleast onc-e every 36 mont-hs for e-ach 0Gr. The first per-formance of this SR at a lagging poewer factor of 4 0.89 shal e :itin36months, plus the 9 Aot alloewanceo SR 30.2,from the date of imp!ectto f h ehia Specification -amend-ment th-at is adding the power factor tc--tng rcguircment to this SRD (Amndmcnt ho. 1-67.implemented on August- 29 SR 3.8.1.11 As required by Regulatory Guide 1.9 (Ref. 3), paragraph 2.2.4, this Surveillance demonstrates the as designed operation of the standby power sources during loss of the offsite source. This test verifies all actions encountered from the loss of offsite power, including (continued)
PALO VERDE UNITS 1,2,3 B 3.8.1-33 REVISION 49 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.11 (continued)
REQUIREMENTS shedding of the nonessential loads and energization of the emergency buses and respective loads from the DG. It further demonstrates the capability of the DG to automatically achieve the required voltage and frequency within the specified time.The DG auto-start time of 10 seconds is derived from requirements of the accident analysis.
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 emergency 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, Emergency Core Cooling Systems (ECCS) injection valves are not desired to be stroked open, high pressure injection systems are not capable of being operated at full flow, or shutdown cooling (SDC) 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 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 to the extent possible ensuring power is available to the component.
Thec ....ue.y of 18 monthos 4A ....iztcnt '":th the rccomcndtion of cgutormy Guide 1.9 (Ref. 3), takes into rcongidcration unRit conAditionz rcgquir-ed to pcrzferm the-!Surweiiiice and is intendcd-to be conA-izstent w:ith expected f'uel GyG!e ! e.Insert 1 -----'his SR is modified by four Notes. The reason for Note 1 is to minimize wear and tear on the DGs during testing. 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 safety systems. This restriction from normally performing the (continued)
PALO VERDE UNITS 1,2,3 B 3.8.1-34 REVISION 4-5 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.12 (continued)
REQUIREMENTS The existing design for CSAS actuation signal does not provide an emergency mode start to the DG. A CSAS actuation signal cannot occur until after a SIAS actuation signal has already been generated.
SR 3.8.1.12.d and SR 3.8.1.12.e ensure that permanently connected loads and auto-connected emergency loads (auto-connected through the automatic load sequencer) are energized from the offsite electrical power system on an ESF signal without loss of offsite power.The requirement to verify the connection of permanent and auto-connected emergency loads is intended to satisfactorily show the relationship of these loads to the offsite circuit 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, high pressure injection systems are not capable of being operated at full flow, or SDC 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 connection and loading of loads, testing that adequately shows the capability of the offsite circuit 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 to the extent possible ensuring power is available to the component.
Thec Fequency of 18 months takcs into con.id.PrioA unit conditions required to perform the Surveillance and is intended-to be con.-istent
,,ith the expected fuel cycle lenths. Operating experience has shown th-at the-se components usually pa-ss them SR when performed -at the-1_8 month Frcguencay.
Thcrcforpe, the Fregucncy w:as insert il --(conti nued)PALO VERDE UNITS 1,2,3 B 3.8.1-36 REVISION W0 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.1.13 This Surveillance demonstrates that DG and its associated 4.16 KV output breaker noncritical protective functions (e.g., high jacket water temperature) are bypassed on a loss of voltage signal concurrent with an ESF actuation test signal, and critical protective functions (engine overspeed, generator differential current, engine low lube oil pressure, and manual emergency stop trip), trip the DG to avert substantial damage to the DG unit. The noncritical 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 18 month Frequency is based on enginccring judgment, tRkingu ntor onsider1atin unit conditions required to With expeted fue. cle lengths. Operating experiencte has 0n less that te couponents, ,hursu ps he SIR whan performed aRt the 1_8 monthFrquecy Therefore, the Frequency tao c5onl1uded to he ccneptable from a reliability Insert Regulatory Guide 1.9 (Ref. 3), paragraph 2.2.9, requires demonstration onc Aper 18 months that the DGs can start and run continuously at full load capability for an interval of not less than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, ! 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> of which is at a load equivalent to 105 to 110% of the continuous rating of the DG (5775 -6050 kW) and 22 hours2.546296e-4 days <br />0.00611 hours <br />3.637566e-5 weeks <br />8.371e-6 months <br /> at a load equivalent to 90 to 100% of the continuous duty rating of the DG (4950 -5500 kW). The DG starts for this Surveillance can be performed either from normal keep-warm or hot conditions.
The provisions for prelubricating 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 (Note 3 and Note 4).In order to ensure that the DG is tested under load conditions that are as close to design conditions as possible, testing is performed using design basis kW loading and maximum kVAR loading permitted during testing. These (continued)
PALO VERDE UNITS 1,2,3 B 3.8.1-38 REVISION 4-5 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.14 (continued)
REQUIREMENTS loads represent the inductive loading that the DG would experience to the extent practicable and is consistent with the intent of Regulatory Guide 1.9 (Ref. 3). Administrative limits have been placed upon the Class 1E 4160 V buses due to high voltage concerns.
As a result, power factors deviating much from unity are currently not possible when the DG runs parallel to the grid while the plant is shutdown.
To the extent practicable, VARs will be provided by the DG during this SR. 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 following compensatory measures shall be implemented prior to the performance of this SR in MODE 1 or 2 with the DG connected to an offsite circuit: a. Weather conditions will be assessed, and the SR will not be scheduled when severe weather conditions and/or unstable grid conditions are predicted or present.b. No discretionary maintenance activities will be scheduled in the APS switchyard or the unit's 13.8 kV power supply lines and transformers which could cause a line outage or challenge offsite power availability to the unit performing this SR.c. All activity, including access, in the Salt River Project (SRP) switchyard shall be closely monitored and controlled.
Discretionary maintenance within the switchyard that could challenge offsite power supply availability will be evaluated in accordance with 10 CFR 50.65(a)(4) and managed on a graded approach according to risk significance.
The 18 month Frequency is conzizqtcnt with the Pecemmcndatiens af ReIum a tIr Guide 1 9 (Ref. 3), requi red to perform the -Sureilanee, and- is inte(nded to be (conti nued)PALO VERDE UNITS 1,2,3 B 3.8.1-39 REVISION 4-5 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.14 (continued)
REQUIREMENTS This Surveillance is modified by four Notes. Note 1 states that momentary variations due to changing bus loads do not invalidate the test. Note 2 ensures that the DG is tested under load conditions that are as close to design basis conditions as possible.
When synchronized with offsite power, testing should be performed at a lagging power factor of 0.89. This power factor is representative of the actual inductive loading a DG would see under design basis accident conditions.
This power factor should be able to be achieved when performing this SR at power and synchronized with offsite power by transferring house loads from the auxiliary transformer to the startup transformer in order to lower the Class 1E bus voltage. Under certain conditions, however, Note 2 allows the surveillance to be conducted at a power factor other than 0.89. These conditions occur when grid voltage is high, and the additional field excitation needed to get the power factor to 0.89 results in voltages on the emergency busses that are too high. This would occur when performing this SR while shutdown, and the loads on the startup transformer are too light to lower the voltage sufficiently to achieve a 0.89 power factor. Under these conditions, the power factor should be maintained as close as practicable to 0.89 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 of 0.89 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 as practicable to 0.89 without exceeding DG excitation limits. The provisions for prelubricating 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 (Note 3 and Note 4).This SR must be pcrformed at a lagging pow.. facAtoe -4 0.89 at. leantonce 3.per-formance of this SR at a lagging powr factor of -o 0u89 shall1 bhe ;ithin 36 months, plus thca 9 monRth allowancc of SR 3.0.2, from the date of implcmcntation; of the Tcchnicval-Specr-i f-icra t ionA ame'n-dm-ent that is adding the powA-ier fco testingrequrmnoftiSR (Amendment No. 167, implemented on August 29-,--2007)(conti nued)PALO VERDE UNITS 1,2,3 B 3.8.1-40 REVISION 49 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
IInsert 1]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 10 seconds, and subsequently achieves steady state required voltage and frequency ranges. Error values for specific instruments for non-steady state (transients) are established to derive indicated values in test procedures.
The 10 second time is derived from the requirements of the accident analysis to respond to a design basis large breaICA The 18 month Frcgucncy i nan 2 -in- + _ 11 4-k aa,,,n -n -F Da .1 * -a , Q. 4 An 1 Ql (Ref. 3), papagraph 2210.ti cii- 0-.t-s, This SR is modified by three Notes. Note 1 ensures that the test is performed with the diesel sufficiently hot. The load band is provided to avoid routine overloading of the DG. Routine overloads may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY.
Per the guidance in Regulatory Guide 1.9, this SR would demonstrate the hot restart functional capability at full-load temperature conditions, after the DG has operated for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> (or until operating temperatures have stabilized) at full load.Momentary transients due to changing bus loads do not invalidate the 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. Note 3 states that the steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument accuracy.The analyzed values for the steady-state diesel generator voltage limits are 4000 and : 4377.2 volts and the analyzed values for the steady-state diesel generator frequency limits are 59.7 and 60.7 hertz. The indicated steady state diesel generator voltage and frequency limits, using the panel mounted diesel generator instrumentation and adjusted for instrument error, are 4080 and : 4300 volts (Ref. 12), and 59.9 and : 60.5 hertz (Ref. 13), respectively.
If digital Maintenance and Testing Equipment (M&TE) is used instead of the panel mounted diesel generator instrumentation, the instrument error may be reduced, increasing the range for the indicated steady state voltage and frequency limits.(continued)
PALO VERDE UNITS 1,2,3 B 3.8.1-41 REVISION -54 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.1.16 As required by Regulatory Guide 1.9 (Ref. 3), paragraph 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, in standby operation (running unloaded), the output breaker is open and can receive an autoclose signal on bus undervoltage, and the load sequence timers are reset.a m *
- A a
- a m a I ine Frequency of !L montns i. .con-istent with the recoAmmendation ofRglatory Guide 1.9 (Ref. 3), and take-s Su -.. o ...Insert11-s 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, 3, and 4 is further amplified to allow the surveillance to be performed for the purpose of reestablishing 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 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 a plant shutdown and startup to determine that plant safety is maintained or enhanced when the surveillance is performed in MODE 1 or 2. Risk insights or deterministic methods may be used for this assessment.(continued)
PALO VERDE UNITS 1,2,3 B 3.8.1-42 REVISION 4-5 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.1.17 Demonstration of the test mode override ensures that the DG availability under accident conditions will not be compromised as the result of testing and the DG will automatically reset to ready-to-load operation if a LOCA actuation signal (e.g., simulated SIAS) is received during operation in the test mode. Ready-to-load operation is defined as the DG running at rated speed and voltage, in standby operation (running unloaded) with the DG output breaker open. These provisions for automatic switchover are required by IEEE-308 (Ref. 12), paragraph 6.2.6(2) and Regulatory Guide 1.9 (Ref. 3), paragraph 2.2.13.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 was 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... ....I I I ITh IS montnh ic istent tfhp rccommedation of Reutr Guide 1.9 (Ref. 3), takes into consideration -nit conditions required to perform the Surveillance, and is intended to; -cen6i6t@nt
- ith expected i Insert la -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, 3, and 4 is further amplified to allow portions of the surveillance to be performed for the purpose of reestablishing 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 partial surveillance, a successful partial surveillance, and a (continued)
PALO VERDE UNITS 1,2,3 B 3.8.1-43 REVISION 4-5 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.17 (continued)
REQUIREMENTS 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 a plant shutdown and startup to determine that plant safety is maintained or enhanced when portions of the surveillance are performed in MODE 1, 2, 3, or 4. Risk insights or deterministic methods may be used for this assessment.
SR 3.8.1.18 Under accident and loss of offsite power conditions loads are sequentially connected to the bus by the automatic load sequencer.
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 1 second load sequence time tolerance ensures that sufficient time 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.
FSAR, Chapter 8 (Ref. 2) provides a summary of the automatic loading of ESF buses.The Frcgucncy of 18 months is consistent wimth the PommcndatioAS of y Gide 1.9 CRDF. 3), paragraph 2.2.4, take-s into consider-ation unit coAnditions regui red to perform the Swrwei!Iance, and- is intended to be--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, 3, and 4 is further amplified to allow the surveillance to be performed for the purpose of reestablishing 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 when they are tied together (continued)
PALO VERDE UNITS 1,2,3 B 3.8.1-44 REVISION 45 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.18 (continued)
REQUIREMENTS (continued) 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 a plant shutdown and startup to determine that plant safety is maintained or enhanced when the surveillance is performed in MODE 1 or 2. Risk insights or deterministic methods may be used for this assessment.
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 ESF actuation signal. In lieu of actual demonstration of connection and loading of loads, testing that adequately shows the capability of the DG system to perform these functions is acceptable.
This testing may include any series of sequential, overlapping, or total steps so that ieded to bc consistent with an expected fuel cycle length of 18 This SR is modified by three 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 continuously circulated and temperature maintained consistent with manufacturer recommendations for DGs. 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 safety systems. This restriction from normally performing the surveillance in MODE 1, 2, 3, and 4 is further amplified to allow portions of the surveillance to be performed for the purpose of reestablishing 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 (continued)
PALO VERDE UNITS 1,2,3 B 3.8.1-45 REVISION 4-5 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.19 (continued)
REQUIREMENTS enhanced.
This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed partial 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 a plant shutdown and startup to determine that plant safety is maintained or enhanced when portions of the surveillance are performed in MODE 1, 2, 3, or 4. Risk insights or deterministic methods may be used for this assessment.
Note 3 states that the steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument accuracy.
The analyze values for the steady-state diesel generator voltage limits are 2 4000 and 4377.2 volts and the analyzed values for the steady-state diesel generator frequency limits are 59.7 and 5 60.7 hertz. The indicated steady state diesel generator voltage and frequency limits, using the panel mounted diesel generator instrumentation and adjusted for instrument error, are 4080 and 5 4300 volts (Ref.12), and 2 59.9 and : 60.5 hertz (Ref.13), respectively.
If digital Maintenance and Testing Equipment (M&TE) is used instead of the panel mounted diesel generator instrumentation, the instrument error may be reduced, increasing the range for the indicated steady state voltage and frequency limits.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.
Error values for specific instruments for non-steady state (transients) are established to derive indicated values in test procedures.
The 10 year Frequency iiz cozistent with the rccommcndatieonz of Reguiatory-G id1.9 (Ref. 31), paragraph 2.3.2.4 -and-Reg~ulator'y Guide 1.137(Rf9)
Insert 1 is SR is modified by two Notes. The reason for Note 1 is to minimize wear on the DG during testing. Note 2 states that the steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument accuracy.
The analyzed values for the steady-state diesel generator voltage limits are 2 4000 and (continued)
PALO VERDE UNITS 1,2,3 B 3.8.1-46 REVISION W Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES ACTIONS F.1 (continued)
A Note modifies condition F. Periodic starting of the Emergency Diesel Generator(s) requires isolation on one of the two normally aligned air start receivers.
During the subsequent Diesel Generator start, the air pressure in the one remaining air receiver may momentarily drop below the minimum required pressure of 185 psig indicated.
This would normally require declaring the now running Diesel Generator inoperable, due to low pressure in the air start system.This is not required, as the Diesel Generator would now be running following the successful start. Should the start not be successful, the DG would be declared inoperable per the requirements of LCO 3.8.1. As such, this Condition is modified by a Note stating that should the required starting air receiver pressure momentarily drop to <185 psig indicated while starting the Diesel Generator on one air receiver only, then entry into Condition F is not required.It is expected that this condition would be fairly short duration (approximately 8 minutes), as the air start compressors should quickly restore the air receiver pressure after the diesel start.SURVEILLANCE SR 3.8.3.1 REQUIREMENTS This SR provides verification that there is an adequate inventory of fuel oil in the storage tanks to support each DG's operation for 7 days at full load. 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 FrcgucncY is adequate to ensuWre that a sufficietm s-upply of fuel oil i4 a ilae since level aIar-Ilms are provided and unit opcr-ater-s we:uld- be -aw':ar of any large uses This Surveillance ensures that sufficient lube oil inventory is available to support at least 7 days of full load operation for each DG. The 2.5 inches visible in the sightglass requirement is based on the DG manufacturer consumption values for the run time of the DG. Implicit in this SR is the requirement to verify the capability to (continued)
PALO VERDE UNITS 1,2,3 B 3.8.3-6 REVISION 61 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE SR 3.8.3.2 (continued)
REQUIREMENTS transfer the lube oil from its storage location to the DG, when the DG lube oil sump does not hold adequate inventory for 7 days of full load operation without the level reaching the manufacturer recommended minimum level.The 31 day Frcquency is adequ-ate to en-sure th-at -a su-Wfficient.
lubc eil supply is 9--... DG and- run- .time are The tests listed below are a means of determining whether new fuel oil is of the appropriate grade and has not been contaminated with substances that would have an immediate, detrimental impact on diesel engine combustion.
If results from these tests are within acceptable limits, the fuel oil may be added to the storage tanks without concern for contaminating the entire volume of fuel oil in the storage tanks. These tests are to be conducted prior to adding the new fuel to the storage tank(s), but in no case is the time between receipt of new fuel and conducting the tests to exceed 31 days. The tests, limits, and applicable ASTM Standards are as follows: a. Sample the fuel oil in accordance with ASTM-D4057 (Ref. 6): b. Verify in accordance with the tests specified in ASTM D975 (Ref. 6) that the sample has an absolute specific gravity at 60/60°F of 0.83 and 0.89, or an API gravity at 60°F of 270 and ! 390, a kinematic viscosity at 40 0 C of 1.9 centistokes and 4.1 centistokes, and a flash point 125 0 F; and c. Verify in accordance with the tests specified in ASTM D1796 (Ref. 6) that the sample water and sediment is< 0.05 percent volume.Failure to meet any of the above limits is cause for rejecting the new fuel oil, but does not represent a failure to meet the LCO concern since the fuel oil is not added to the storage tanks.(continued)
PALO VERDE UNITS 1,2.3 B 3.8.3-7 REVISION 4-]1 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE SR 3.8.3.4 REQUIREMENTS (conti nued)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 without recharging.
A start cycle is defined by the DG vendor, but usually is measured in terms of time (seconds or cranking) or engine cranking speed. The pressure specified in this SR is intended to reflect the lowest value at which the DG can be considered OPERABLE.The 31 day Frequency takes into account the capacity-, capability, redundancy, and diversity of the AG sourcres and othcr indicationg in the control room, inciudnWg alams t alrtth opraorto-b-elow-noAr-mal -air- st-art 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. Removal of water from the fuel oil 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, ground water, 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 .The Surveillance Frequencies are---- " y Reu D latory Guide 1.17 (Ref. 19) Thi SR is........ 14 1.. tive .....-ar. The presence of water does not necessarily represent failure of this SR provided the accumulated water is removed during the performance of this Surveillance.(continued)
PALO VERDE UNITS 1,2,3 B 3.8.3-9 REVISION 4-4 DC Sources -Operating B 3.8.4 BASES ACTIONS C.1 and C.2 (continued)
Time allows for re-establishing charging capability such that Category A parameters can be met. Operation with the DC electrical power subsystem battery charger inoperable is not allowed for an indefinite period of time even when the battery cell parameters have been verified to meet the Category A limits of Table 3.8.6-1. The 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> completion time provides a period of time to correct the problem commensurate with the importance of maintaining the DC electrical power subsystem battery charger in an OPERABLE status.The loss of the two required (in-service) battery chargers on the same train would be a degradation of the train beyond the scope of Condition C, thus rendering the train inoperable and requiring entry into Condition A.D.1 If the battery cell parameters cannot be maintained within Category A limits as specified in LCO 3.8.6, the short term capability of the battery is also degraded and the battery must be declared inoperable.
SURVEILLANCE SR 3.8.4.1 REQUIREMENTS Verifying battery terminal voltage while on float charge for the batteries helps to ensure the effectiveness of the charging system and the ability of the batteries to perform their intended function.
Float charge is the condition in which the charger is supplying the continuous charge required to overcome the internal losses of a battery (or battery cell) and maintain the battery (or a battery cell)in a fully charged state. The voltage requirements are based on the nominal design voltage of the battery and are consistent with the initial voltages assumed in the battery sizing calcula i The 7 day ...gucncy ....(continued)
PALO VERDE UNITS 1,2,3 B 3.8.4-6 REVISION 2 DC Sources -Operating B 3.8.4 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.4.2 Visual inspection to detect corrosion of the battery cells and connections, or measurement of the resistance of each inter-cell, inter-rack, inter-tier, and terminal connection, provides an indication of physical damage or abnormal deterioration that could potentially degrade battery performance.
The limits established for this SR are based on calculation 1,2,3ECPK207 which states that if every terminal connection were to degrade to 150E-6 ohms, there would be sufficient battery capacity to satisfy the DBA Duty Cycle (Ref. 13).Th..Sureillance FrequencY forn these npetionS, Whic. h can Sdctectc ios6 t c e power- lsses due resstace eatngis92 days. Thi Fequency is%cosdee acptbe bae noeaigexperi;enerelte Visual inspection of the battery cells, cell plates, and battery racks provides an indication of physical damage or abnormal deterioration that could potentially degrade battery performance.
The presence of physical damage or deterioration does not necessarily represent a failure of this SR, provided an evaluation determines that the physical damage or deterioration does not affect the OPERABILITY of the battery (its ability to perform its design function).
Thig SR is consistent with IEEE 450 (Ref. 9), which recmmeds etaledvisual inspection of cell condition and rack -integrity.-
The 18 mont-h Surveillance Frequency is cons~istentR with expec-ted fuel cycle length, minimizing batter-y tetn 8hil onln that coul d resut edrn Visual inspection and resistance measurements of inter-cell, inter-rack, inter-tier, and terminal connections provide an indication of physical damage or abnormal deterioration that could indicate degraded battery condition.
The anticorrosion material is used to help ensure good electrical connections and to reduce terminal deterioration.(continued)
PALO VERDE UNITS 1,2,3 B 3.8.4-7 REVISION 45 DC Sources -Operating B 3.8.4 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.4.4 and SR 3.8.4.5 (continued)
The visual inspection for corrosion is not intended to require removal of and inspection under each terminal connection.
The removal of visible corrosion is a preventive maintenance SR. The presence of visible corrosion does not necessarily represent a failure of this SR provided visible corrosion is removed during performance of SR 3.8.4.4.The connection resistance limits for SR 3.8.4.5 is based on calculation 1,2,3ECPK207 which states that if every terminal connection were to degrade to 150E-6 ohms there would be sufficient battery capacity to satisfy the DBA Duty Cycle (Ref. 13).The urelncsare cossetwith IEEE-150 (Ref. 9), which recommends cell to cell and terminal connection Fr.equency i4 co.nsistent.
with expected fuel cycle length, miiizn battery testing w:hile on line that could r-esult This SR requires that each required battery charger be capable of supplying 400 amps for batteries A and B and 300 amps for batteries C and D, and 125 V for 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />. These requirements are based on the design capacity of the chargers (Ref. 4). According to Regulatory Guide 1.32 (Ref. 10), 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 ensures that these requirements can be satisfied.
The S.Uureillarnce Frmequency is acceptable, given the u-nit conditions required to perform the test and the othe amnistrati~e nt-rols1 existin toenue adequate char-ger pepfeormane duing the"se 18 month intcrvals
.In addition, this Frequenc..y i i.nended to be c.nsistent with expected-fuel GGle inser 111----T-his SR is modified by a Note. The reason for the Note is that performing the Surveillance on the charger credited for (continued)
PALO VERDE UNITS 1,2,3 B 3.8.4-8 REVISION X5 DC Sources -Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.6 (continued)
REQUIREMENTS OPERABILITY would perturb the electrical distribution system and challenge safety systems. This restriction from normally performing the surveillance in MODE 1, 2, 3, and 4 is further amplified to allow portions of the surveillance to be performed for the purpose of reestablishing 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 partial 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 a plant shutdown and startup to determine that plant safety is maintained or enhanced when portions of the surveillance are performed in MODE 1, 2, 3, or 4. Risk insights or deterministic methods may be used for this assessment.
SR 3.8.4.7 A battery service test is a special test of battery capability, as found, to satisfy the design requirements (battery duty cycle) of the DC electrical power system. The discharge rate and test length should correspond to the design duty cycle requirements as specified in Reference 4.ThDp Frequcncy of 18 mnthD isz cnzistcnt with the ccomenatin~
f Regulatoryýiý G id1.32 (Ref. 10) and Reglatry uid 1.29(Ref.
11), whieh state that the battey zeriee tezst TAhould- be perfor-med during refueling to, or at zne otherp utage, with interwlalzq Insert~ ~ i 1,11S s .......m odified by two Notes. Note 1 allows the'performance of a battery performance discharge test or a modified performance discharge test in SR 3.8.4.8 in lieu of a service test since both performance discharge test parameters envelope the service test. The reason for Note 2 is that performing the Surveillance would perturb the electrical distribution system and challenge safety systems.(continued)
PALO VERDE UNITS 1,2,3 B 3.8.4-9 REVISION 35 DC Sources -Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.8 REQUIREMENTS (continued)
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.The modified performance discharge test is a simulated duty cycle consisting of just two rates: the one minute rate published for the battery or the largest current load of the duty cycle (but in no case lower than the performance test rate), followed by the test rate employed for the performance test, both of which envelope the duty cycle of the service test. Since the ampere-hours removed by 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.A modified 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.Either the battery performance discharge test or the modified performance discharge test is acceptable for satisfying SR 3.8.4.8. In addition, either of the performance discharge tests may be used to satisfy SR 3.8.4.8 while satisfying the requirements of SR 3.8.4.7 at the same time, because the test parameters envelope the service test described in SR 3.8.4.7.The acceptance criteria for this Surveillance are consistent with IEEE-450 (Ref. 9) and IEEE-485 (Ref. 5). These references recommend that the battery be replaced if its capacity is below 80% of the manufacturer rating. A capacity of 80% shows that the battery rate of deterioration is increasing, even if there is ample capacity to meet the load requirements.
~ The FrquencY for this test is normally lnser nm1h If the battery shows degradation, or if the (continued)
PALO VERDE UNITS 1,2;3 B 3.8.4-10 REVISION 3.7 Battery Cell Parameters B 3.8.6 BASES ACTIONS A.1, A.2, and A.3 (continued)
Continued operation is only permitted for 31 days before battery cell parameters must be restored to within Category A and B limits. With the consideration that, while battery capacity is degraded, sufficient capacity exists to perform the intended function and to allow time to fully restore the battery cell parameters to normal limits, this time is acceptable prior to declaring the battery inoperable.
B.1 With one or more batteries with one or more battery cell parameters not within the Category C limit for any connected cell. sufficient capacity to supply the maximum expected load requirement is not assured and the corresponding DC electrical power subsystem must be declared inoperable.
Additionally, other potentially extreme conditions, such as not completing any of the Required Actions of Condition A within the required Completion Time or average electrolyte temperature of representative cells falling below 60 0 F, are also cause for immediately declaring the associated DC electrical power subsystem inoperable.
SURVEILLANCE SR 3.8.6.1 REQUIREMENTS This SR verifies that Category A battery cell parameters are consistent with IEEE-450 (Ref. 3), which recommends regular battery inspections (at least one per monh including float voltage, specific gravity, and electrolyte level of pilot cells.[insert 11 -" " SR 3.8.6.2 The quaperly inspection of level, specific gravity and float voltage is consistent with I I .n o a attery discharge
< 105 V or a Insebattery overcharge
> 150 V, the battery must be demonstrated to meet Category B limits. Transients, such as motor starting transients, which may momentarily cause battery (continued)
PALO VERDE UNITS 1,2,3 B 3.8.6-3 REVISION 4 Battery Cell Parameters B 3.8.6 BASES SURVEILLANCE SR 3.8.6.2 (continued)
REQUIREMENTS voltage to drop to 105 V, do not constitute a battery discharge provided the battery terminal voltage and float current return to pre-transient values. This inspection is also consistent with IEEE-450 (Ref. 3), which recommends special inspections following a severe discharge or overcharge, to ensure that no significant degradation of the battery occurs as a consequence of such discharge or overcharge.
SR 3.8.6.3 This Surveillance verification that the average temperature of representative cells (a 10% representative sample of available cells for each battery bank) is 60°F is consistent with a recommendation of IEEE-450 (Ref. 3), which states that the temperature of electrolytes in representative cells should be determined on a quarterly basis.Lower than normal temperatures act to inhibit or reduce battery capacity.
This SR ensures that the operating temperatures remain within an acceptable operating range.This limit is based on vendor recommendations.
InserTable 3.8.6-1 This table delineates the limits on electrolyte level, float voltage, and specific gravity for three different categories.
The meaning of each category is discussed below.Category A defines the normal parameter limit for each designated pilot cell in each battery. The cells selected as pilot cells are those whose level, voltage and electrolyte specific gravity approximate the state of charge of the entire battery.The Category A limits specified for electrolyte level are based on vendor recommendations and are consistent with the guidance in IEEE-450 (Ref. 3), with the extra 3/4,/ inch allowance above the high water level indication for operating margin to account for temperatures and charge (continued)
PALO VERDE UNITS 1,2,3 B 3.8.6-4 REVISION ra Inverters
-Operating B 3.8.7 BASES (continued)
SURVEILLANCE REQUIREMENTS SR 3.8.7.1 This Surveillance verifies that the inverters are functioning properly with all required circuit breakers closed and AC vital instrument buses energized from the inverter.
The verification of proper voltage and frequency output ensures that the required power is readily available for the instrumentation of the RPS and ESFAS connected to the AC vital instrument bus h a rqec ae" "ý The 7 d, Pegunne-y tae iInsert 1 lether- ind-iAtins, -;w-il -bhle i n the r-ent-re!-
teAem that aler-t the opcr-ator to inverter malfnctions.
REFERENCES
- 1. UFSAR, Chapter 8.2. UFSAR, Chapter 6.3. UFSAR, Chapter 15.PALO VERDE UNITS 1,2,3 B 3.8.7-5 REVISION &
Inverters
-Shutdown B 3.8.8 BASES ACTIONS A.1, A.2.1, A.2.2, A.2.3, and A.2.4 (continued) movement, operations with a potential for draining the reactor vessel, and operations with a potential for positive reactivity additions.
By the allowance of the option to declare required features inoperable with the associated inverter(s) inoperable, appropriate restrictions will be implemented in accordance with the affected required features LCOs' Required Actions. In many instances, this option may involve undesired administrative efforts.Therefore, the allowance for sufficiently conservative actions is made (i.e., to suspend CORE ALTERATIONS, movement of irradiated fuel assemblies, and operations involving positive reactivity additions).
The Required Action to suspend positive reactivity additions does not preclude actions to maintain or increase reactor vessel inventory, provided the required SDM is maintained.
Suspension of these activities shall not preclude completion of actions to establish a safe conservative condition.
If moving irradiated fuel assemblies while in MODES 1, 2, 3, or 4, the fuel movement is independent of reactor operations.
Therefore, inability to immediately suspend movement of irradiated fuel assemblies would not be sufficient reason to require a reactor shutdown.
These actions minimize the probability of the occurrence of postulated events. It is further required to immediately initiate action to restore the required inverters and to continue this action until restoration is accomplished in order to provide the necessary inverter power to the unit safety systems.The Completion Time of immediately is consistent with the required times for actions requiring prompt attention.
The restoration of the required inverters should be completed as quickly as possible in order to minimize the time the unit safety systems may be without sufficient power.SURVEILLANCE SR 3.8.8.1 REQUIREMENTS This Surveillance verifies that the inverters are functioning properly with all required circuit breakers closed and AC vital instrument buses energized from the inverter.
The verification of proper voltage and frequency output ensures that the required power is readily available for the instrumentation connected to the AC vital instrument b~use The 7 day Frequency takes into account the rcndtundn insert ijj __(conti nued)PALO VERDE UNITS 1,2,3 B 3.8.8-4 REVISION 2 Inverters
-Shutdown B 3.8.8 BASES SURVEILLANCE SR 3.8.8.1 (continued)
REQUIREMENTS capability of the in~'crters And other indicm~Atin av:ailable iln the control room that alertthe operator to in"erter REFERENCES
- 1. UFSAR, Chapter 6.2. UFSAR, Chapter 15.PALO VERDE UNITS 1,2,3 B 3.8.8-5 REVISIONI Distribution Systems -Operating B 3.8.9 BASES SURVEILLANCE SR 3.8.9.1 REQU I REMENTS This Surveillance verifies that the AC, DC, and AC vital instrument bus electrical power distribution systems are functioning properly, with the required circuit breakers closed and the buses energized.
The correct breaker alignment ensures the appropriate separation and independence of the electrical divisions is maintained, and the appropriate voltage is available to each required bus.The verification of proper voltage availability on the buses ensures that the required voltage is readily available for motive as well as control functions for critical system loads connected to ther The 7 day Frequent y trkes room thataerthoprtrt uytemafnin.
REFERENCES
- 1. UFSAR, Chapter 6.2. UFSAR, Chapter 15.3. Regulatory Guide 1.93, Revision 0, December 1974.PALO VERDE UNITS 1,2,3 B 3.8.9-10 REVISION 4 Distribution Systems -Shutdown B 3.8.10 BASES (continued)
ACTIONS (continued)
Notwithstanding performance of the above conservative Required Actions, a required shutdown cooling (SDC)subsystem may be inoperable.
In this case, Required Actions A.2.1 through A.2.4 do not adequately address the concerns relating to coolant circulation and heat removal. Pursuant to LCO 3.0.6, the SDC ACTIONS would not be entered.Therefore, Required Action A.2.5 is provided to direct declaring SDC inoperable, which results in taking the appropriate 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 unit safety systems may be without power.SURVEILLANCE SR 3.8.10.1 REQUIREMENTS This Surveillance verifies that the AC, DC, and AC vital instrument bus electrical power distribution system is functioning properly, with all the required buses energized.
The verification of proper voltage availability on the buses ensures that the required power is readily available for motive as well as control functions for critical system loads connec~ted to these The 7 day Frequency t-ake-s x.aiw b in the onmtrol room that alcrt the operator to REFERENCES
- 1. UFSAR, Chapter 6.2. UFSAR, Chapter 15.PALO VERDE UNITS 1,2,3 B 3.8.10-4 REVISION G Boron Concentration B 3.9.1 BASES ACTIONS A.3 (continued)
In determining the required combination of boration flow rate and concentration, there is no unique design basis event that must be satisfied.
The only requirement is to restore the boron concentration to its required value as soon as possible at greater than or equal to 26 gpm of a solution containing greater than 4000 ppm boron. In order to raise the boron concentration as soon as possible, the operator should begin boration with the best source available for unit conditions.
Once boration is initiated, it must be continued until the boron concentration is restored.
The restoration time depends on the amount of boron that must be injected to reach the required concentration.
SURVEILLANCE SR 3.9.1.1 REQUIREMENTS This SR ensures the coolant boron concentration in the RCS and the refueling canal is within the COLR limits. The boron concentration of the coolant in each volume is determined periodically by chemical analysis.A uf onne every 72 ho.....is therefore a rcsnbcamount of tiPt)vrf the boronn rconcentratioAn of r-epresent-ative Samples. The Fr-equencGy is based on oErtn Kexprience, whic-h h-as shown 72 ousto be REFERENCES
- 1. 10 CFR 50, Appendix A, GDC 26.2. UFSAR, Section 9.1.2.PALO VERDE UNITS 1,2,3 B 3.9.1-4 REVISION 4 Nuclear Instrumentation B 3.9.2 BASES ACTIONS B.1 (continued)
With no SRM OPERABLE, action to restore a monitor to OPERABLE status shall be initiated immediately.
Once initiated, action shall be continued until an SRM is restored to OPERABLE status.With no SRM OPERABLE, there is no direct means of detecting changes in core reactivity.
However, since CORE ALTERATIONS and positive reactivity additions are not to be made, the core reactivity condition is stabilized until the SRMs are OPERABLE.
This stabilized condition is verified by performing Action B.1 of LCO 3.3.12 which requires RCS boron concentration to be determined by redundant methods immediately and at the monitoring frequency specified in the COLR Section 3.3.12. This action satisfies the requirements of the inadvertent deboration safety analysis.RCS boron concentration sampling by redundant methods ensures a boron dilution will be detected with sufficient time to terminate the event before the reactor achieves criticality.
SURVEILLANCE SR 3.9.2.1 REQUIREMENTS SR 3.9.2.1 is the performance of a CHANNEL CHECK, which is a comparison of the parameter indicated on one channel to a similar parameter on other channels.
It is based on the assumption that the two indication channels should be consistent with core conditions.
Changes in fuel loading and core geometry can result in significant differences between source range channels, but each channel should be consistent with its local conditions.
The Y is ba--d on experience that-the r-arity of ehannel fa iUA1. Since th pprobbility of tw.o randoni failuzi reundant channcls in any 12 houerio is extremely
]oý IM, aCNELHCK-minimizes the hance o-f los- of fIInction du-e to "filu oF (continued)
PALO VERDE UNITS 1,2,3 B 3.9.2-3 REVISION 1-5 Nuclear Instrumentation B 3.9.2 BASES SURVEILLANCE SR 3.9.2.2 REQUIREMENTS (continued)
SR 3.9.2.2 is the performance of a CHANNEL CALIBRATION every A menths. This SR is modified by a Note stating that neutron detectors are excluded from the CHANNEL CALIBRATION.
The detectors are of simple construction, and any failures in the detectors will be apparent as change in channel output. The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.
CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational.
This SR is an extension of SR 3.3.12 for the Boron Dilution Alarm System CHANNEL CALIBRATION listed here because of its Applicability in t The 18 month P.equency is component dsaily pass the Sur-wcillancc when perfor-med on the 18 month F.equency..
The CHANNEL CALIBRATION is normally performed during a plant outage, but can be performed with the reactor at power if detector curve determination is not performed.
Detector curve determination can only be performed under conditions that apply during a plant outage since the flux level needs to be at shutdown levels for detector energi zati on.REFERENCES
- 1. 10 CFR 50, Appendix A, GDC 13, GDC 26, GDC 28, and GDC 29.2. UFSAR, Section 15.4.6.PALO VERDE UNITS 1,2,3 B 3.9.2-4 REVISION 44 Containment Penetrations B 3.9.3 BASES ACTIONS A.1 and A.2 (continued) valves are open, the unit must be placed in a condition in which the isolation function is not needed. This is accomplished by immediately suspending CORE ALTERATIONS and movement of irradiated fuel assemblies within containment.
Performance of these actions shall not preclude completion of movement of a component to a safe position.SURVEILLANCE REQUIREMENTS SR 3.9.3.1 This Surveillance demonstrates that each of the containment penetrations required to be in its closed position is in that position.
The Surveillance on the open purge and exhaust valves will demonstrate that the valves are not blocked from closing. Also, the Surveillance will demonstrate that each valve operator has motive power, which will ensure each valve is capable of being closed by an OPERABLE automatic containment purge isolation signal.Thc Sotetillae is perfomtd every 7 days during COe th cntinct. The Suwrwcillanccp intcrval is; rselcctcd to uc"P44 10144mur.t 4nt ui irmalduraion f tic tocomplete fuci handlin oprains. A surveillance before the star-t ofr 'eing operations will provi ode ta oi or- thr-ee Z-urvc0;iLancc verificRatios during the applicable pOerio for postulated fiuel handling accidet that. releases flissio produCt- radoatii within... containm..
ent will not1 result...1 in a release of fission pro9duct raRdioacrtivity to9h environment in excess of those recommended by Standard r~ns. I- SR 3.9.3.2 This Surveillance demonstrates that each containment purge valve actuates to its isolation position on manual initiation or on an actual or simulated high radiation si The318mon siilth Frequenay maintains c-onsistencyig h Insert 1 requirements.
The CPGAS is tested in accordance with LCO of ec v;alve is in accorda4nce with the Tinseryie Testing (continued)
PALO VERDE UNITS 1,2,3 B 3.9.3-5 REVISION 1 Containment Penetrations B 3.9.3 BASES SURVILLANCE REQUIREMENTS SR 3.9.3.2 (continued)
Po..gam requwiements.
These surveillances performed during MODE 6 will ensure that the valves are capable of closing after a postulated fuel handling accident to limit a release of fission product radioactivity from the containment.
SR 3.9.3.3 This Surveillance demonstrates that the necessary hardware, tools, equipment and personnel are available to close the equipment hatch and that the equipment hatch is clear of obstructions that would impede its CIO The 7-day Frequency is coAmmensur-ate with the Insert 1 T ... 1 .. .,, ....,,, ÷0 b met forp an open equipment hth ftehthi cAsed, the czapabi 1i ty to ls the hac i.o REFERENCES
- 1. GPU Nuclear Safety Evaluation SE-0002000-O01, Rev. 0, May 20, 1988.2. UFSAR, Section 15.7.4.3. NUREG-0800, Section 15.7.4, Rev. 1, July 1981.PALO VERDE UNITS 1,2,3 B 3.9.3-6 REVISION 4-9 SDC and Coolant Circulation
-High Water Level B 3.9.4 BASES ACTIONS A.4 (continued)
If SDC loop requirements are not met, all containment penetrations to the outside atmosphere must be closed to prevent fission products, if released by a loss of decay heat event, from escaping the containment building.
The 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Completion Time allows fixing most SDC problems without incurring the additional action of violating the containment atmosphere.
SURVEILLANCE REQUIREMENTS SR 3.9.4.1 This Surveillance demonstrates that the SDC loop is in operation and circulating reactor coolant at a flowrate of greater than or equal to 3780 gpm. The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability and to prevent thermal and boron stratification in the The of 12 hourS inoernEtro, and alarm indications available to thc operator in thc contro roo-tm for monitor-ing the SOC System.REFERENCES
- 1. UPSAR, Section 5.4.7.PALO VERDE UNITS 1.2,3 B 3.9.4-4 REVISION 0 SDC and Coolant Circulation
-Low Water Level B 3.9.5 BASES ACTIONS B.3 (Continued)
If no SDC loop is in operation or no SDC loops are OPERABLE, all containment penetrations providing direct access from the containment atmosphere to the outside atmosphere must be closed within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. With the SDC loop requirements not met, the potential exists for the coolant to boil and release radioactive gas to the containment atmosphere.
Closing containment penetrations that are open to the outside atmosphere ensures that dose limits are not exceeded.The Completion Time of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is reasonable, based on the low probability of the coolant boiling in that time.SURVEILLANCE SR 3.9.5.1 REQUIREMENTS This Surveillance demonstrates that one SDC loop is operating and circulating reactor coolant at a flowrate of greater than or equal to 3780 gpm. The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability and to prevent thermal and boron stratification in the core. In addition, this Surveillance demonstrates that the other SDC loop is OPERABLE.In addition, during operation of the SDC loop with the water level in the vicinity of the reactor vessel nozzles, the SDC loop flow rate determination must also consider the SDC pump suction reuir* The of 12 heo-urs is" insert 1 r- H i ... .. .a-blehl t-o the ... .. -ater to ... "'lt the 99c System in the control. roo9m.
that thc required loops are GRALE and in operatign ensures that loops be placed in n pcation as neded, to maintain dEcay heat and retain forced crculation.
The Frcqucncy of 12 hou-rsr i-s consider-ed reAsonableP-, s inee ot he r -a dm in istrPatv cotrl -ape available and have proeven to bhe acceptable by operatin expeF-ieRGe.-(conti nued)PALO VERDE UNITS 1,2,3 B 3.9.5-4 REVISION 46 SDC and Coolant Circulation
-Low Water Level B 3.9.5 BASES SURVEILLANCE SR 3.9.5.2 REQUIREMENETS (continued)
Verification that the required pump that is not in operation is OPERABLE ensures that an additional SDC pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation.
Verification is performed by verifying proper breaker alignment and power available to the r The Frequency of 7 day6 is contr-9ls a'.ai ab! e and has beenhon to- be acceptabl e by opcratingcxrin.
REFERENCES
- 1. UFSAR, Section 5.4.7.PALO VERDE UNITS 1,2,3 B 3.9.5-5 REVISION Refueling Water Level-Fuel Assemblies B 3.9.6 BASES SURVEILLANCE REQUIREMENTS SR 3.9.6.1 (continued)
The Frequency of 21 hourps i~s bhased on cnieR ering judgment and is considcrcd adeut in iew o~f the large volume of~atcrand hc nrmalprocdural controls of valve positions, andHYA opratonswhih mkesignificant unplanned level REFERENCES
- 1. Regulatory Guide 1.25, March 23, 1972.2. UFSAR, Section 15.7.4.3. NUREG-OBDO, Section 15.7.4.4. 10 CFR 100.10.PALO VERDE UNITS 1,2,3 B 3.9.6-3 REVISION 0 Refueling Water Level-CEAs B 3.9.7 BASES SURVEILLANCE REQUIREMENTS SR 3.9.7.1 Verification of a minimum water level of 23 ft above the top of irradiated fuel assemblies seated within the reactor vessel ensures that the design basis for the postulated fuel handling accident analysis during refueling operations is met. Water at the required level above the top of the irradiated fuel limits the consequences of damaged fuel rods that are postulated to result from a fuel handling accident inside containment (Ref. 2).The Frequenc-y of 24 and ig considered a Innsert peaton houwrg ig based on engiccin Judgment dequatc in view of the large volume of*1 ,.hi-h makc si.-gifici;nt unplanned level REFERENCES
- 1. Regulatory Guide 1.25, March 23, 1972.2. UFSAR, Section 15.7.4.3. NUREG-0800, Section 15.7.4.4. 10 CFR 100.10.PALO VERDE UNITS 1,2,3 B 3.9.7-3 REVISION 0 Insert 1 The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.Insert Attachment 6 Proposed No Significant Hazards Consideration
1.0 DESCRIPTION
OF AMENDMENT REQUEST 2.0 BASIS FOR PROPOSED NO SIGNIFICANT HAZARDS CONSIDERATION Attachment 6 Proposed No Significant Hazards Consideration Request for Adoption of TSTF 425, Rev. 3 Page 1
1.0 DESCRIPTION
OF AMENDMENT REQUEST The proposed change requests the adoption of an approved change to the standard technical specifications (STS) for Combustion Engineering Plants (NUREG-1432), to allow relocation of specific technical specification surveillance frequencies to a licensee-controlled program. The proposed change is described in Technical Specification Task Force (TSTF) Traveler 425, Revision 3 (ADAMS Accession No. ML090850642) related to the Relocation of Surveillance Frequencies to Licensee Control -RITSTF Initiative 5b and was described in the Notice of Availability published in the Federal Register on July 6, 2009 (74 FR 31996).The proposed changes are consistent with NRC-approved Industry/Technical Specification Task Force (TSTF) Traveler 425, Rev. 3, "Relocate Surveillance Frequencies to Licensee Control -RITSTF Initiative 5b." The proposed change relocates surveillance frequencies to a licensee-controlled program, the Surveillance Frequency Control Program (SFCP). This change is applicable to licensees using probabilistic risk guidelines contained in NRC-approved NEI 04-10, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies," (ADAMS Accession No. 071360456).
2.0 BASIS FOR PROPOSED NO SIGNIFICANT HAZARDS CONSIDERATION As required by 10 CFR 50.91 (a), the Arizona Public Service (APS) Company 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.
Attachment 6 Proposed No Significant Hazards Consideration Request for Adoption of TSTF 425, Rev. 3 Page 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 TS), since these are not affected by changes to the surveillance frequencies.
Similarly, there is no impact to safety analysis acceptance criteria as described in the plant licensing basis. To evaluate a change in the relocated surveillance frequency, APS will perform a probabilistic risk evaluation using the guidance contained in NRC approved NEI 04-10, Rev. 1 in accordance with the TS SFCP.NEI 04-10, Rev. 1, methodology provides reasonable acceptance guidelines and methods for evaluating the risk increase of proposed changes to surveillance frequencies consistent with Regulatory Guide 1.177.Therefore, the proposed changes do not involve a significant reduction in a margin of safety.Based upon the reasoning presented above, APS concludes that the requested change does not involve a significant hazards consideration as set forth in 10 CFR 50.92(c), Issuance of Amendment.
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 1 TSTF-425 (NUREG-1432) vs. Palo Verde Technical Specification Cross Reference Yili i I .. .. =,;,!;, :!,,
lorpondlng Palo Vede TS Surveillance Requirements (SR, 4 3.1.1 Shutdown Margin (SDM) -Reactor Trip Breakers Open 3.1..1 13.1.1.1 -Verify SDM1__3.1.2 Shutdown Margin -Reactor Trip Breakers Closed Not in TSTF 3.1.2.1 Verify SDM 1 X Not in TSTF _ 3.1.2.2 Verify KN-1 1 X Not in TSTF 1__ _ 3.1.2.3 Verify criticality cannot be achieved 1 X 3.1.3 Reactivity Balance 3.1.2.1 1 3.1.3.1 Verify overall core reactivity balance 3.1.4 Moderator Temperature Coefficient (MTC)Not in TSTF 3.1.4.1 Verify MTC is within the upper limit N/A Not in TSTF 3.1.4.2 Verify MTC is within the lower limit N/A 3.1.5 Control Element Assembly Alignment 3.1.4.1 1 3.1.5.1 Verify indicated position 1 3.1.4.2 1 3.1.5.2 Verify indicated position 1 3.1.4.3 1 3.1.5.3 Verify freedom of movement 1 3.1.4.4 1 3.1.5.4 Channel Functional Test 1 3.1.4.5 N/A 3.1.5.5 Verify drop time N/A 3.1.6 Shutdown Control Element Assembly (CEA) Insertion Limits 3.1.5.1 1 3.1.6.1 Verify CEA withdrawn 1
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 2 00 n O n P o V r T $ u r v llla n o e q u e n nte ( ) .. ,'a !1 ...1, JIN .l ... .. ."'*3.1.7 Regulating Control Element Assembly Insertion Limits 3.1.6.1 1 3.1.7.1 Verify CEA group position 1 3.1.6.2 1 3.1.7.2 Verify insertion time within limits 1 3.1.6.3 1 3.1.7.3 Verify Power Dependent Insertion Limit (PDIL) alarm circuit Operable 1 3.1.8 Part Strength Control Element Assembly Insertion Limits 3.1.7.1 1 3.1.8.1 Verify CEA group position 1 3.1.9 Special Test Exception
-Shutdown Margin (SDM)3.1.8.1 1 3.1.9.1 Verify CEA position 1 3.1.8.2 N/A 3.1.9.2 Verify CEA capable of full insertion N/A Not in TSTF 3.1.9.3 Verify Reactor subcritical with CEAs fully inserted 1 X 3.1.10 Special Test Exceptions
-Modes 1 and 2 3.1.9.1 1 3.1.10.1 Verify Thermal Power 1 Not in TSTF 3.1.10.2 Verify CEA position 1 X 3.1.11 Special Test Exceptions
-Reactivity Coefficient Testing Not in TSTF 3.1.11.1 Verify Linear Heat Rate (LHR) and Departure from Nucleate Boiling Ratio N/A (DNBR) do not exceed limits 3.2.1 Linear Heat Rate 3.2.1.1 1 3.2.1.1 Verify LHR within limits 1 3.2.1.2 1 3.2.1.2 Verify the Core Operating Limit Supervisory System (COLSS) margin alarm 1 actuates Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 3.r 1 ,, ,., ,:mir!f! repondlng Palo VerdoTt$ 8urveilllnoeoRdquilement* (SR) , 3.2.2 Planar Radial Peaking Factors (Fxy)3.2.2.1 1 3.2.2.1 Verify measured Fxy 3.2.3 Azimuthal Power Tilt (Tq)3.2.3.1 1 3.2.3.1 Calculate Tq and verify within limit 1 3.2.3.2 1 3.2.3.2 Verify COLSS azimuthal tilt alarm 1 3.2.3.3 1 3.2.3.3 Confirm validity of COLSS calculated Tq 1 3.2.4 Departure From Nucleate Boiling Ratio 3.2.4.1 1 3.2.4.1 Verify DNBR within limit 1 3.2.4.2 1 3.2.4.2 Verify COLSS margin alarm actuates 1 3.2.5 Axial Shape Index (ASI 3.2.5.1 1 3.2.5.1 Verify ASI within limit 1 3.3.1 Reactor Protective System Instrumentation
-Operating 3.3.1.1 1 3.3.1.1 Channel Check 1 3.3.1.2 1 3.3.1.2 Verify Reactor Coolant System (RCS) flow rate 1 3.3.1.3 1 3.3.1.3 Check the Core Protection Calculator (CPC) System Event Log 1 3.3.1.4 1 3.3.1.4 Perform calibration and adjust linear power level signal 1 3.3.1.5 1 3.3.1.5 Verify total RCS flow rate 1 3.3.1.6 1 3.3.1.6 Verify linear power subchannel gains 1 3.3.1.7 1 3.3.1.7 Channel Functional Test 1 3.3.1.8 1 3.3.1.8 Channel Calibration 1 3.3.1.9 1 X ---
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 4!, Sr' ) tfil :r, CorrOeponding Palo Verde TS Surveillance Requirements (SR)4 J 0 :,. ,V ,, , ..*3.3.1.10 1 3.3.1.9 Channel Calibration 1 3.3.1.11 1 3.3.1.10 Channel Functional Test 1 3.3.1.12 N/A 3.3.1.11 Verify shape annealing matrix elements N/A 3.3.1.13 N/A 3.3.1.12 Channel Functional Test N/A 3.3.1.14 1 3.3.1.13 Verify response time within limits 1 3.3.2 Reactor Protective System Instrumentation
-Shutdown 3.3.2.1 1 3.3.2.1 Channel Check 1 3.3.2.2 1 3.3.2.2 Channel Functional Test 1 3.3.2.3 N/A 3.3.2.3 Channel Functional Test N/A 3.3.2.4 1 3.3.2.4 Channel Calibration 1 3.3.2.5 1 3.3.2.5 Verify response time within limits 1 3.3.3 Control Element Assembly Calculators 3.3.3.1 1 3.3.3.1 Channel Check 1 3.3.3.2 1 X 3.3.3.2 (Deleted)
---3.3.3.3 1 3.3.3.3 Channel Functional Test 1 3.3.3.4 1 3.3.3.4 Channel Calibration 1 3.3.3.5 1 3.3.3.5 Channel Functional Test 1 3.3.3.6 1 X 3.3.4 Reactor Protective System Logic and Trip Initiation 3.3.4.2 1 3.3.4.1 Channel Functional Test 1 3.3.4.3 1 3.3.4.2 Channel Functional Test 1 3.3.4.1 1 3.3.4.3 Channel Functional Test 1 3.3.4.4 N/A X ---
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 5 S......, 4tr!e6 OndIng Palo Verde TS 8urve!loance Roqujr'monts
()',, -.3.3.5 Engineered Safety Features Actuation System Instrumentation 3.3.5.1 1 3.3.5.1 Channel Check 1 3.3.5.2 1 3.3.5.2 Channel Functional Test 1 3.3.5.3 1 3.3.5.3 Channel Calibration 1 3.3.5.4 1 3.3.5.4 Verify response time within limits 1 3.3.5.5 N/A 3.3.5.5 Channel Functional Test N/A 3.3.6 Engineered Safety Features Actuation System Logic and Manual Trip 3.3.6.1 1 3.3.6.1 Channel Functional Test 1 3.3.6.2 1 3.3.6.2 Perform subgroup relay test 1 X 3.3.6.3 1 X ---3.3.7 Diesel Generator
-Loss of Voltage Start 3.3.7.1 1 3.3.7.1 Channel Check 1 3.3.7.2 1 3.3.7.2 Channel Functional Test 1 3.3.7.3 1 3.3.7.3 Channel Calibration 1 3.3.8 Containment Purge Isolation Actuation Signal 3.3.8.1 1 3.3.8.1 Channel Check 1 3.3.8.2 1 X ---3.3.8.3 1 3.3.8.2 Channel Functional Test 1 3.3.8.4 1 X ---3.3.8.5 1 3.3.8.3 Channel Functional Test 1 3.3.8.6 1 3.3.8.4 Channel Calibration 1 3.3.8.7 1 X ---
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 6 n,*fr pondlng Palo Verde T$ Survellonme R~qUlrem*nts (M),J S*tNu~b~r' 3.3.8.8 1 3.3.8.5 Channel Functional Test 1 3.3.9 Control Room Essential Filtration Actuation Signal 3.3.9.1 1 3.3.9.1 Channel Check 1 3.3.9.2 1 3.3.9.2 Channel Functional Test 1 3.3.9.3 1 3.3.9.3 Channel Functional Test 1 3.3.9.4 1 3.3.9.4 Channel Calibration 1 3.3.9.5 1 3.3.9.5 Channel Functional Test 1 3.3.9.6 1 3.3.9.6 Verify response time within limits 1 X 3.3.10 Post Accident Monitoring Instrumentation 3.3.11.1 1 3.3.10.1 Channel Check 1 3.3.11.2 1 3.3.10.2 Channel Calibration 1 3.3.11 Remote Shutdown System 3.3.12.1 1 3.3.11.1 Channel Check 1 3.3.12.2 1 3.3.11.2 Verify control circuit and transfer switch capable of performing intended function 1 3.3.12.3 1 3.3.11.3 Channel Calibration 1 3.3.12.4 1 X ---3.3.12 Boron Dilution Alarm System 3.3.13.1 1 3.3.12.1 Channel Check 1 3.3.13.2 1 3.3.12.2 Channel Functional Test 1 3.3.13.3 1 3.3.12.3 Channel Calibration 1 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling Limits Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 7'~~ i. ..1 7* '1;.. .0n# rr,'ondtng0 Palo Verde T$ SurveIllan0e RIeq6lrments ( 3.4.11 3.4.1.1 Verify pressure 1 3.4.1.2 1 3.4.1.2 Verify temperature 1 3.4.1.3 1 3.4.1.3 Verify flow rate 3.4.1.4 1 X 3.4.2 RCS Minimum Temperature for Criticality 3.4.2.1 1 3.4.2.1 Verify temperature 1 X 3.4.3 RCS Pressure and Temperature Limits 3.4.3.1 1 3.4.3.1 Verify pressure, temperature, heatup and cooldown rates 1 3.4.4 RCS Loops -Modes 1 and 2 3.4.4.1 1 3.4.4.1 Verify loops in operation 1 3.4.5 RCS Loops -Mode 3 3.4.5.1 1 3.4.5.1 Verify loop in operation 1 3.4.5.2 1 3.4.5.2 Verify secondary side water level 1 3.4.5.3 1 3.4.5.3 Verify breaker alignment and power available 1 3.4.6 RCS Loops -Mode 4 3.4.6.1 1 3.4.6.1 Verify RCS loop or SDC train in operation 1 3.4.6.2 1 3.4.6.2 Verify secondary side water level 1 3.4.6.3 1 3.4.6.3 Verify breaker alignment and power available 1 3.4.7 RCS Loops -Mode 5, Loops Filled 3.4.7.1 1 3.4.7.1 Verify SDC train in operation 1
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 8 j.Palo V'rde TS Survell"ance R q .r.e.tsO(N)
)3.4.7.2 1 3.4.7.2 Verify secondary side water level 1 __3.4.7.3 1 3.4.7.3 Verify breaker alignment and power available I _____________3.4.8 RCS Loops -Mode 5, Loops Not Filled 3.4.8.1 1 3.4.8.1 Verify SDC train in operation1 3.4.8.2 1 3.4.8.2 Verify breaker alignment and power available I___________3.4.9 Pressurizer 3.4.9.1 1 3.4.9.1 Verify water level 1 __3.4.9.2 1 3.4.9.2 Verify heater capacity 1 3.4.9.3 1 X--____ 3.4.10 Pressurizer Safety Valves -Modes 1, 2 and 3 Not in TSTF ___ 3.4.10.1 Verify safety valve Operable N/A____ 3.4.11 Pressurizer Safety Valves -Mode 4 Not in TSTF __ 3.4.11.1 Verify safety valve Operable N/A Not in TSTF __ 3.4.11.2 Verify SDC relief valve aligned 1 X Not in TSTF ___ 3.4.11.3 Verify SDC relief valve Operable N/A ___ 3.4.12 Pressurizer Vents Not in TSTF __ 3.4.12.1 Cycle Pressurizer Vent Valve 1 X Not in TSTF 3.4.12.2 Verify flow through pressurizer vent path 1 X 13 Low Temperature Overpressure Protection System 3.4.12.1 1 X I---
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 9.r* bt , i Irl, 1ar Cprroponding Palo Verde TS Surveillano Requirement.
($1)4 3.4.12.2 1 X 3.4.12.3 1 X ---3.4.12.4 1 3.4.13.1 Verify RCS vent open 1 Not in TSTF 3.4.13.2 Verify SDC relief valve aligned 1 X Not in TSTF 3.4.13.3 Verify SDC relief valve Operable NIA 3.4.12.5 1 X 3.4.12.6 1 X 3.4.12.7 1 X 3.4.14 RCS Operational Leakage 3.4.13.1 1 3.4.14.1 Perform RCS water inventory balance 1 3.4.13.2 1 3.4.14.2 Verify primary to secondary leakage 1 3.4.15 RCS Pressure Isolation Valve (PIV) Leakage 3.4.14.1 1 3.4.15.1 Verify leakage from PIV 1 3.4.14.2 1 3.4.15.2 Verify SDC interlock 1 3.4.14.3 1 X ---3.4.16 RCS Leakage Detection Instrumentation 3.4.15.1 1 3.4.16.1 Channel Check 1 3.4.15.2 1 3.4.16.2 Channel Functional Test 1 3.4.15.3 1 3.4.16.3 Channel Calibration 1 3.4.15.4 1 3.4.16.4 Channel Calibration 1 3.4.15.5 1 X___________
___ ___3.4.17 RCS Specific Activity __
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 10 ,~~4~2 8 I J si~i~r c~rrePonding Palo Vrde TS $UrveilIonos ReqUiremnt(S
'3.4.16.1 1 3.4.17.1 Verify gross specific activity 3.4.16.2 1 3.4.17.2 Verify Dose Equivalent 1-131 1 3.4.16.3 1 3.4.17.3 Determine E-BAR 1 3.4.18 Steam Generator Tube Integrit Not in TSTF 3.4.18.1 Verif tube integrity N/A Not in TSTF 3.4.18.2 Verif tubes plugged N/A 3.5.1 Safet Injection Tanks -0perating 3.5.1.1 SITs 1 3.5.1.1 Verif valve open 1 3.5.1.2 SITs 1 3.5.1.2 Verif borated water volume 1 3.5.1.3 SITs 1 3.5.1.3 Verif nitrogen cover pressure 1 3.5.1.4 SITs 1 3.5.1.4 Verif boron concentration 1 3.5.1.5 SITs 1 3.5.1.5 Verif power removed from valve operator 1 3.5.2 Safet Injection Tanks -Shutdown Not in TSTF 3.5.2.1 Verif valve open 1 X Not in TSTF 3.5.2.2 Verif borated water volume 1 X Not in TSTF 3.5.2.3 Verif nitrogen cover pressure 1 X Not in TSTF 3.5.2.4 Verif boron concentration 1 X Not in TSTF 3.5.2.5 Verif power removed from valve operator 1 X 3.5.3 Emergency Core Cooling Systems -0perating 3.5.2.1 1 X--3.5.2.2 1 3.5.3.1 Verif valve position 1 3.5.2.3 1 3.5.3.2 Verifiy piing full 1 Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 11.I... ...rospondlng Polo Verde T8 Survellance Requirements.(.R)
., 3.5.2.4 N/A __3.5.3.3 Verify pump differential pressure N/A 3.5.2.5 N/A X--3.5.2.6 1 3.5.3.4 Verify valve actuation 1 __3.5.2.7 1 _ 3.5.3.5 Verify pump starts 1 3.5.2.8 1 3.5.3.6 Verify pump stops 1 __3.5.2.9 1 3.5.3.7 Verify throttle valve position 1 3.5.2.10 1 3.5.3.8 Verify flow path not obstructed 1__3.5.4 Emergency Core Cooling Systems -Shutdown Not in TSTF 3.5.4.1 Surveillance Requirements are applicable N/A 3.5.5 Refueling Water Tank 3.5.4.1 1 3.5.5.1 Verify water temperature 1 3.5.4.2 1 3.5.5.2 Verify borated water volume 1 3.5.4.3 1 3.5.5.3 Verify boron concentration 1 3.5.6 Trisodium Phosphate (TSP)3.5.5.1 1 3.5.6.1 Verify baskets contain TSP 1 3.5.5.2 1 3.5.6.2 Verify TSP provides adequate pH adjustment 1 3.6.1 Containment Not in TSTF 3.6.1.1 Perform leakage rate testing N/A Not in TSTF 3.6.1.2 Verify containment integrity N/A 3.5.2.4N/A
....... .33.6.2 Containm ent Air Locks 3.6.2.1 N/A 3.6.2.1 Perform leakage rate testing N/A Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 12 I J t:lUlr Qo ll00ndcng Palo Verd itS urveilianoe 0 (R 3.6.2.2 1 3.6.2.2 Verif door operation1 3.6.3 Containment Isolation Valves 3.6.3.1 1 3.6.3.1 Verif valve position 1 3.6.3.2 1 3.6.3.3 Verif valve position 1 3.6.3.3 1 3.6.3.3 Verif valve position 1 3.6.3.4 N/A 3.6.3.4 Verif valve position N/A 3.6.3.5 1 3.6.3.5 Verif valve isolation time N/A 3.6.3.6 1 3.6.3.6 Perform leakae rate testing i 3.6.3.7 1 3.6.3.7 Verify valve actuation 1 3.6.3.8 1 X 3.6.3.9 N/A X 3.6.4 Containment Pressure 3.6.4A.1 1 3.6.4.1 Verify ressure within limits 1 3.6.5 Containment Air Ten erature 3.6.5.1 1 3.6.5.1 Verify tererature within limit 1 3.6.6 Containment S ray 3.6.6A.1 1 3.6.6.1 Verify valve position 1 3.6.6A.2 X 3.6.6A.3 1 X 3.6.6A.4 1 3.6.6.2 Verify piping full 1 3.6.6A.5 N/A 3.6.6.3 Verify ump ressure N/A 3.6.6A.6 1 3.6.6.4 Verify valve actuation 1
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 13.. In~I1taC6r*sponding Palo Verde TS Surveillance Requlrements (1R), 3.6.6A.7 1 3.6.6.5 Verify pump starts 1 3.6.6A.8 1 X 3.6.6A.9 1 3.6.6.6 Verify spray nozzle not obstructed 3.7.1 Main Steam Safety Valves Not in TSTF 3.7.,1.1 Verify lift setpoint N/A 3.7.2 Main Steam Isolation Valves 3.7.2.1 N/A 3.7.2.1 Verify valve isolation time N/A 3.7.2.2 1 X ---3.7.3 Main Feedwater Isolation Valves 3.7.3.1 N/A 3.7.3.1 Verify valve isolation time N/A 3.7.3.2 1 X ---3.7.4 Atmospheric Dump Valves 3.7.4.1 1 3.7.4.1 Cycle valves 1 3.7.4.2 1 X ---3.7.5 Auxiliary Feedwater System 3.7.5.1 1 3.7.5.1 Verify valve position 1 3.7.5.2 N/A 3.7.5.2 Verify pump pressure N/A 3.7.5.3 1 3.7.5.3 Verify valve actuation 1 3.7.5.4 1 3.7.5.4 Verify pump starts 1 3.7.5.5 N/A 3.7.5.5 Verify water flow N/A__ _ [ 1_ II 1i Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 14'0irnu r rp ndln Palo Verd' :S SurvelIInce Roqulrisnts
(,,),, J 3.7.6 Condensate Storage Tank 3.7.6.1 1 3.7.6.1 Verify level 1 3.7.7 Essential Cooling Water System 3.7.7.1 1 _ 3.7.7.1 Verify valve position 1 3.7.7.2 1 3.7.7.2 Verify valve actuation 1 3.7.7.3 1 3.7.7.3 Verify pump starts 1 3.7.8 Essential Spray Pond System 3.7.8.1 1 3.7.8.1 Verify valve position 1 3.7.8.2 1 X--3.7.8.3 1 3.7.8.2 Verify pump starts 1 3.7.9 Ultimate Heat Sink 3.7.9.1 1 3.7.9.1 Verify water depth 1 __3.7.9.2 1 3.7.9.2 Verify water temperature 1 3.7.9.3 1 X--3.7.10 Essential Chilled Water System 3.7.10.1 1 3.7.10.1 Verify valve position 1 __3.7.10.2 1 3.7.10.2 Verify system component actuation 1 3.7.11 Control Room Essential Filtration System 3.7.11.1 1 3.7.11.1 Operate each train 1 3.7.11.2 N/A __3.7.11.2 Perform filter testing N/A __3.7.11.3 1 __3.7.11.3 Verify train actuation 1 __
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 15 OW.. .. Ciortespondlng Palo Verde TS Surveillanoe Requiroents (M)4 .T 3.7.11.4 1 X ---Not in TSTF 3.7.11.4 Perform air inleakage testing N/A 3.7.12 Control Room Emergency Air Temperature Control System 3.7.12.1 1 3.7.12.1 Verify train capability 1 3.7.13 Engineered Safety Feature Pump Room Exhaust Air Cleanup System 3.7.13.1 1 3.7.13.1 Operate each train 1 3.7.13.2 N/A 3.7.13.2 Perform filter testing N/A 3.7.13.3 1 3.7.13.3 Verify train actuation 1 3.7.13.4 1 3.7.13.4 Verify train capability 1 3.7.13.5 1 X 3.7.14 Fuel Storage Pool Water Level 3.7.16.1 1 3.7.14.1 Verify water level 1 3.7.15 Fuel Storage Pool Boron Concentration 3.7.17.1 1 3.7.15.1 Verify boron concentration 1 3.7.16 Secondary Specific Activity 3.7.19.1 1 3.7.16.1 Verify specific activity 1 3.7.17 Spent Fuel Assembly Storage Not in TSTF 3.7.17.1 Verify enrichment, burnup, and decay time N/A 3.8.1 AC Sources -Operating Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 16 Tip 4.. ,, it1.
Palo Verde TS (SR)3.8.1.1 1 3.8.1.1 Verify breaker alignment 1 3.8.1.2 1 3.8.1.2 Verify Diesel Generator (DG) starts from standby conditions 1 3.8.1.3 1 3.8.1.3 Verify DG synchronized and loaded 1 3.8.1.4 1 3.8.1.4 Verify day tank level 1 3.8.1.5 1 3.8.1.5 Remove accumulated water from day tank 1 3.8.1.6 1 3.8.1.6 Verify fuel oil transfer system operation 1 3.8.1.7 1 3.8.1.7 Verify DG starts from standby conditions 1 3.8.1.8 1 3.8.1.8 Verify transfer of power from normal offsite circuit to alternate offsite circuit 1 3.8.1.9 1 3.8.1.9 Verify DG load rejection 1 3.8.1.10 1 3.8.1.10 Verify DG maintains load following load reject 1 3.8.1.11 1 3.8.1.11 Verify equipment operation on loss of offsite power 1 3.8.1.12 1 3.8.1.12 Verify equipment operation on Engineered Safety Feature (ESF) signal 1 3.8.1.13 1 3.8.1.13 Verify automatic trips bypassed on ESF signal 1 3.8.1.14 1 3.8.1.14 Verify DG operates for > 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 1 3.8.1.15 1 3.8.1.15 Verify DG starts and operates 1 3.8.1.16 1 3.8.1.16 Verify DG synchronizes with offsite power 1 3.8.1.17 1 3.8.1.17 Verify ESF signal overides test mode 1 3.8.1.18 1 3.8.1.18 Verify interval between each timed load block 1 3.8.1.19 1 3.8.1.19 Verify equipment operation on loss of offsite power in conjunction with ESF 1 signal 3.8.1.20 1 3.8.1.20 Verify simultanious DG starts and operates 1 3.8.2 AC Sources -Shutdown Not in TSTF 3.8.2.1 Surveillance Requirements are applicable N/A 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 17n410,110r 0Orrospondlng Palo Vorde TS Survelllanco Requlrements
)4 , 3.8.3.1 1 3.8.3.1 Verify tank level 1 3.8.3.2 1 3.8.3.2 Verify lubricating oil inventory 1 3.8.3.3 N/A 3.8.3.3 Verify fuel oil properties N/A 3.8.3.4 1 3.8.3.4 Verify starting air receiver pressure 1 3.8.3.5 1 3.8.3.5 Remove accumulated water from storage tank 1 3.8.4 DC Sources -Operating 3.8.4.1 1 3.8.4.1 Verify battery terminal voltage 1 Not in TSTF 3.8.4.2 Verify no visible corrosion 1 X Not in TSTF 3.8.4.3 Verify no visual physical damage 1 X Not in TSTF 3.8.4.4 Remove visible terminal corrosion 1 X Not in TSTF 3.8.4.5 Verify connection resistance 1 X 3.8.4.2 1 3.8.4.6 Verify battery chargers supply amperage 1 3.8.4.3 1 3.8.4.7 Verify battery capacity (service test) 1 Not in TSTF 3.8.4.8 Verify battery capacity (discharge test) 1 X 3.8.5 DC Sources -Shutdown Not in TSTF 3.8.5.1 Surveillance Requirements are applicable N/A 3.8.6 Battery Cell Parameters Not in TSTF 3.8.6.1 Verify battery pilot cell parameters 1 X Not in TSTF 3.8.6.2 Verify battery connected cell parameters 1 X 3.8.6.1 1 X ---3.8.6.2 1 X ---3.8.6.3 1 X ---3.8.6.4 1 3.8.6.3 Verify electrolyte temperature 1
Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 18....... i ll 'l ~l:" i il]':' E: : ~ 4on~apOndlng Palo Verde TBt Surveillanoc ReqiremI ne (i t) J i] .... i: o_ R:", I.". , "v I ,1, ,",I' :,1: i1,,,I: ..,
- a T S S r lh "1,A ,~ ~,. I , , ,, , * ý0 , pn,,, P a ,, ....3.8.6.5 1 X ---3.8.6.6 1 X 3.8.7 Inverters
-Operating 3.8.7.1 1 3.8.7.1 Verify inverter voltage, frequency, and alignment 1 3.8.8 Inverters
-Shutdown 3.8.8.1 1 3.8.8.1 Verify inverter voltage, frequency, and alignment 1 3.8.9 Distribution Systems -Operating 3.8.9.1 1 3.8.9.1 Verify breaker alignment and voltage to distribution subsystems 1 3.8.10 Distribution Systems -Shutdown 3.8.10.1 1 3.8.10.1 Verify breaker alignment and voltage to distribution subsystems 1 3.9.1 Boron Concentration 3.9.1.1 1 3.9.1.1 Verify boron concentration 3.9.2 Nuclear Instrumentation 3.9.2.1 1 3.9.2.1 Channel Check 1 3.9.2.2 1 3.9.2.2 Channel Calibration 1 3.9.3 Containment Penetrations 3.9.3.1 1 3.9.3.1 Verify containment penetration in required status 1 3.9.3.2 1 3.9.3.2 Verify valve actuation 1 Not in TSTF 3.9.3.3 Verify capability to close equipment hatch 1 X Attachment 7 TSTF-425 (NUREG-1432) vs. Palo Verde TS Cross Reference Request for Adoption of TSTF 425, Rev. 3 Page 19 6s~s~on ing Ow' OVo Vrde To$Surve It~~ 00! ri~nt f 3.9.4 Shutdown Cooling and Coolant Circulation
-High Water Level 3.9.4.1 1 3.9.4.1 Verif laoo operable 1 3.9.5 Shutdown Cooling and Coolant Circulation
-Low Water Level 3.9.5.1 1 3.9.5.1 Verif loop operable 1 3.9.5.2 1 3.9.5.2 Verif breaker alignment and ower available 1 3.9.6 Refueling Water Level -Fuel Assemblies 3.9.6.1 1 3.9.6.1 Verif water level 1 3.9.7 Refueling Water Level -CEAs Not in TSTF 3.9.7.1 Verify water level 1 X Notes 1 .TSTF 425 SR Number -A list of the surveillance requirements provided in the TSTF for change.2. Insert -"1l" is provided in this column where standard insert wording is being used for the surveillance requirement being relocated, --"is provided where the surveillance requirement does not exist, and "N/A" is provided where no change is proposed because the surveillance requirement is event driven, conditional, or controlled by another approved program and therefore not a candidate for relocation.