Text

License Amendment Request for Adoption of TSTF-425-A, Revision 3, Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program Using the Consolidated..
	ML103140605
Person / Time
Site:	Farley
Issue date:	10/29/2010
From:	Ajluni M J; Southern Nuclear Operating Co
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	NL-10-0272
	Download: ML103140605 (419)
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Mark J. Ajiluni, P.E. Southern Nuclear Nuclear Licensing Director Operating Company, Inc.40 Inverness Center Parkway Post Office Box 1295 Birmingham, Alabama 35201 Tel 205.992.7673 Fax 205.992.7885 October 29, 2010 SOUTHERN COMPANY Docket Nos.:, 50-348 50-364 NL-10-0272 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, D. C. 20555-0001 Joseph M. Farley Nuclear Plant License Amendment Request for Adoption of TSTF-425-A, Revision 3, Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program Usincq the Consolidated Line Item Improvement Process Ladies and Gentlemen:

In accordance with the provisions of 10 CFR 50.90 of Title 10 of the Code of Federal Regulations (10 CFR), Southern Nuclear Operating Company (SNC) is submitting a request for an amendment to the Technical Specifications (TS) for the Joseph M. Farley Nuclear Plant (FNP).The proposed amendment would modify the FNP TS by relocating specific surveillance frequencies to a licensee-controlled program with the implementation of Nuclear Energy Institute (NEI) 04-10, Rev.1 "Risk-Informed Technical Specification Initiative 5B, Risk-Informed Method for Control of Surveillance Frequencies." The availability of this TS improvement was announced in the Federal Register on July 6, 2009 (74 FR 31996) as part of the consolidated line item improvement process (CLIIP).Enclosure 1 provides the basis for the proposed changes to the FNP TS, the requested confirmation of applicability, and the plant specific verifications.

Enclosure 2 provides Documentation of PRA Technical Adequacy.

Enclosure 3 provides the existing FNP TS pages marked-up to show the proposed changes for FNP. Enclosure 4 provides the clean typed proposed FNP TS pages.Enclosure 5 provides the proposed TS Bases changes for FNP. Enclosure 6 provides a cross reference between the FNP TS and the TSTF 425 Marked-up pages.SNC requests approval of the proposed license amendment by April 29, 2011 with the amendment being implemented within 120 days of receipt of amendment.

Aool U. S. Nuclear Regulatory Commission NL-10-0272 Page 2 In accordance with 10 CFR 50.91, "Notice for Public Comment; State Consultation," a copy of this application, with enclosures, is being provided to the appropriate designated Alabama Officials.

This letter contains no NRC commitments.

If you have any questions, please contact N. J. Stringfellow at (205) 992-7037.Mr. M. J. Ajluni states he is the Nuclear Licensing Director of Southern Nuclear Operating Company, is authorized to execute this oath on behalf of Southern Nuclear Operating Company and to the best of his knowledge and belief, the facts set forth in this letter are true.Respectfully submitted, M. J. Ajluni Nuclear Licensing Director Sworn to and subscribed before me this 2t day of 0 Qc- , , 2010.o~tary Public My commission expires:

Enclosures:

1. Basis of Proposed Change 2. Documentation of PRA Technical Accuracy 3. Markup for FNP Proposed TS Changes 4. Clean Typed Pages for FNP Proposed TS Changes 5. Markup for FNP Proposed TS Bases Changes 6. Technical Specification Cross Reference for FNP and TSTF 425 Mark ups cc: Southern Nuclear Operating Company Mr. J. T. Gasser, Executive Vice President Mr. J. R. Johnson, Vice President

-Farley Ms. P. M. Marino, Vice President

-Engineering RType: CFA04.054 U. S. Nuclear Regulatory Commission Mr. L. A. Reyes, Regional Administrator Mr. R. E. Martin, NRR Project Manager -Farley Mr. E. L. Crowe, Senior Resident Inspector

-Farley Mr. P. Boyle, NRR Project Manager -Farley Alabama Department of Public Health Dr. D. E. Williamson, State Health Officer Joseph M. Farley Nuclear Plant License Amendment Request for Adoption of TSTF-425-A, Revision 3, Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program Using the Consolidated Line Item Improvement Process Enclosure 1 Basis for Proposed Change Enclosure 1 Basis for Proposed Change Table of Contents 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 No Significant Hazards Consideration Determination

4.0 Environmental

Evaluation Enclosure 1 Basis for Proposed Change 1.0 Description The proposed change would modify the Joseph M. Farley Nuclear Plant (FNP)Technical Specifications (TS) by relocating specific surveillance frequencies to a licensee-controlled program with the adoption of Technical Specification Task Force (TSTF)-425, Revision 3, "Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Risk Informed Technical Specification Task Force (RITSTF) Initiative 5)." Additionally, the change would add a new program, the Surveillance Frequency Control Program, to the FNP TS Section 5, Administrative Controls.

The changes are consistent with NRC approved Industry/TSTF STS change TSTF-425, Revision 3, (ADAMS Accession No. ML080280275).

The Federal Register notice published on July 6, 2009 announced the availability of this TS improvement.

2.0 Assessment

2.1 Applicability

of Published Safety Evaluation Southern Nuclear Operating Company (SNC) has reviewed the safety evaluation dated July 6, 2009 as part of the consolidated line item improvement process (CLIIP). This review included a review of the NRC staff's evaluation, TSTF-425, Revision 3, and the requirements specified in NEI 04-10, Rev. 1, (ADAMS Accession No. ML071360456).

SNC has concluded that the justifications presented in the TSTF and the Safety Evaluation, prepared by the NRC staff, are applicable to Units 1 and 2 of FNP and justify this amendment for the incorporation of changes to the TS for Units 1 and 2 of FNP.Enclosure 2 includes SNC documentation with regard to PRA technical adequacy consistent with the requirements of Regulatory Guide 1.200, Revision 2 (ADAMS Accession No. ML070240001), 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 1.200.2.2 Optional Changes and Variations The proposed amendment is consistent with the Standard TS changes described in TSTF-425, Revision 3; however, SNC proposes the following variations or deviations from TSTF-425: NRC letter dated April 14, 2010 provides a change to an optional insert (INSERT #2) to the existing TS Bases to facilitate adoption of the Traveler while retaining the existing NUREG TS surveillance frequency (SF) Bases considerations for licensees not choosing to adopt TSTF-425.

The TSTF-425 TS Bases insert states as follows: El -2 Enclosure 1 Basis for Proposed Change 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 (LARs) 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. 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.To resolve this issue with existing LARs 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 (April 28, 2010 discussion between the TSTF and the NRC): 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.SNC has incorporated these recommended changes into this License Amendment Request.Enclosure 6 provides a cross-reference between the NUREG-1431 Surveillance Requirements (SRs) included in TSTF-425 versus the FNP TS. This Enclosure includes a summary description of the referenced TSTF-425/FNP TS SRs which is being provided for information purposes only and is not intended to be a verbatim description of the TS SRs. This cross-reference highlights the following:

El -3 Enclosure 1 Basis for Proposed Change 1. SRs included in TSTF-425 and corresponding FNP SRs with identical SR numbers;2. SRs included in TSTF-425 and corresponding FNP SRs with differing SR numbers;3. SRs included in TSTF-425 that are not contained in the FNP TS; and 4. FNP plant-specific SRs that are not contained in the TSTF-425 mark-ups.Concerning the above, FNP SRs that have SR numbers identical to the corresponding TSTF-425 SRs are not deviations from TSTF-425. FNP SRs with SR numbers that differ from the corresponding TSTF-425 SRs are administrative deviations from TSTF-425 with no impact on the NRC's model safety evaluation dated July 6, 2009 (74 FR 31996).For TSTF-425 SRs that are not contained in the FNP TS, the corresponding mark-ups included in TSTF-425 for these SRs are not applicable to FNP. This is an administrative deviation from TSTF-425 with no impact on the NRC's model safety evaluation dated July 6, 2009 (74 FR 31996).For FNP plant-specific SRs that are not contained in the mark-ups provided in TSTF-425, SNC has determined that the relocation of the Frequencies for these FNP plant-specific SRs is consistent with the intent of TSTF-425, Revision 3, and with the NRC's model safety evaluation dated July 6, 2009 (74 FR 31996), including the scope exclusions identified in Section 1.0, "Introduction," of the model safety evaluation, because the subject plant-specific SRs involve fixed periodic Frequencies.

In accordance with TSTF-425, changes to the Frequencies for these SRs would be controlled under the Surveillance Frequency Control Program. The Surveillance Frequency Control Program provides the necessary administrative controls to require that SRs related to testing, calibration and inspection are conducted at a frequency to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met. Changes to Frequencies in the Surveillance Frequency Control Program would be evaluated using the NRC approved methodology and probabilistic risk guidelines contained in NEI 04-10, Revision 1.E1-4 Enclosure 1 Basis for Proposed Change 3.0 Regulatory Analysis 3.1 No Significant Hazards Consideration SNC has reviewed the proposed no significant hazards consideration determination (NSHCD) published in the Federal Register dated July 6, 2009 (74 FR 31996) as part of the CLIIP. SNC has concluded that the proposed NSHCD presented in the Federal Register notice is applicable to Units 1 and 2 of FNP and the evaluation is hereby incorporated by reference to satisfy the requirements of 10 CFR 50.91 (a) for this application.

4.0 Environmental

Evaluation SNC has reviewed the environmental evaluation included in the model safety evaluation dated July 6, 2009 (74 FR 31996) as part of the CLIIP. SNC has concluded that the staff's findings presented in the published evaluation are applicable to Units 1 and 2 of FNP and the evaluation is hereby incorporated by reference for this application.

El -5 Joseph M. Farley Nuclear Plant License Amendment Request for Adoption of TSTF-425-A, Revision 3, Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program Using the Consolidated Line Item Improvement Process Enclosure 2 Documentation of PRA Technical Adequacy Enclosure 2 Documentation of PRA Technical Adequacy Table of Contents 1.0 Introduction

2.0 Technical

Adequacy of FNP PRA Model 2.1 PRA Model for As-Built As-Operated FNP 2.1.1 PRA Maintenance and Update 2.1.2 Plant Changes Not Yet Incorporated into the PRA Model 2.2 Consistency with Applicable ASME PRA Standards 2.2.1 Previous Peer Review and Self Assessments for FNP PRA Model 2.2.2 RG 1.200 PRA Peer Review for FNP PRA against ASME PRA Standard Requirements

2.2.3 Resolutions

of Findings from RG 1.200 PRA Peer Review 2.3 Identification of Key Assumptions

3.0 External

Event Considerations

4.0 General

Conclusion Regarding PRA Capability

5.0 References

Enclosure 2 Documentation of PRA Technical Adequacy 1.0 Introduction SNC employs a multi-faceted approach to establishing and maintaining the technical adequacy and plant fidelity of the PRA models for all operating SNC nuclear generation sites. This approach includes both a proceduralized PRA maintenance and an update process, and the use of self-assessments and independent peer reviews. The following information describes this approach as it applies to the FNP PRA.2.0 Technical Adequacy of FNP PRA Model 2.1 PRA Model for As-Built As-Operated FNP 2.1.1 PRA Maintenance and Update The SNC risk management process ensures that the applicable PRA model remains an accurate reflection of the as-built and as-operated units. The SNC risk management process also delineates the responsibilities and guidelines for updating the full power internal events PRA models at all operating SNC nuclear generation sites.The overall SNC risk management program defines the process for implementing regularly scheduled and interim PRA model updates, for tracking issues identified as potentially affecting the PRA models (e.g., due to changes in the plant, errors or limitations identified in the model, industry operational experience), and for controlling the model and associated computer files. To ensure that the current PRA model remains an accurate reflection of the as-built, as-operated plant, the FNP PRA model has been updated according to the requirements defined in the SNC risk management process: Pertinent modifications to the physical plant (i.e. those potentially affecting the Base Line PRA (BL-PRA) models, calculated core damage frequencies (CDFs), or large early release frequencies (LERFs) to a significant degree) shall be reviewed to determine the scope and necessity of a revision to the baseline model within six months following either a periodic refueling outage on Unit 1 or a specific major plant modification occurring outside a refueling outage. The BL-PRAs should be updated as necessary in accordance with a schedule approved by the PRA Manager following the scoping review. Upon completion of the lead Unit's BL-PRA, the other Unit's BL-PRA will be regenerated by modification of the updated BL-PRAs to account for Unit differences which significantly impact the results.E2-2 Enclosure 2 Documentation of PRA Technical Adequacy* Pertinent modifications to plant procedures and Technical Specifications shall be reviewed annually for changes which are of statistical significance to the results of the BL-PRA and those changes documented.

Reliability data, failure data, initiating events frequency data, human reliability data, and other such PRA inputs shall be reviewed approximately every three years for statistical significance to the results of the BL-PRAs. Following the tri-annual review, the BL-PRAs shall be updated to account for the significant changes to these two categories of PRA inputs in accordance with an approved schedule." BL-PRAs shall be updated to reflect germane changes in methodology, phenomenology, and regulation as judged to be prudent by the PRA custodian or as required by regulation.

In addition to these activities, SNC risk management procedures provide the guidance for particular risk management and PRA quality and maintenance activities.

This guidance includes:* Documentation of the PRA model, PRA products, and bases documents.

The approach for controlling electronic storage of Risk Management (RM) products including PRA update information, PRA models, and PRA applications.

Guidelines for updating the full power, internal events PRA models for SNC nuclear generation sites.* Guidance for use of quantitative and qualitative risk models in support of the On-Line Work Control Process Program for risk evaluations for maintenance tasks (corrective maintenance, preventive maintenance, minor maintenance, surveillance tests and modifications) on systems, structures, and components (SSCs) within the scope of the Maintenance Rule (10 CFR 50.65 (a)(4)).In accordance with this guidance, regularly scheduled PRA model updates nominally occur on an approximate three year cycle;however, longer intervals may be justified if it can be shown that the PRA continues to adequately represent the as-built, as-operated plant. Table 1 shows the brief history of the major FNP PRA model updates.E2-3 Enclosure 2 Documentation of PRA Technical Adequacy 2.1.2 Plant Changes Not Yet Incorporated into the PRA Model As part of the PRA evaluation for each Surveillance Test Interval (STI), based on a Surveillance Frequency change request, an evaluation will be performed by the PRA Department, to assess the impact, if any, of any plants changes which are not incorporated into the FNP PRA model which is used for providing risk information/insights prior to presenting the results of the risk analysis to the Integrated Decision-making Panel (IDP). If non-trivial impact is expected, then this may include the performance of additional sensitivity studies or PRA model changes to confirm the impact on the risk analysis.E2-4 Enclosure 2 Documentation of PRA Technical Adequacy Table 1 -CDF and LERF by Revision for Unit 1 (Unit 2)Revision Unit 1 (Unit 2) CDF Unit 1 (Unit 2) LERF Major changes from previous revision per reactor year per reactor year 0 (IPE) 1.30E-04 4.47E-07 N/A 1 (12/1997) 7.63E-05 (7.49E-05) 6.29E-07 (6.29E-07) e Conversion of model from large event tree to linked fault tree using CAFTA 0 Developed unit-specific models for Unit 1 and Unit 2 to support EOOS* Incorporated plant design changes completed since the IPE 2 (05/1998) 8.72E-05 (8.65E-05) 5.50E-07 (5.50E-07)

Revised RCP seal LOCA modeling 0 Revised SBO modeling* Revised ATWS modeling to ensure proper application of UET* Changed mission time for AFW to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for general transient initiating events* Refined modeling of swing components to ensure all failure modes are addressed where train re-alignment is credited 0 Revised LERF modeling to use LERF definition developed by the WOG Risk Based Technologies Working Group* Incorporated plant design changes completed since previous revision E2-5 Enclosure 2 Documentation of PRA Technical Adequacy Table 1 -CDF and LERF by Revision for Unit 1 (Unit 2)Revision Unit 1 (Unit 2) CDF Unit 1 (Unit 2) LERF Major changes from previous revision per reactor year per reactor year 3 (08/1999) 6.52E-05 (6.45E-05) 4.50E-07 (4.50E-07) 0 Updated component reliability data to include plant experience through 12/31/97* Updated initiating event frequencies using NUREG/CR-5750 generic data and plant experience through 12/31/97* Incorporated design changes for the instrument air system" Expanded modeling of the service water intake structure and turbine building DC systems to include alternate battery chargers and battery banks to support EOOS assessments" Revised SBO modeling to include SBO sequences in the fault tree rather than adding offsite power recovery during post-processing

Revised the ATWT modeling to ensure the proper success criteria for AFW are applied to the various cases" Added Very Small LOCA event tree E2-6 Enclosure 2 Documentation of PRA Technical Adequacy Table 1 -CDF and LERF by Revision for Unit 1 (Unit 2)Revision Unit 1 (Unit 2) CDF Unit 1 (Unit 2) LERF Major changes from previous revision per reactor year per reactor year 4 (05/2000) 5.57E-05 (6.91 E-05) 4.47E-07 (4.53E-07)

Revised HRA for events where procedures had changed* Updated flooding analysis for the Service Water Intake Structure and CCW pump/HX rooms 0 Added System Model for emergency air compressors for atmospheric relief valves and AFW pumps* Added Unit 2 SW lube and cooling booster pumps* Incorporated plant design changes completed since previous revision 5 (11/2001) 3.86E-05 (5.81 E-05) 4.19E-07 (4.26E-07) 0 Revised model to address WOG Peer Review comments* Incorporated plant design changes completed since previous revision 6 (03/2005) 3.79E-05 (3.32E-05) 4.94E-07 (4.92E-07) 0 Incorporated plant design changes through December 2004* Revised SGTR Event Tree* Updated CCF Analysis 0 Updated HRA 0 Updated component reliability, unavailability and initiating event data with plant experience through December 2001 E2-7 Enclosure 2 Documentation of PRA Technical Adequacy Table 1 -CDF and LERF by Revision for Unit 1 (Unit 2)Revision Unit 1 (Unit 2) CDF Unit 1 (Unit 2) LERF Major changes from previous revision per reactor year per reactor year 7 (06/2006) 2.35E-05 (2.03E-05) 5.11 E-07 (5.06E-07)

Revised SW success criteria for diesel generator support* Revised LERF model to incorporate induced SGTR* Revised modeling of maintenance on CCW and Charging pumps to incorporate current plant practice of minimizing at-power train maintenance outages utilizing swing pumps" Revised pipe rupture frequencies for internal flooding per EPRI TR-1013141

Revised modeling of SW Pump 2D to reflect design changes completed following Revision 6" Revised event tree for Secondary Side Break initiating events E2-8 Enclosure 2 Documentation of PRA Technical Adequacy Table 1 -CDF and LERF by Revision for Unit 1 (Unit 2)Revision Unit 1 (Unit 2) CDF Unit 1 (Unit 2) LERF Major changes from previous revision per reactor year per reactor year 8 (06/2008) 1.87E-05(1.54E-05) 5.05E-07(5.00E-07) 0 Incorporates removal of final Unit 2 SW Booster Pump* Revised requirements for Unit 2 SW Pumps such that cyclone separator is no longer required 0 Revised operating alignment in which RCP Seal Injection and RCP Thermal Barrier Cooling are supplied by opposite trains (This eliminates a single train CCW, SW, or Electrical Bus initiating event for causing a total loss of RCP Seal cooling)* 20% CDF reduction for Unit 1 and 24% CDF reduction for Unit 2 9(10/2010) 2.28E-5 1.40E-07 0 Upgrade per RG 1.200 Revision 2* Incorporated RCP Shutdown Seals 0 Added Internal Flooding* Restructured Event Trees E2-9 Enclosure 2 Documentation of PRA Technical Adequacy 2.2 Consistency with Applicable ASME PRA Standard Requirements

2.2.1 Previous

peer review and Self Assessment for FNP PRA Model Several assessments of technical capability have been made for the FNP PRA models. These assessments are as follows and further discussed in the paragraphs below:* An independent PRA peer review was conducted under the auspices of the Westinghouse Owners Group (WOG) in 2001 (Reference 1), following the Industry PRA Peer Review process (Reference 2). This peer review included an assessment of the PRA model maintenance and update process.* In 2005, a gap analysis (Reference

3) was performed against the available version of the ASME PRA Standard (Reference

4) and Regulatory Guide 1.200.2.2.2. RG 1.200 PRA Peer Review for FNP PRA Model against ASME PRA Standard Requirements A complete Peer Review of the FNP Probabilistic Risk Assessment (PRA) against the requirements of Section 2 of the ASME/American Nuclear Society (ANS) Combined PRA standard (Reference

5) and the requirements of Regulatory Guide (RG) 1.200, Revision 2 (Reference 6)was completed in March 2010. This peer review was performed using the process defined in Nuclear Energy Institute (NEI) 05-04 (Reference 7).1. The ASME PRA Standard (Reference

5) contains a total of 326 numbered supporting requirements in 14 technical elements and the configuration control element. Of the 326 SRs, eight were determined to be not applicable to the FNP PRA. There were eight not applicable requirements for the FNP review: AS-B4, SY-A9, HR-C3, HR-D5, DA-C5, DA-C8, DA-C15, and DA-D2.2. Among 318 applicable SRs, 92% of SRs met Capability Category II or higher as follows: E2-10 Enclosure 2 Documentation of PRA Technical Adequacy yMet No. of SRs % of total applicable Capability Category MeSN. fs~SRs CC-I/Il/Ill (or SR 213 65%Met)CCI 9 3%CC II 30 9%CC III 12 4%cc 1/11 13 4%CC 1I/111 24 7%SR Not Met 17 5%SR Not Applicable 8 3%Total 326 100%2.2.3 Resolution of Findings from RG 1.200 PRA Peer Review The final report has been issued. Table 2 provides a summary of the resolution of the FNP Peer Review not-met CAT II SRs.E2-1 1 Enclosure 2 Documentation of PRA Technical Adequacy Table 2 Resolution of the FNP PRA Peer Review F&Os for Not-Met CAT II SRs Review F&O # Finding Resolution The Status of Resolution by SNC Element IE-A5 IE-A5-01 The system notebooks look at Add a systematic review of A systematic review of the FNP safety and (SR CCI) the impact of the identified the safety and non-safety non-safety systems was performed that met CCI initiators on that system. systems that could cause a resulted in the development of a Table C-1 However, a system by system plant scram to verify that no "Farley Initiating Event Identification Analysis" review might identify additional additional initiators are which is documented as part of the FNP plant specific initiators, needed Initiating Event Notebook.

This table lists each particularly associated with FNP system ordered by a system group transformers, buses, etc. identifier, system ID, system description, impact of system loss and treatment of system loss in FNP PRA. The treatment of system loss in FNP PRA column addressed specifically whether the loss of a system would result in a initiating event and how the initiating event was grouped. This finding is considered closed pending incorporation into Initiating Events notebook.IE-A9 IE-A9-01 A plant-specific review of Review significant non- A search was performed on the Condition (SR CCI) potential precursor events, such scram events at the plant to Reports database.

A comparison of the search met CCI as intake structure clogging and determine if any precursors for significant non-scram events to FNP's others, has not been performed exist initiating events list revealed no new initiating FNP. event precursors to plant trips. This finding is considered closed pending incorporation into Initiating Events notebook.E2-12 Enclosure 2 Documentation of PRA Technical Adequacy Table 2 Resolution of the FNP PRA Peer Review F&Os for Not-Met CAT II SRs Review F&O # Finding Resolution The Status of Resolution by SNC Element IE-B3 IE-Bl-01 Several cases were noted Include the impact of the. Table C-1 "Farley Initiating Event Identification (SR CCI) where grouping in the IE initiator on the PSA systems Analysis" was created which is documented in met CCI document is unclear or in the model the FNP Initiating Event Notebook.

This table incorrect.

Therefore, additional lists each FNP system ordered by a system documentation is needed to group identifier, system ID, system description, verify that the event grouping is impact of system loss and treatment of system clear and can be easily traced loss in FNP PRA. The treatment of system to the plant impact. loss in FNP PRA column addressed specifically whether the loss of a system would result in a initiating event and how the initiating event was grouped. This finding is considered closed pending incorporation into Initiating Events notebook.IE-C5 IE-C5-01 FNP did not weigh the initiating Modify the initiating event The adjustment has been done as part of the (SR CC-I/lI) event frequencies by the frequency to address plant quantification.

This finding is considered closed not met fraction of time the plant is at availability pending incorporation into Initiating Events power. notebook.E2-13 Enclosure 2 Documentation of PRA Technical Adequacy Table 2 Resolution of the FNP PRA Peer Review F&Os for Not-Met CAT 11 SRS Review F&O # Finding Resolution The Status of Resolution by SNC Element AS-C2 AS-C2-02 The FNP AS notebook 0 Add initiating events The Accident Sequence notebook was revised (SR CC-I/II/Ill) provides discussions of the %LOSPF and %LOSPG to to correctly reference the loss of bus initiating not met examples indicated in the SR. Table 2.6-1 events. The descriptions of the %LOSSACF Improve the level of and %LOSSACG events in Table 2.6-4 were documentation.

0 Correct the descriptions of not changed because they are correct.initiating events %LOSSACF Instead, the descriptions for those events were and %LOSSACG in Table corrected in Table 2.6-1 and events %LOSPF 2.6-4 and %LOSPG were added to Table 2.6-1. The documentation was revised. This finding is considered closed.SY-A6 SY-A9-01 The system boundary as Review the component The system notebooks were reviewed and (SR CC-I/Il/Ill) defined in the system notebook boundary definitions to modified as needed to reflect the boundary of not met does not match up to the fault ensure that they are the system as shown in the model. The tree. For example, room sufficiently detailed to support system sections were reviewed and cooling is defined in the identify exactly what is corrected as needed to reflect the support notebook as system included within each systems as modeled. This finding is dependency but in the model component and that are considered closed pending final updates to the room cooling is included as part consistent from the model to System notebooks.

of the system designation.

the system notebooks E2-14 Enclosure 2 Documentation of PRA Technical Adequacy Table 2 Resolution of the FNP PRA Peer Review F&Os for Not-Met CAT II SRs Review F&O # Finding Resolution The Status of Resolution by SNC Element SY-Ci SY-C1 -01 The system notebooks Correct the System This is a documentation issue. The references (SR CC-I/II/III) documentation on test and notebook's references for were corrected.

This finding is considered not met maintenance for several test and maintenance closed pending final updates to the System systems is incorrect and information notebooks.

references old or incorrect documents.

HR-D2 HR-D2-01 Detailed HFE assessments are Perform detailed analysis A revision to Table 8-2 of the HRA notebook (SR CCI) HR-D2-02 used for events that are not on all events to verify the has been prepared providing a more detailed met CCI shown to be directly applicable applicability used or use explanation of the approach used. The pre-to the analysis performed.

screening values for those initiator approach relies on detailed THERP Also, the screening values used events not explicitly assessments that are mapped to similar HFEs.for pre-HRAs are significantly analyzed with a detailed HR-D2 does not preclude using detailed lower than the ASEP values analysis THERP analyses for all HFEs. These findings without justification of the are considered closed pending update of the values used. HRA notebook.HR-G1 HR-G1-01 In general, detailed analysis is Develop HRAs for the The events were included in the HRA calculator (SR CCI) done for most post HRA events, referenced 2 events and file using the values found in NUREG CR5500 met CCI However, the most important include in the HRA and WCAP-15831.

The finding is considered HRAs showing up in the cutset calculation closed pending update of the HRA notebook.have not been performed on a detailed analysis.E2-15 Enclosure 2 Documentation of PRA Technical Adequacy Table 2 Resolution of the FNP PRA Peer Review F&Os for Not-Met CAT II SRs Review F&O # Finding Resolution The Status of Resolution by SNC Element HR-G7 HR-G7-01 The multiple human action Explicitly evaluate the top An HRA Dependency Analysis was conducted QU-A5 HR-G7-02 analysis described in Appendix HRA combinations in the and incorporated into the Revision 9 model QU-C2 C does not appear to be used dependency analysis.

quantification.

This analysis will be (SR CCI/II/Il) in the quantification.

Update the HRA incorporated into the HRA notebook as not met Attachment C to the HRA dependence evaluation to Appendix C. The finding is considered closed notebook performs the be consistent with industry pending update of the HRA notebook.dependency assessment, but practices the dependency factors are based upon 2004 HRA values.The multiplication factors in the rule file are to be based upon current HRA. The top HRA cutset combinations in the QU notebook are not addressed in the HRA dependency analysis.HR-13 HR-13-01 Sources of uncertainty are not

Include a source of A document was created to address HRA (SR CCI/II/Il) included in the HRA calculation uncertainty in the HRA Uncertainty for the FNP model. It can be found not met similar to other FNP calculation as Attachment F in the HRA notebook.

The documentation.

finding is considered closed pending update of the HRA notebook.E2-16 Enclosure 2 Documentation of PRA Technical Adequacy Table 2 Resolution of the FNP PRA Peer Review F&Os for Not-Met CAT II SRs Review F&O # Finding Resolution The Status of Resolution by SNC Element IFEV-B3 IFEV-B3-01 The FNP PRA flooding analysis

Include a discussion of New text concerning uncertainty and IFSO-B3 indicates that sources of uncertainty and assumptions assumptions has been incorporated into the IFPP-B3 uncertainty were not related to internal flooding appropriate sections of the Flooding notebook.(SR CCI/II/II) documented because of the low issues including partitioning, The finding is considered closed pending not met contribution to CDF and LERF initiating events, and flood update of the Flooding notebook., from flooding.

Although this is sources true, the SR requires that a discussion of uncertainty be provided.IFPP-B2 IFPP-B2-02 Internal flooding notebook Add information about the New text concerning screened/eliminated areas (SR CCI/II/Il)

IFPP-B2-03 provides the process and screened/eliminated areas and buildings has been incorporated into the not met selection result of flood areas and buildings in terms of appropriate sections of the Flooding notebook.partitioning.

However, there is internal flooding analysis The finding is considered closed pending no description about the reason update of the HRA notebook.for eliminating areas from further analysis, except containment.

IFQU-A7 IFQU-A7-01 Quantification of flooding event Perform and provide An HRA Dependency Analysis was conducted (SR CCI/II/Il) does not perform uncertainty uncertainty analysis and and incorporated into the Revision 9 model not met analysis and dependency dependency analysis, even quantification.

This analysis will be analysis.

though the flood risk is not incorporated into the HRA notebook as significant Appendix C. The finding is considered closed pending update of the HRA notebook.E2-17 Enclosure 2 Documentation of PRA Technical Adequacy Table 2 Resolution of the FNP PRA Peer Review F&Os for Not-Met CAT 11 SRs Review F&O # Finding Resolution The Status of Resolution by SNC Element IFSN-A4 IFSN-A4-01 In the IF Notebook, there was Add a table that explicitly New text has been incorporated into the (SR CCI/II/Il) extensive discussion with includes drain capacities appropriate sections of the Flooding notebook.not met respect to treatment of drains The finding is considered closed pending and explicit evidence that update of the HRA notebook.drains were considered as propagation paths for several flood scenarios.

However, no explicit estimation of drain capacities could be found.IFSN-B3 IFSN-B3-01 There is no description about Include a section in the IF New text concerning uncertainty and (SR CCI/11/11) uncertainty.

Notebook to discuss the IF assumptions has been incorporated into the not met assumptions and sources of appropriate sections of the Flooding notebook.uncertainty The finding is considered closed pending update of the HRA notebook.QU-F1 QU-F1 -01 The mutually exclusive logic Update the documentation The documentation reference has been (SR CCI/II/Il) was generated by the to reflect the actual updated. The finding is considered closed not met procedure FNP-0-ACP-52.1 but references pending update of the Quantification notebook.was not documented in the quantification notebook.E2-18 Enclosure 2 Documentation of PRA Technical Adequacy Table 2 Resolution of the FNP PRA Peer Review F&Os for Not-Met CAT 11 SRs Review F&O # Finding Resolution The Status of Resolution by SNC Element MU-B4 MU-B4-01 There is no reference to a peer Revise either NL-PRA-001 These procedures are under revision.(SR CCI/II/II) review for upgrades.

A section or NL-PRA-002 to explicitly not met which addressed upgrades (not require a peer review for updates) to the PRA specific PRA upgrades change in software used was not found.E2-19 Enclosure 2 Documentation of PRA Technical Adequacy There were no LE findings.

The following SRs were Category I.Review Summary of Assessment Element LE-C2 The FNP PRA LERF model relies largely on human error probabilities taken from the WCAP-16341-P.

Because the WCAP HEPs (SR CCI) are generic rather than plant-specific, they were derived as conservative estimates.

met CCI LE-C9 No credit is taken for either equipment operation or human actions in adverse environments.(SR CCI)met CCI LE-C1 1 No credit was taken in the FNP PRA for equipment or operator actions impacted by containment failure. The WCAP-16341-P (SR CCI) methodology conservatively does not credit containment sprays for fission product scrubbing or pressure suppression for the met CCI containment failure.LE-C12 The LERF frequency calculated in the FNP PRA is so low that no review was performed to reduce LERF based on engineering (SR CCI) analysis to support equipment operation or operator action after containment failure.met CCI E2-20 Enclosure 2 Documentation of PRA Technical Adequacy 2.3 Identification of Key Assumptions The overall initiative 5B process is a risk-informed process with the PRA model results providing one of the inputs to the Independent Decision-making Panel (IDP) to determine if a Surveillance Test Interval (STI) change is warranted.

The methodology recognizes that a key area of uncertainty for this application is the standby failure rate utilized in the determination of the STI extension impact.The FNP PRA model does not use the standby failure rate approach, but the demand failure approach.

In the demand failure approach, demand failure probabilities were evaluated by Bayesian update using plant specific failure data (total number of demands and total number of failures) and generic data.Therefore, there is no specific assumption utilized in the FNP PRA model for standby failure rate.For evaluating the impact of a STI change for 5B application, the following assumption will be used: Qd = 1/2 AT Where Qd: Demand failure probability, A: Standby failure rate, and T: a STI Therefore, if a STI increased from TO to T1 by a surveillance frequency change, the demand failure probability will be assumed to increase from Qd to Qd*(T1 /TO).It is also noted that key assumptions may differ based on the system being considered for a STI change. Therefore, for each application of the PRA model, assumptions will be reviewed, key assumptions for a particular application will be identified, and impact of these key assumptions on the risk insights will be assessed.3.0 External Event Considerations The NEI-04-10 methodology allows for STI change evaluations to be performed in the absence of quantifiable PRA models for all external hazards. For those cases where the STI cannot be modeled in the plant PRA (or where a particular PRA model does not exist for a given hazard group), a qualitative or bounding analysis is performed to provide justification for the acceptability of the proposed test interval change.External hazards were evaluated in the FNP Individual Plant Examination of External Events (IPEEE) submitted in response to the NRC IPEEE program (Generic Letter 88-20, Supplement

4) (Reference 8). The IPEEE program was a one-time review of external hazard risk and was limited in its purpose to the identification of potential plant vulnerabilities and the understanding of associated severe accident risks. The results of E2-21 Enclosure 2 Documentation of PRA Technical Adequacy the FNP IPEEE study are documented in the FNP IPEEE main report. The primary areas of external event evaluation at FNP were internal fire and seismic.The internal fire events were addressed by a scenario-based PRA approach that meets the requirements of NUREG-1407 (Reference

9) to systematically and successively evaluate fire and smoke hazards and their associated risk impact to FNP. The IPEEE Fire PRA study provided estimates of CDF and LERF. However, the original IPEEE Fire PRA has not been updated. Currently, a state-of-the-art FNP Fire PRA model, which will meet all Capability Category II (CC-Il) requirements in the ASME PRA standard is being developed.

When, and if, the IPEEE Fire PRA model is used, consistent with NEI-04-10, the fire risk insights will be complemented by conservative qualitative potential impact of the fire hazard.In the FNP IPEEE, the seismic risk evaluation was performed in accordance with EPRI Seismic Margins Analysis (SMA) methodology.

Since the SMA approach was used, there are no comprehensive CDF and LERF values available from the seismic analysis in the FNP IPEEE to support the STI risk evaluations.

In addition to internal fires and seismic events, the FNP IPEEE analysis of high winds, floods, and other external hazards was accomplished by using a progressive screening approach described in NUREG-1407.

The FNP IPEEE concluded that in all reviewed areas no potential vulnerabilities were identified.

As stated earlier, the NEI 04-10 methodology allows for STI change evaluations to be performed in the absence of quantifiable PRA models for all external hazards.Therefore, for fire risk assessment, until a new FNP fire PRA model which meets all CC-II requirements in the ASME PRA standard is built, the impacts on fire risk of an STI change will be assessed using a qualitative or a bounding approach supplemented with insights from IPEEE fire PRA and from the FNP internal events PRA model. In performing the assessment for the other external events, a qualitative or a bounding approach will also be utilized in most cases.4.0 General Conclusion Regarding PRA Capability The FNP PRA maintenance and update processes and technical capability evaluations described above provide a robust basis for concluding that the PRA is suitable for use in risk-informed licensing actions. As specific risk-informed PRA applications are performed, remaining gaps to specific requirements in the PRA standard will be reviewed to determine application specific additional analysis, i.e., sensitivity studies, which may be required on an as needed basis E2-22 Enclosure 2 Documentation of PRA Technical Adequacy 5.0 References

1. 'Westinghouse Owners Group Peer Review Final Report," Westinghouse, 2002.2. "Probabilistic Risk Assessment (PRA) Peer Review Process Guidance," NEI-00-02, Rev. A3, 2000.3. "Gap Analysis of the Farley PRA", ERIN, 2005.4. American Society of Mechanical Engineers, Standard for Probabilistic Risk Assessment for Nuclear Power Plant Applications, ASME RA-S-2002, 2002 and Addenda to Standard for Probabilistic Risk Assessment for Nuclear Power Plant Applications, ASME RA-Sa-2003, 2003.5. 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", American Society of Mechanical Engineers, 2009.6. U.S. Nuclear Regulatory Commission, An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities, Regulatory Guide 1.200, Revision 2, 2008.7. "Process for Performing Internal Events PRA Peer Reviews Using the ASME/ANS PRA Standard", NEI 05-04, Revision 2, 2008.8. "Individual Plant Examination of External Events (IPEEE) for Severe Accident Vulnerabilities

-10 CFR 50.54(f), Supplement 4," NRC Generic Letter 88-20, June 1991.9. "Procedural and Submittal Guidance for the Individual Plant Examination of External Events (IPEEE) for Severe Accident Vulnerabilities," NUREG-1407, US NRC, June 1991.E2-23 Joseph M. Farley Nuclear Plant License Amendment Request for Adoption of TSTF-425-A, Revision 3, Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program Using the Consolidated Line Item Improvement Process Enclosure 3 Markup for FNP Proposed TS Changes Enclosure 3 Markups for FNP Proposed TS Changes Insert 1 In accordance with the Surveillance Frequency Control Program Insert 2 The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.Insert 3 5.5.19 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 interval 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 E3-1 Definitions 1.1 1.1 Definitions SHUTDOWN MARGIN (SDM)(continued)

SLAVE RELAY TEST b. In MODES 1 and 2, the fuel and moderator temperatures are changed to the hot zero power temperatures.

A SLAVE RELAY TEST shall consist of energizing each slave relay and verifying the OPERABILITY of each slave relay. The SLAVE RELAY TEST shall include, as a minimum, a continuity check of associated testable actuation devices.A STAGGERED TEST BASIS -hall concict of the tctinRg Of ono of the 6ycteomz, 6ubsyctoms, channcls, or ethc docignat, d copn. -ent, during thc inRteral .p ..ified by the SUl n ill1la so that all systems, s channels, Or othcr designated co)mpoenets aro tested during n Survoillanco FrFequency intorvals, whore n is the total Runubcr of syctomsG, subsystems, cha~nncs, or 9thc desinaated comoonE)ente in the associated functionR.

1RT-AGaaFR~fl Tr=RT- BAI THERMAL POWER TRIP ACTUATING DEVICE OPERATIONAL TEST (TADOT)THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.A TADOT shall consist of operating the trip actuating device and verifying the OPERABILITY of required alarm, interlock, and trip functions.

The TADOT shall include adjustment, as necessary, of the trip actuating device so that it actuates at the required setpoint within the required accuracy.Farley Units 1 and 2 1.1-6 Amendment No. P: (Unit 1)Amendment No. (Unit 2)

SDM 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)LCO 3.1.1 SDM shall be within the limits provided in the COLR.APPLICABILITY:

MODE 2 with keff< 1.0, MODES 3, 4, and 5.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Initiate boration to restore Immediately SDM to within limit.Farley Units 1 & 2 3.1.1-1 Amendment No. (Unit 1)Amendment No. (Unit 2)

Core Reactivity

3.1.2 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1---------------

NOTE ----------------

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 measured core reactivity is within + 1% Ak/k of predicted values./Once prior to entering MODE 1 after each refueling AND-------- NOTE --------Only required after 60 EFPD--- -- -- --- -- -----Insert 1 Farley Units 1 and 2 3.1.2-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

Rod Group Alignment Limits 3.1.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. More than one rod not D.1.1 Verify SDM to be within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months within alignment limit, the limits provided in the COLR.OR D.1.2 Initiate boration to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore required SDM to within limit.AND D.2 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY S R 3.1.4.1 Verify individual rod positions within alignment limit. 2h '-s S R 3.1.4.2 Verify rod freedom of movement (trippability) by moving each rod not fully inserted in the core> 10 steps in either direction.

SR 3.1.4.3 Verify rod drop time of each rod, from the fu Prior to reactor withdrawn position, is < 2.7 seconds from e criticality after beginning of decay of stationary gripper o 'voltage each removal of to dashpot entry, with: the reactor head r 1/a. mavg >! 541 OF; and /b. All reactor coolant perating.Farley Units 1 and 2 3.1.4-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

Shutdown Bank Insertion Limits 3.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each shutdown bank is withinthe limits specified in the COLR.Insert 1 Farley Units 1 and 2 3.1.5-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

Control Bank Insertion Limits 3.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.2 Verify each control bank insertion is within the limits specified in the COLR. fe S R 3.1.6.3 Verify sequence and overlap limits specife th 2euf COLR are met for control banks not fully, ithdra, l Insert Farley Units 1 and 2 3.1.6-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

PHYSICS TESTS Exceptions-MODE 2 3.1.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. RCS lowest loop average C.1 Restore RCS lowest 15 minutes temperature not within loop average limit. temperature to within limit.D. Required Action and D.1 Be in MODE 3. 15 minutes associated Completion Time of Condition C not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 Perform a CHANNEL OPERATION TEST on Prior to initiation of power range and intermediate range channels per PHYSICS TESTS SR 3.3.1.7, SR 3.3.1.8, and Table 3.3.1-1.SIR 3.1.8.2 Verify the RCS lowest loop average temperature is>t 531 OF.S R 3.1.8.3 Verify THERMAL POWER is < 5% RTP./ ,,]SR3184 Verify SDM to be within the limits provided " th COLR. , SInsert 1 Farley Units 1 and 2 3.1.8-2 Amendment No. = (Unit 1)Amendment No. t (Unit 2)

FQ(Z)3.2.1 SURVEILLANCE REQUIREMENTS-N r --------------------------------------------------------------

During power escalation at the beginning of each cycle, THERMAL POWER may be increased until an equilibrium power level has been achieved, at which a power distribution map is obtained SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify FQ(Z) is within steady state limit.Insert 1 Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND Once after achieving equilibrium conditions after exceeding, by> 20% RTP, the THERMAL POWER at which FQ(Z) was last verified AND)5-,-,-Bn

+h r .Farley Units 1 and 2 3.2.1-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

FQ(Z)3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.2 (continued)

Once after achieving equilibrium conditions after exceeding, by> 20% RTP, the THERMAL POWER at which FQ(Z) was last verified AND w 1F==-1/Insert 1I Farley Units 1 and 2 3.2.1-5 Amendment No. (Unit 1)Amendment No. (Unit 2)

F3N 3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.2.1 Verify FAH is within limits specified in the COLR.Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND Farley Units 1 and 2 3.2.2-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

AFD 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD)LCO 3.2.3 The AFD in % flux difference units shall be maintained within the limits specified in the COLR.-------------------------

NOTE --------------------------

The AFD shall be considered outside limits when two or more OPERABLE excore channels indicate AFD to be outside limits.APPLICABILITY:

MODE 1 with THERMAL POWER > 50% RTP.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AFD not within limits. A.1 Reduce THERMAL 30 minutes POWER to < 50% RTP.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD within limits for each OPERABLE excore channel.Insert 1 Farley Units 1 and 2 3.2.3-1 Amendment No. (Unit 1)Amendment No. (Unit 2)

QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1-----------------

NOTES ----------------

1. With input from one Power Range Neutron Flux channel inoperable and THERMAL POWER< 75% RTP, the remaining three power range channels can be used for calculating QPTR.2. SR 3.2.4.2 may be performed in lieu of this Surveillance.

Verify QPTR is within limit by calculation.

SR 3.2.4.2 ----------------------

NOTE -----------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after in t from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWE> 75% RTP.Confirm that the normalized symmetric po er distribution is consistent with QPTR.Insert 1 Farley Units 1 and 2 3.2.4-4 Amendment No. (Unit 1)Amendment No. (Unit 2)

RTS Instrumentation

3.3.1 SURVEILLANCE

REQUIREMENTS

NOTE -------------------------------------

Refer to Table 3.3.1-1 to determine which SRs apply for each RTS Function.SURVEILLANCE FREQUENCY SR 3.3.1.1 -------------------

NOTE ------------------

Not required to be performed for source range instrumentation until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after THERMAL POWER is < P-6.Perform CHANNEL CHECK.SR 3.3.1.2 ---------------------

NOTES ----------------

1. Adjust NIS channel if calorimetric calculated power exceeds NIS indicated power by more than +2% RTP.2. Not required to be performed until 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER is >_ 15% RTP.Compare results of calorimetric heat balan ce'A calculation to Nuclear Instrumentation Systep' (NIS)channel output.SR 3.3.1.3 ---------------

NOTES ------- ------ --1. Adjust NIS channel if absolute di erence s> 3%.2. Not required to be performed ntil 7 ays after THERMAL POWER is _> 50/RT 3. Performance of SR 3.3.1.9 sati fies this SR.Compare results of the1et/measurements to NIS AFID.I Insert 11:T Farley Units 1 and 2 3.3.1-9 Amendment No. (Unit 1)Amendment No. (Unit 2)

RTS Instrumentation

3.3.1 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.4 --------------------

NOTE ----------------

This Surveillance must be performed on the reactor trip bypass breaker prior to placing the bypass breaker in service.Perform TADOT. R a SR 3.3.1.5 Perform ACTUATION LOGIC TEST./1 92 days eRCTAGGERED TEST BASIS SR 3.3.1.6 Perform TADOT.SR 3.3.1.7----------

NOTE --------Not required to be performed for source rar instrumentation prior to entering MODE 3 fj MODE 2 until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entry into MOI Perform COT.Farley Units 1 and 2 3.3.1-10 Amendment No. (Unit 1)Amendment No. (Unit 2)

RTS Instrumentation

3.3.1 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.8---------------

--NOTE -----------------

This Surveillance shall include verification that interlocks P-6 and P-10 are in their required state for existing unit conditions.

Perform COT.Insert 1 "-------- NOTE --------Only required when not performed

i Prior to reactor startup AND Four hours after reducing power below P-6 for source range instrumentation AND Twelve hours after reducing power below P-1 0 for power range and intermediate range instrumentation AND Farley Units 1 and 2 3.3.1-11 Amendment No. (Unit 1)Amendment No. (Unit 2)

RTS Instrumentation

3.3.1 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.9 -------------------

NOTES ---------------

1. Neutron detectors are excluded from the calibration.

2. Not required to be performed until 7 days after THERMAL POWER is 50% RTP.Calibrate excore channels to agree with incor~e detector measurements.'/

SR 3.3.1.10 ------------------------------

NOTES ----------------

7 ---1. Neutron detectors are excluded from CHANNEL CALIBRATION.

2. This Surveillance shall include verif ation that the time constants are adjusted t he prescribed values.---------------------------------------

NT Perform CHANNEL CALIBRATIT SR 3.3.1.11 Perform COT. N! ots"- ------. N O T E .- --SInsert 1 Only required when not erformed Prior to reactor startup Farley Units 1 and 2 3.3.1-12 Amendment No. (Unit 1)Amendment No. (Unit 2)

RTS Instrumentation

3.3.1 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.12 --------------------

NOTE ------------------

Verification of setpoint is not required.Perform TADOT.SR 3.3.1.13 ------------------

NOTE ------------------------

/Verification of setpoint is not required.Perform TADOT. Prior to exceeding the P-9 interlock whenever the unit has been in MODE 3, if not performed within the previous 31 days SIR 3 .3 .1 .1 4 1N O T E .... .-- -Neutron detectors are excluded response time te s tin g ._ _Verify RTS RESPONSE TI swithin limits. enma TSTAG RED!E Insert 1E:: Farley Units 1 and 2 3.3.1-13 Amendment No. = (Unit 1)Amendment No. (Unit 2)

ESFAS Instrumentation 3.3.2 L. (continued)

L.2-NOTE -----------

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for Surveillance testing, provided the other train is OPERABLE.Restore train to OPERABLE status.24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months in MODE 3.30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months )DE 5 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months N¶11,9 dayseR STGzzz-TrQ SR 3.3.2.4 Perform COT.SR 3.3.2.5 Perform TADOT.Farley Units 1 and 2 3.3.2-6 Amendment No. (Unit 1)Amendment No. (Unit 2)

ESFAS Instrumentation

3.3.2 SURVEILLANCE

REQUIREMENTS SR 3.3.2.10 --------------------

NOTE -------------------

Verification of setpoint not required.------NOTE-----Only required when not performed within previous 92 days.----------------------------------------------------------------------

Perform TADOT.Prior to reactor startup Farley Units 1 and 2 3.3.2-7 Amendment No. (Unit 1)Amendment No. (Unit 2)

PAM Instrumentation

3.3.3 ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition C Table 3.3.3-1 for the not met. channel.E. As required by Required E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action D.1 and referenced in AND Table 3.3.3-1.E.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. As required by Required F.1 Initiate action in Immediately Action D.1 and accordance with referenced in Specification 5.6.8.Table 3.3.3-1.SURVEILLANCE REQUIREMENTS

NOTE--------------------------------

SR 3.3.3.1 and SR 3.3.3.2 apply to each PAM instrumentation Function in Table 3.3.3-1.SURVEILLANCE FREQUENCY SIR 3.3.3.1 Perform CHANNEL CHECK for each required instrumentation channel that is normally energized./

SR 3.3.3.2 Perform CHANNEL CALIBRATION.

Insert 1 Farley Units 1 and 2 3.3.3-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

Remote Shutdown System 3.3.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Submit a report to the 14 days associated Completion NRC outlining the Time not met for Source preplanned alternate Range Neutron Flux method of ensuring the function.

reactor remains shutdown in the event of a control room evacuation, the cause of the inoperability, and the plans and schedule for restoring the Source Range Neutron Flux monitor to OPERABLE status.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK for each required monitoring instrumentation channel that is normally energized.

SR 3.3.4.2 Verify each required control circuit and transfer switch is capable of performing the intended fSR 3.3.4.3-----------------

NOTE ------------

Neutron detectors are excluded from C CALIBRATION.

/Perform CHANNEL CALIBRAI monitoring instrumentation cI)4 I Insert Farley Units 1 and 2 3.3.4-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

LOP DG Start Instrumentation

3.3.5 ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME D. ----------

NOTE -----------

D.1 Verify voltage on Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Only applicable to associated bus is > 3850 Function 3. volts.One Alarm Function channel inoperable on one or more trains.E. Required Action and E.1 Restore bus voltage to > 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion 3850 volts.Time of Condition D not met.F. Required Action and F.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition E AND not met.F.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 -------------------

NOTES ----------------

1. TADOT shall exclude actuation of the final trip actuation relay for LOP Functions 1 and 2.2. Setpoint verification not required.Perform TADOT. 4I, I Insert1 I Farley Units 1 and 2 3.3.5-2 Amendment No. R (Unit 1)Amendment No. (Unit 2)

LOP DG Start Instrumentation

3.3.5 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.2 -- ------------------

NOTE ---------------

CHANNEL CALIBRATION shall exclude actuation of the final trip actuation relay for Functions 1 and 2.Perform CHANNEL CALIBRATION. ,ttths SR 3.3.5.3-----------------

Note ...............

Response time testing shall include actuation of the final trip actuation relay.Verify ESF RESPONSE TIME within limit.//948FERt 7 Farley Units 1 and 2 3.3.5-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

Containment Purge and Exhaust Isolation Instrumentation

3.3.6 SURVEILLANCE

REQUIREMENTS

1,41 r ----------------------------------------------------------

Refer to Table 3.3.6-1 to determine which SRs apply for each Containment Purge and Exhaust Isolation Function.SURVEILLANCE FREQUENCY SR 3.3.6.1 Perform CHANNEL CHECK. I, SR 3.3.6.2 Perform ACTUATION LOGIC TEST./02 dayS OR a STAGGERED TEST BASIS Farley Units 1 and 2 3.3.6-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

CREFS Actuation Instrumentation

3.3.7 ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued)

B.2 Place both CREFS trains Immediately in emergency recirculation mode.C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for Condition A AND or B not met in MODE 1, 2, 3, or 4. C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. Required Action and D.1 Suspend CORE Immediately associated Completion ALTERATIONS.

Time for Condition A or B not met during AND movement of irradiated fuel assemblies or D.2 Suspend movement of Immediately during CORE irradiated fuel assemblies.

ALTERATIONS.

SURVEILLANCE REQUIREMENTS

NOTE ------------------------------

Refer to Table 3.3.7-1 to determine which SRs apply for each CREFS Actuation Function.SURVEILLANCE FREQUENCY S R 3.3.7.1 Perform CHANNEL CHECK.S R 3.3.7.2 Perform COT. ./ '..................

Farley Units 1 and 2 3.3.7-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

CREFS Actuation Instrumentation

3.3.7 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.3 Perform ACTUATION LOGIC TEST. 9 ,s-a S R 3.3.7.4 Perform MASTER RELAY TEST. W).4 -,n S R 3.3.7.5 Perform SLAVE RELAY TEST.SR 3.3.7.6 -------------------

NOTE -------------------

Verification of setpoint is not required.Perform TADOT.S R 3.3.7.7 Perform CHANNEL CALIBRATION. D nert 1 Farley Units 1 and 2 3.3.7-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

PRF Actuation Instrumentation

3.3.8 SURVEILLANCE

REQUIREMENTS

NOTE--------------------------------

Refer to Table 3.3.8-1 to determine which SRs apply for each PRF Actuation Function.SURVEILLANCE FREQUENCY SR 3.3.8.1 Perform CHANNEL CHECK. ...I S R 3.3.8.2 Perform COT.SR 3.3.8.3 Perform ACTUATION LOGIC TEST.STAGGERED TEST BASIS SR 3.3.8.4 Perform MASTER RELAY TEST. 2y S R 3.3.8.5 Perform SLAVE RELAY TEST. ,// / Of SR 3.3.8.6 --------------------

NOTE---------------

Verification of setpoint is not required.Perform TADOT.S R 3.3.8.7 Perform CHANNEL CAIBATIO!

0////o Insert 1 Farley Units 1 and 2 3.3.8-3 Amendment No. (Unit 1)Amendment No. f (Unit 2)

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY S R 3.4. 1.1 Verify pressurizer pressure is within the limit 2hrs specified in the COLR.S R 3.4.1.2 Verify RCS average temperature is within the li specified in the COLR.it S R3.41. VeifyRC toalflow rate is within the S R 3.4.1.4 -----------

NOTE, ...............-----

-Not required to be performed until 7 dfays >-90% RTP.Verify by measurement that RCS total/ rjatieis ,,.t- "'"I"*'within the limits.//I I n sert:1 l Farley Units 1 and 2 3.4.1-2 Amendment No. M (Unit 1)Amendment No. (Unit 2)

RCS P/T Limits 3.4.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. --------NOTE -------------

C.1 Initiate action to restore Immediately Required Action C.2 shall parameter(s) to within be completed whenever limits.this Condition is entered.AND Requirements of LCO not C.2 Determine RCS is Prior to entering met any time in other acceptable for continued MODE 4 than MODE 1, 2, 3, or 4. operation.

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 are within the limits specified in the PTLR.I Insert 1 Farley Units 1 and 2 3.4.3-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

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 Three RCS loops shall be OPERABLE and in operation.

APPLICABILITY:

MODES 1 and 2.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of LCO not A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months met.SURVEILLANCE JIREMENTS SURVEILLANCE Farley Units 1 and 2 3.4.4-1 Amendment No. (Unit 1)Amendment No. (Unit 2)

RCS Loops--MODE 3 3.4.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. One required RCS loop C.1 Restore required RCS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not in operation, and loop to operation.

reactor trip breakers closed and Rod Control OR System capable of rod withdrawal.

C.2 De-energize all control 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months rod drive mechanisms (CRDMs).D. Two required RCS loops D.1 De-energize all CRDMs. Immediately inoperable.

AND OR D.2 Suspend all operations Immediately No RCS loop in involving a reduction of operation.

RCS boron concentration.

AND D.3 Initiate action to restore Immediately one RCS loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loops are in operation.

SR 3.4.5.2 Verify steam generator secondary side water levels are > 30% (narrow range) for required RCS loops. Al SR 3.4.5.3 Verify correct breaker alignment and indicated p r are available to the required pump that is not in operation.

Insert I Farley Units 1 and 2 3.4.5-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

RCS Loops--MODE 4 3.4.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. One required RHR loop B.1 Be in MODE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable.

AND Two required RCS loops inoperable.

C. Required RCS or RHR C.1 Suspend all operations Immediately loops inoperable, involving a reduction of RCS boron concentration.

OR AND No RCS or RHR loop in operation.

C.2 Initiate action to restore Immediately one loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RHR or RCS loop is in operation.

SR 3.4.6.2 Verify SG secondary side water levels are _> 75% / 0-(wide range) for required RCS loops. _ _/S R 3.4.6.3 Verify correct breaker alignment and indicatedoer are available to the required pump that is note operation. Farley Units 1 and 2 3.4.6-2 Amendment No. = (Unit 1)Amendment No. (Unit 2)

RCS Loops--MODE 5, Loops Filled 3.4.7 APPLICABILITY:

MODE 5 with RCS loops filled.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR loop A.1 Initiate action to restore a Immediately inoperable, second RHR loop to OPERABLE status.AND OR Required SGs secondary side water levels not A.2 Initiate action to restore Immediately within limits, required SG secondary side water levels to within limits.B. Required RHR loops B.1 Suspend all operations Immediately inoperable, involving a reduction of RCS boron concentration.

OR AND No RHR loop in operation.

B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation. "...I S R 3.4.7.2 Verify SG secondary side water level is _> 75% ("e/2hus range) in required SGs.Insert 1 Farley Units 1 and 2 3.4.7-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

RCS Loops -MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE IFREQUENCY SR 3.4.7.3 Verify correct breaker alignment and indicated power are available to the required RHR pump that is not in operation.

Insert 1 Farley Units 1 and 2 3.4.7-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

RCS Loops--MODE 5, Loops Not Filled 3.4.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required RHR loops B.1 Suspend all operations Immediately inoperable, involving reduction in RCS boron concentration.

OR AND No RHR loop in operation.

B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY S R 3.4.8.1 Verify one RHR loop is in operation.

S R 3.4.8.2 Verify correct breaker alignment and indicated peer are available to the required RHR pump thatnoti operation.

IInsert I Farley Units 1 and 2 3.4.8-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

Pressurizer

3.4.9 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is < 63.5% indicated.

!i ur SR 3.4.9.2 Verify capacity of each required group of pressuriz heaters is 125 kW. / /SR 3.4.9.3 Verify required pressurizer heaters are car being powered from an emergency power Insert 1 Farley Units 1 and 2 3.4.9-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

Pressurizer PORVs 3.4.11 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. More than one block valve F.1 Place associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable.

PORVs in manual control.AND F.2 Restore one block valve 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to OPERABLE status.AND F.3 Restore remaining 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months block valve to OPERABLE status.G. Required Action and G.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition F not AND met.G.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 --------------------

NOTES---------------

1. Not required to be met with block valve closed in accordance with the Required Action of Condition B or E.2. Not required to be performed prior to entry into MODE 3.3. Not required to be performed for Unit 2 for the remainder of operating cycle 16 for block valve Q2B31 MOV8000B.Perform a complete cycle of each block valve.Insert 1I Farley Units 1 and 2 3.4.11-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

Pressurizer PORVs 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.2 ------------------

NOTE-----------------

Not required to be performed prior to entry into MODE 3.Perform a complete cycle of each PORV during MODE 3 or 4.,, ,Jv .SR 3.4.11.3 Perform a complete cycle of each PORV using t backup PORV control system.SR 3.4.11.4 ----------------------------

NOTE -----------------

Required to be performed only for U 2 f e remainder of operating cycle 16.Check power available t nit Two PORV block valve Q21331 MOV800JlFarley Units 1 and 2 3.4.11-4 Amendment No. =(Unit 1)Amendment No. (Unit 2)

LTOP System 3.4.12 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. One required RHR relief D.1 Reduce pressurizer level 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months valve inoperable.

to < 30% (cold calibrated).

AND D.2 Assign a dedicated 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months operator for RCS pressure monitoring and control.AND D.3 Restore required RHR 7 days relief valve to OPERABLE status.E. Two required RHR relief E.1 Depressurize RCS and 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months valves inoperable, establish RCS vent of> 2.85 square inches.OR Required Action and associated Completion Time of Condition A, C, or D not met. Insert 1 OR LTOP System inoperable for any reason other than Condition A, B, C, or D.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify a maximum of one charging pump is capable of injecting into the RCS.Farley Units 1 and 2 3.4.12-3 Amendment No. =(Unit 1)Amendment No. f(Unit 2)

LTOP System 3.4.12 SURVEILLANCE REQUIREMEN SURVEILLANCE SR 3.4.12.2 Verify each accumulator is isolated.SR 3.4.12.3 Verify RHR suction isolation valves are open for required RHR suction relief valve. 7 SR 3.4.12.4--NOTE Only required to be performed when LCO 3.4.12.b.SR 3.4.12.5 Verify each required RHR suction relief setpoint.In accordance with the Inservice Testing Program AND Farley Units 1 and 2 3.4.12-4 Amendment No. (Unit 1)Amendment No. --31 (Unit 2)

RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 ------------------

NOTES --------------------

---NOTE --------1. Not required to be performed in MODE 3 or 4 Only required to until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state operation.

be performed during steady 2. Not applicable to primary to secondary LEAKAGE. state operation Verify RCS operational LEAKAGE is within limits by performance of RCS water inventory balance.SR 3.4.13.2 -------------------

NOTE ----------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

Verify primary to secondary LEAKAGE is < 150 gallons per day through any one SG. I Insert 1 Farley Units 1 and 2 3.4.13-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 ----------------

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 RHR 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 inch of valve size up to a maximum of 5 gpm at an RCS pressure > 2215 psig and < 2255 psig.Insert 1 18 months, prior to entering MODE 2 AND Following valve actuation due to automatic or manual action or flow through the valve (except for RCS PIVs located in the RHR flow path)N SR 3.4.14.2-------------

NOTE -----------

Not required to be met when the RHR System valves are required open in accordance with SR 3.4.12.3.----------------------------------------------------------------------

Verify RHR System autoclosure interlock causes the valves to close automatically with a simulated or actual RCS pressure signal >_ 700 psig and _< 750 psig.Farley Units 1 and 2 3.4.14-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SR 3.4.14.3-------------

NOTE -----------------

Not required to be met when the RHR System valves valves are required open in accordance with SR 3.4.12.3.Verify RHR System open permissive interlock prevents the valves from being opened with a simulated or actual RCS pressure signal>_ 295 psig and _< 415 psig.Insert 1 : Farley Units 1 and 2 3.4.14-4 Amendment No. (Unit 1)Amendment No. (Unit 2)

RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of the required containment atmosphere radioactivity monitor.SR 3.4.15.2 Perform COT of the required containment atmosphere radioactivity monitor.SR 3.4.15.3 Perform CHANNEL CALIBRATION of th, containment atmosphere radioactivity pO SR 3.4.15.4 Perform CHANNEL CALIBRATIO hequired containment air cooler condenss e moni Insert 1I Farley Units 1 and 2 3.4.15-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

RCS Specific Activity 3.4.16 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Tavg < 500-F.Time of Condition A not met.OR DOSE EQUIVALENT 1-131 in the unacceptable region of Figure 3.4.16-1.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify reactor coolant gross specific activity< 100/E PCi/gm.SR 3.4.16.2 ----------------------

NOTE ----------------

Only required to be performed in MODE Verify reactor coolant DOSE EQUIVALE T113~AND fBetween 2 and Insert 1 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a THERMAL POWER change of> 15% RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period Farley Units 1 and 2 3.4.16-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

RCS Specific Activity 3.4.16 SURVIELLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.3---------------------------------

NOTE --------------

Not required to be performed until 31 days after a minimum of 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 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .Determine E from a sample taken in MODE 1 after a minimum of 2 effective full power days and 20 dap of MODE 1 operation have elapsed since the actor was last subcritical for -> 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .Inse 1a ýFarley Units 1 and 2 3.4.16-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

Accumulators

3.5.1 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SIR 3.5.1.1 Verify each accumulator isolation valve is fully open. !2hus S R 3.5.1.2 Verify borated water volume in each accumulator/

!2his> 7555 gallons (31.4%) and _< 7780 gallons (58./).SR 3.5.1.3 Verify nitrogen cover pressure in each acc tor is_ 601 psig and _< 649 psig.SR 3.5.1.4 Verify boron concentration in each u ator is._ 2200 ppm and -< 2500 ppm.AND Insert 1-------NOTE-Only required to be performed for affected accumulators Once within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of >_ 12%level, indicated, that is not the result of addition from the refueling water storage tank SR 3.5.1.5 Verify power is removed from each accumulator isolation valve operator when RCS pressure is-> 2000 psig.Farley Units I and 2 3.5.1-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

ECCS -Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 --------------------

NOTE -----------------

Only required to be performed for valves 8132A and 8132B when Centrifugal Charging Pump A is inoperable.

Verify the following valves are in the listed position with power to the valve operator removed.Number Position Function 8884, 8886 Closed Centrifugal Charging Pu p to RCSHo eg 8132A, 8132B Open Centrifu I Chargin Pump discha ge isolat' n 8889 Closed R to RCS Hot L g jInjection SR 3.5.2.2 Verify each ECCS manual, power erated, and automatic valve in the flow path, t at is not locked, sealed, or otherwise secured in sition, is in the correct position.SR 3.5.2.3 Verify each ECCS pump's de eloped head the test In accordance with flow point is greater than or qual to thequired the Inservice developed head. Program S R 3.5.2.4 Verify each ECC auo-atic val in the flow path eah that is not lokes rl ort lerwvise secured/position, actuates tot e co / ect position n actual or simulated actuatio si al.Insert 1 Farley Units 1 and 2 3.5.2-2 Amendment No. R (Unit 1)Amendment No. (Unit 2)

ECCS-- Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify each ECCS pump starts automatically on an actual or simulated actuation signal.SR 3.5.2.6 Verify, for each ECCS throttle valve listed below, each position stop is in the correct position.Valve Number CVC-V-8991 A/B/C CVC-V-8989 A/B/C CVC-V-8996 A/B/C CVC-V-8994 A/B/C RHR-HV 603 A/B SR 3.5.2.7 Verify, by visual inspection, each EC train containment sump suction inlet is n estricted by debris and the suction inlet trash r s, screens nd inner cages are properly installe nd show evidence of structural distress o bnorm corrosion.

I nsert 1 Farley Units 1 and 2 3.5.2-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

ECCS-- Shutdown 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.2 Verify the following valves are in the listed position with power to the valve operator removed.Number Position Function 8706A, Closed RHR pump discha e 8706B to centrifugal ch ing pump suction 8884, Closed Centrifugal arging 8886 pump disc arge to RCS hot legs Insert 1 Farley Units 1 and 2 3.5.3-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 --------------------

NOTE ---------------

Only required to be performed when ambient air temperature is < 35OF.Verify RWST borated water temperature is >_ 350F.SR 3.5.4.2 Verify RWST borated water volume is > 471,000 gallons.SR 3.5.4.3 Verify RWST boron concentration is ppm an< 2500 ppm.Insert 1 Farley Units 1 and 2 3.5.4-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

Seal Injection Flow 3.5.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 ---------------------

NOTE---------------

Not required to be performed until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after the Reactor Coolant System pressure stabilizes at 2215 psig and 2255 psig.Verify manual seal injection throttle valves are adjusted to give a flow within the limits of Figure /3.5.5-1 with the seal water injection flow control valve full open.Insert 1 Farley Units 1 and 2 3.5.5-2 Amendment No. n] (Unit 1)Amendment No. f (Unit 2)

ECCS Recirculation Fluid pH Control System 3.5.6 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)3.5.6 ECCS Recirculation Fluid pH Control System LCO 3.5.6 APPLICABILITY:

The ECCS Recirculation Fluid pH Control System shall be OPERABLE.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ECCS Recirculation Fluid A.1 Restore system to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months pH Control System OPERABLE status.inoperable.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.6.1 Perform a visual inspection of the ECCS Recirculation Fluid pH Control System and verify the following:

a. Three (3) storage baskets are in place, an b. Have maintained their integrity, and c. Each basket is filled with trisodium ph phate compound such that the level is be een the indicated fill marks on the baskets Insert 1 Farley Units 1 and 2 3.5.6-1 Amendment No. (Unit 1)Amendment No. (Unit 2)

Containment Air Locks 3.6.2 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 testing in accordance with the Containment Leakage Rate Testing Program.In accordance with the Containment Leakage Rate Testing Program SR 3.6.2.2 Verify only one door in the air lock can be opened at a time.Insert 1 Farley Units 1 and 2 3.6.2-5 Amendment No. (Unit 1)Amendment No. (Unit 2)

Containment Isolation Valves 3.6.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A, B, AND C, or D not met.E.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. One or more penetration F.1 Reduce leakage to within Prior to entering flow paths containing limit. MODE 4 from MODE containment purge 5 if the existing valves, with penetration leakage is determined leakage not within the during quarterly penetration limits. testing per SR 3.6.3.5 OR Insert 1 Prior to entering MODE 4 if excess leakage is determined during MODE 5 per SR 3.6.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each 48 inch purge valve is sealed close except for one purge valve i ation anua flowlv ath while in Condition D of this LCO.S R 3 .6 .3 .2 .............................

N O T E ---------------------------------

Valves and blind flanges in high radiation areas may\be verified by use of administrative controls.

1 Verify each containment isolation manual valve and blind flange that is located outside 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.Farley Units 1 and 2 3.6.3-5 Amendment No. (Unit 1)Amendment No. (Unit 2)

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.3---------------

NOTES ----------------

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.2. The blind flange on the fuel transfer canal flange is only required to be verified closed after each draining of the canal.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 3.6.3.4 Verify the isolation time of each power operated or In accordance with automatic containment isolation valve in the IST the Inservice Program is within limits. Testing Program SR 3.6.3.5 Perform leakage rate testing for containment penetrations containing containment purge valv with resilient seals. AND Ie Within 92 days after opening the valve S R 3.6.3.6 Verify each 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.Farley Units 1 and 2 3.6.3-6 Amendment No. (Unit 1)Amendment No. (Unit 2)

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be >_ -1.5 psig and _< +3.0 psig.APPLICABILITY:

MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment pressure A.1 Restore containment 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not within limits, pressure to within limits.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits.Insert 1 Farley Units 1 and 2 3.6.4-1 Amendment No. (Unit 1)Amendment No. (Unit 2)

Containment Air Temperature 3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 Containment average air temperature shall be < 120 0 F.APPLICABILITY:

MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment average air A.1 Restore containment 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months temperature not within average air temperature limit. to within limit.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment average air temperature is within limit.Insert I Farley Units 1 and 2 3.6.5-1 Amendment No. E (Unit 1)Amendment No. f (Unit 2)

Containment Spray and Cooling Systems 3.6.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Two containment cooling D.1 Restore one containment 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months trains inoperable, cooling train to OPERABLE status.E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition C or D AND not met.E.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. Two containment spray F.1 Enter LCO 3.0.3. Immediately trains inoperable.

OR Any combination of three or more trains inoperable.

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 in the correct position.SR 3.6.6.2 Operate each required containment cooling tr fan unit for >_ 15 minutes.SR 3.6.6.3 Verify each containment cooling train co ing ater flow rate is > 1600 gpm.Insert 1 Farley Units 1 and 2 3.6.6-2 Amendment No. f2 (Unit 1)Amendment No. H (Unit 2)

Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.4 Verify each containment spray pump's developed In accordance with head at the flow test point is greater than or equal to the Inservice the required developed head. Testing Program S R 3.6.6.5 Verify each automatic containment spray valve in the ! cts flow path that is not locked, sealed, or otherwise--

secured in position, actuates to the correct position on an actual or simulated actuation signal.SR 3.6.6.6 Verify each containment spray pump starts automatically on an actual or simulated actuatio signal.S R 3.6.6.7 Verify each containment cooling train starts ._8 automatically on an actual or iuaedact signal. ; ýSR 3.6.6.8 Verify each spray nozzle is unobstruc./Y , E Insert 1 Farley Units 1 and 2 3.6.6-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

HMS 3.6.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY S R 3.6.8.1 Operate each HMS train for >_ 15 minutes.S R 3.6.8.2 Verify each HMS fan speed is >_ 1320 rpm. / 1!mots S R 3.6.8.3 Verify each HMS train starts on an actualor //'!simulated actuation signal./ ,,/...IInsert 1 Farley Units 1 and 2 3.6.8-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

Reactor Cavity Hydrogen Dilution System 3.6.9 3.6 CONTAINMENT SYSTEMS 3.6.9 Reactor Cavity Hydrogen Dilution System LCO 3.6.9 Two Reactor Cavity Hydrogen Dilution trains shall be OPERABLE.APPLICABILITY:

MODES 1 and 2.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Reactor Cavity A.1 Restore the train to 30 days Hydrogen Dilution train OPERABLE status.inoperable.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.9.1 Operate each Reactor Cavity Hydrogen Dilution train for >_ 15 minutes.S R 3.6.9.2 Verify each Reactor Cavity Hydrogen Dilution trai Imchs starts on an actual or simulated actuation sign. ., I'nsert 1 Farley Units 1 and 2 3.6.9-1 Amendment No.= (Unit 1)Amendment No. M (Unit 2)

ARVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each ARV.SR 3.7.4.2 Verify one complete cycle of at least one manual isolation valve in each ARV Line. /Insert 1 Farley Units 1 and 2 3.7.4-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

AFW System 3.7.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Three AFWtrains D.1 ----------

NOTE-------

inoperable.

LCO 3.0.3 and all other LCO Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status.Initiate action to restore Immediately one AFW train to OPERABLE status.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 ---------------------

NOTE ---------------

Not required to be performed for the AFW flow control valves when _< 10% RTP or when the AFW system is not in automatic control.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.Insert 1 Farley Units 1 and 2 3.7.5-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.2 --------------------

NOTE -----------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after >_ 1005 psig in the steam generator.

Verify the developed head of each AFW pump at the In accordance flow test point is greater than or equal to the required with the Inservice developed head. Testing Program.SR 3.7.5.3 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.SR 3.7.5.4 -------------------

NOTE -----------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after > 1005 psig in the steam generator.

Verify each AFW pump starts automatically on n actual or simulated actuation signal.SR 3.7.5.5 Verify the turbine driven AFW pump steam mis mtn valves open when air is supplied from theiresptiv air accumulators.

Insert 1 Farley Units 1 and 2 3.7.5-3 Amendment No. E (Unit 1)Amendment No. H (Unit 2)

CST 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Condensate Storage Tank (CST)LCO 3.7.6 APPLICABILITY:

The CST shall be OPERABLE.MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. CST inoperable.

A.1 Verify by administrative 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months means OPERABILITY of backup water supply. AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND A.2 Restore CST to 7 days OPERABLE status.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the CST level is >_ 150,000 gal.Insert 1 Farley Units 1 and 2 3.7.6-1 Amendment No. (Unit 1)Amendment No. (Unit 2)

CCW System 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1----------------

NOTE ----------------

Isolation of CCW flow to individual components does not render the CCW System inoperable.

Verify each accessible CCW 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.rl:-ýýSR 3.7.7.2 Verify each CCW automatic valve in the flow pa that is not locked, sealed, or otherwise secured position, actuates to the correct position on an/or simulated actuation signal. 7 SR 3.7.7.3 Verify each CCW pump starts automatical actual or simulated actuation signal.I Insert 1 D--P Farley Units 1 and 2 3.7.7-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

SWS 3.7.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A or B AND not met.C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1----------------

NOTE ----------------

Isolation of SWS flow to individual components does not render the SWS inoperable.

Verify each accessible SWS 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.

/j SR 3.7.8.2 Verify each SWS automatic valve in the flow r is not locked, sealed, or otherwise secured in position, actuates to the correct position ona*or simulated actuation signal. /SR- 3.7.8.3 Verify each SWS pump starts auton actual or simulated actuation signal.SR 3.7.8.4 Verify the integrity of the SWS inspection of the ground area.I Insert 1 Farley Units 1 and 2 3.7.8-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

UHS 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Ultimate Heat Sink (UHS)LCO 3.7.9 APPLICABILITY:

The UHS (Service Water Pond) shall be OPERABLE.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. UHS water level or A.1 Be in MODE 4. 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months temperature not within the required limit(s).

AND A.2 Be in MODE 5. 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Verify water level of UHS is :? 184 ft mean sea level.SR 3.7.9.2 Verify water temperature of _< 95 0 F at the discharo of the Service Water Pumps /Insert 1 JJ Farley Units 1 and 2 3.7.9-1 Amendment No. MM (Unit 1)Amendment No. f (Unit 2)

Control Room 3.7.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Suspend CORE Immediately associated Completion ALTERATIONS.

Time of Condition B not met during movement of AND irradiated fuel assemblies or during CORE E.2 Suspend movement of Immediately ALTERATIONS.

irradiated fuel assemblies.

OR Two CREFS trains inoperable during movement of irradiated fuel assemblies or during CORE ALTERATIONS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Operate each CREFS Pressurization train with the heaters operating and each CREFS Recirculation and Filtration train for > 15 minutes.SR 3.7.10.2 Perform required CREFS filter testing in accordan e In accordance with with the Ventilation Filter Testing Program (VFT .VFTP SIR 3.7.10.3 ---------------

NOTE ------ --- --Not required to be performed in MODES.5 nd 6.Verify each CREES train actuates / nactual or ZEEEýsimulated actuation signal.S Insert1 Farley Units 1 and 2 3.7.10-3 Amendment No. (Unit 1)Amendment No. (Unit 2)

CRACS 3.7.11 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Two CRACS trains D.1 Suspend CORE Immediately inoperable during ALTERATIONS.

movement of irradiated fuel assemblies or during AND CORE ALTERATIONS.

D.2 Suspend movement of Immediately irradiated fuel assemblies.

E. Two CRACS trains E.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, 3, or4.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Verify each CRACS train has the capability to remove the assumed heat load.Insert 1 Farley Units 1 and 2 3.7.11-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

PRF 3.7.12 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME, E. Two PRF trains inoperable E.1 Suspend movement of Immediately during movement of* irradiated fuel irradiated fuel assemblies assemblies in the SFPR.in the SFPR.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 ------------------

NOTE -----------------

Only required to be performed during movement of irradiated fuel assemblies in the SFPR.Verify two PRF trains aligned to the SFPR.SR 3.7.12.2 Operate each PRF train for > 15 minutes in the applicable mode of operation (post LOCA and/or refueling accident).

SR 3.7.12.3 Perform required PRF filter testing in accordance In accordance with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.7.12.4 Verify each PRF train actuates and the norm pent fuel pool room ventilation system isolates on actual or simulated actuation signal.SR 3.7.12.5 Verify one PRF train can maintain a pres re 1! mcOthS G_<-0,125 inches water gauge with res/pet a'to e ST"FAGGERED areas during. .the post LOCA mode of.. era' at R flow rate! <5500 cfm__.S R 3.7.12.6 Verify Onepesrwih

.-' P'RF train ca n maintain #sli .htl l'lnegative'2 I ...fuel handling accidentw modFo=nat W ES-ASIS..rate <5500 S"Insert 1 Farley Units 1 and 2 3.7.12-2 Amendment No. (Unit 1)Amendment No.. (Unit 2)

Fuel Storage Pool Water Level 3.7.13 3.7 PLANT SYSTEMS 3.7.13 Fuel Storage Pool Water Level LCO 3.7.13 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 water A.1 ----------NOTE------

level not within limit. LCO 3.0.3 is not applicable.

Suspend movement of Immediately irradiated fuel assemblies in the fuel storage pool.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.13.1 ;Verify the fuel storage pool water level is > 23 ft above the top of the irradiated fuel assemblies sea in the storage racks.Insert 1 Farley Units 1 and 2 3.7.13-1 Amendment No. (Unit 1)Amendment No. (Unit 2)

Fuel Storage Pool'Boron Concentration 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Fuel Storage Pool Boron Concentration LCO 3.7.14 APPLICABILITY:

The fuel storage pool boron concentration shall be > 2000 ppm.When fuel assemblies are stored in the fuel storage pool.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool'boron

NOTE ----------

concentration not within LCO 3.0.3 is not applicable.

limit.A.1 Suspend movement of fuel Immediately assemblies in the fuel Insert 1 " storage pool.AND rag .A.2 Initiataction to restore Immediately.o fuel storl e pool boron"*_oncentrat n to within lim it."%SURVEILLANCE REQUIREMENTS

__._._"_.SURVEILLANCE FREQUENCY SR 3.7.14.1 Verify the fuel storage pool boron concentration is i within limit.Farley Units 1 and 2 3.7.14-1 Amendment No. .(Unit 1)Amendment No. (Unit 2)

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 within A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months limit.AND A.2 Be'in MODE 5. 36 hour4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months s-SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.16.1 Verify the specific activity of the secondary coolant is<0.10 pCi/gm DOSE EQUIVALENT 1-131.Insert 1 Farley Units 1 and 2 3.7.16-1 Amendment No. (Unit 1)Amendment No. (Unit 2)

Cask Storage Area Boron Concentration Cask Loading Operations 3.7.17 SURVEII SURVEILLANCE SR 3.7.17.1 Verify the cask storage area boron concentration is within limit.Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months prior to entering the Applicability of this LCO.AND Farley Units 1 and 2 3.7.17-2 Amendment No. (Unit1)Amendment No. (Unit2) dESF Room Coolers 3.7.19 SURVEILLANCEREQUIREMENTS

_______SURVEILLANCE I FREQUENCY SR 3.7.19.1 Verify each ESF Room Cooler system manual valve servicing safety-related equipment that is not locked, sealed, or otherwise secured in position, is in the correct position.

/SR 3.7.19.2 Verify each ESF Room Cooler fan starts automatically on an actual or simulated actu signal. /Insert 1 Farley Units 1 and 2 3.7.19-2 Amendment No. EM(Unit 1), Amendment No.H (Unit 2)

AC Sources--Operating

3.8.1 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power availability for each required offsite circuit.SR 3.8.1.2------------------

NOTES----------------

1. Performance of SR 3.8.1.6 satisfies this SR.2. All DG starts may be preceded by an engin prelube period and followed by a warmup period prior to loading.3. A modified DG start involving idling an gradual acceleration to synchronous peed may be used for this SR as recomm nded by;the manufacturer.

When modified art procedures are not used, the time voltage, and frequency tolerances of SR 3.8.1 6 must be met.Verify each DG starts from standb conditions and achieves steady state voltage > 40 V and< 4580 V, and frequency

> 58.8 z and < 61.21.Farley Units 1 and 2 3.8.1-6 Amendment No. (Unit 1)Amendment No. (Unit 2)

AC Sources--

Operating 3.8.1 SURVEILLANCE REQUREMENTS 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 3.8.1.6.Verify each DG is synchronized and loaded and operates for _> 60 minutes at a load > 2700 kW and 2850 kW for the 2850 kW DG and > 3875 kW and4075 kW for the 4075 kW DGs./lfý ; .__ Y -1 SR 3.8.1.4 Verify each day tank contains 900 gal of fuel oi for the 4075 kW DGs and 700 gal of fuel oil for the/2850 kW DG.SR 3.8.1.5 Verify the fuel oil transfer system operates o tra0sfer fuel oil from storage tank to the day tank. I kf SR 3.8.1.6 --------------------

NOTE----------------

All DG starts may be preceded by a en ne relube period.Verify each DG starts from sta y ndition and achieves in 12 seconds, vo -3952 V and frequency

_ 60 Hz.Insert 1 Farley Units 1 and 2 3.8.1-7 Amendment No. E (Unit 1)Amendment No. (Unit 2)

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.7 --------------------

NOTE ----------------

This Surveillance shall not be performed in MODE 1 or 2.Verify manual transfer of AC power sources from the 19-8 normal offsite circuit to the alternate required offsite circuit.SR 3.8.1.8 Verify each DG rejects a load greater than or equa o its associated single largest post-accident load, a d: a. Following load rejection, the speed is 5% of the difference between nominal speed n he overspeed trip setpoint; and b. Following load rejection, the volta le ei_>3740 V and 450V Ins r 1 I Farley Units 1 and 2 3.8.1-8 Amendment No. (Unit 1)Amendment No. (Unit 2)

AC Sources--

Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.9 ---------------------

NOTES ---------------

1. All DG starts may be preceded by an engine prelube period.2. This Surveillance shall not be performed in MODE 1,2, 3, or 4.Verify on an actual or simulated loss of offsite power signal: a. De-energization of emergency buses;b. Load shedding from emergency buses;c. DG auto-starts from standby condition an 1. energizes permanently connecte loads in< 12 seconds,'2. energizes auto-connected sh down loads through automatic lao sequencer, 3. maintains steady state vol ge_ 3740 V and _<'4580 V, 4. maintains steady state requency_ 58.8 Hz and <61.2 z, and 5. supplies permanen y connected and auto-connected s tdown loads for-> 5 minutes.Insert I Farley Units 1 and 2 3.8.1-9 Amendment No. .(Unit 1)Amendment No. (Unit 2)

AC Sources--Operating

3.8.1 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY S R 3.8.1.10 ----------.

N O TE ..... --,--.------------

All DG starts may be preceded by prelube period.Verify on an actual or simulated Engineered Safety Feature (ESF) actuation signal each DG auto-starts from standby condition and: a. In < 12 seconds after auto-start and during tests, achieves voltage > 3952 V;b. In < 12 seconds after auto-start and during tests, achieves frequency

> 60 Hz;c. Operates for >5 minutes and maintains steady state generator voltage and freq ncy of!3740Vand!<458OVand!58.8 H and<61.2 Hz;-------------------

NOTE----------------

SR,3.8.1.10.d and e shall not be perform d in MODE 1 or 2.d. Permanently connected loads main energized from the offsite po r system; and e. Emergency loads are energ ed from the offsite power system.SInsert1I Farley Units 1 and 2 3.8.1-10 Amendment No. (Unit 1)Amendment No. (Unit 2)

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.11 Verify each DG's automatic trips are bypassed on actual or simulated loss of voltage signal on the emergency bus and/or an actual or simulated ESF actuation signal except: a. Engine overspeed;

b. Generator differential current; and c. Low lube oil pressure.SR 3.8.1.12 -------------------------------

NOTE ----------------

Momentary transients below the minimu load specified do not invalidate this test.Verify each DG operatesfor

> 24 h urs: a. For > 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded >43 3 for the 4075 k DGs and_ 31O0kW forte 2850 kWD ,and b. For the remaining hous of the tes oaded407SkWforthe40 5kW D and 2850 Farley Units 1 and 2 3.8A1-11 Amendment No. (Unit 1)Amendment No. (Unit 2)

AC Sources -Operating

3.8.1 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.13-------------------

NOTES---------------

1. This Surveillance shall be performed within 10 minutes of shutting down the DG after the DG has operated > 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded > 4075 kW for the 4075 kW DGs and > 2850 kW for the 2850 kW DG.Momentary transients below the minimum load specified do not invalidate this test.2. All DG starts may be preceded by an engine prelube period.Verify each DG starts and achieves, in < 12 seconds, voltage > 3952 V and frequency

> 60 Hz.(/SR 3.8.1.14-------------------

NOTE ------------

This Surveillance shall not be performed in MODE 1, 2, 3, or 4. 7---------------------------------------------------------------

Verify each DG: a. Synchro*izes with offsite power loaded with emergency loads ur restoration of offsite power;b. Transfers loads to offsite pow c. Returns to ready-to-load op /rati Insert 1 Farley Units I and 2 3.8.1-12 Amendment No. 1 (unit 1)Amendment No. (Unit 2)

AC Sources--

Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.15 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 returning DG to ready-to-load operation.

/SR 3.8.1.16 Verify interval between each sequenced load block within +/- 10% of design interval or 0.5 seconds, /whichever is greater, for each emergency load /sequencer.

/SR 3.8.1.17---------

NOTES ,-1. All DG starts may be preceded by an e/prelube period.2. This Surveillance shall not be per MODE 1, 2, 3, or 4.------------------------------------------------------

Verify on an actual or simulated loss or signal in conjunction with an actual or actuation signal: a. De-energization of emergen b. Load shedding from emer cy c. DG auto-starts from sta y cor 1. energizes perm ent o in: 12 second ý//(continued)

Insert 1 Farley Units 1 and 2 3.8.1-13 Amendment No. (Unit 1)Amendment No. (Unit 2)

AC Sources --Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.17 (continued)

2. energizes auto-connected emergency loads through load sequencer, 3. achieves steady state voltage_> 3740 V and <4580 V, 4. achieves steady state frequency> 58.8 Hz and < 61.2 Hz, and 5. supplies permanently connected and auto-connected emergency loads for_ 5 minutes.SR 3.8.1.18-----------------

NOTE ---------------

Testing of the shared Emergency Diesel Generator (EDG) set (EDG 1-2A or EDG 1C) on either unit may be used to satisfy this surveillance requirement for these EDGs for both units.Verify each DG does not trip and voltage is maintained

< 4990 V and > 3330 V during and following a load rejection of > 1200 kW and 240 kW.SR 3.8.1.19 -------------------

NOTE ---------------

All DG starts may be preceded by an engine relube period.Verify when started simultaneously fr standby condition, each DG achieves, in: 1 seconds, voltage >_ 3952 V and frequency

-0 Hz.L Ins rt Farley Units 1 and 2 3.8.1-14 Amendment No. J@ (Unit 1)Amendment No. (Unit 2)

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. One or more DGs with new D.1 Restore stored fuel oil 30 days fuel oil properties not within properties to within lim its. lirrits.E. One or more DGs with the E.1 Restore at least one 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months required starting air starting air receiver receiver pressure < 350 pressure per affected psig and > 150 psig (for DG to > 350 psig (for DG DG 1-2A, 1B, and 2B), or 1-2A, 1 B, and 2B) or< 200 psig and > 90 psig > 200 psig (for DG 1C).(for DG lC).F. Required Action and F.1 Declare associated DG Immediately associated Completion' inoperable.

Time not met.OR One or more DGs diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than Condition A, B, C, D, or E.SURVEILLANCEREQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verifypbeach fuel oil storage tank contains > 25,000 ga of Useable fuel.Insert 1 Farley. Units 1 and 2 3.8.3-2 Amendment No. (Unit 1)Amendment No. I--J (Unit 2)

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.2 Verify lubricating oil inventory is >_ 238 gal (for DG 1-2A, 1B, and 2B) or > 167 gal (for DG 1C).SR 3.8.3.3 Verify fuel oil properties of new and stored fuel are In accordance with tested in accordance with, and maintained w in the the Diesel Fuel Oil limits of, the Diesel Fuel Oil Testing Progri. Testing Program S R 3.8.3.4 Verify each DG hasat least one airrt receiverwith a pressure >! 350 psig (for DG lX,2", 1 B, a nd n l d>200.psig (for DG 11C). ,-Insert 1 Farley Units 1 and 2 3.8.3-3 Amendment No. (Unit 1)Amendment No: (Unit 2)

DC Sources -Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is > 127.8 V on float charge.SR 3.8.4.2 Verify no visible corrosion at battery terminals and connectors.

OR Verify post-to-post battery connection resistance f each cell-to-cell and terminal connection is-< 15 microhms for the Auxiliary Building batteries ante< 150t0 microhms for the SWIS batteries.

S R 3.8.4.3 Verify battery cells, cell plates, and racks sh n visual indication of physical damage or abn ra deterioration.

S R 3.8.4.4 Remove visible terminal corrosion, verify ter cell- to-cell and terminal connections a~r~oaed anti-corrosion material.SR 3.8.4.5 Verify post-to-post battery connection sist 'c of each Cell-to-cell and terminal connec h i -<5 microhms forthe Auxiliary Building<5 1500 microhms for the SWIS batie Inser 1 Farley Units I and-2 3.8.4-2 Amendment No. P (Unit 1)Amendment No. V (Unit 2)

DC Sources--

Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY" SR 3.8.4.6 .--------------

NOTE-- ---- -------------------

This Surveillance may be performed in MODE 1, 2, 3, 4, 5, or 6 provided spare or redundant charger(s) placed in service are .within surveillance frequency to maintain DC subsystem(s)

OPERABLE.Verify each required Auxiliary Building battery charger supplies > 536 amps at > 125 V for _> 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and each required SWIS battery charger supplies 3 amps at _> 125 V for > 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .SR 3.8.4.7 --------------------

NOTES----

1. The performance discharge test in SR 3.8.4.may be performed in lieu of the service test SR 3.8.4.7 once per 60 months.2. The modified performance discharge test n SR 3.8.4.8 may be performed in lieu of the s rvice test at any time.3. This Surveillance shall not be perform d for the Auxiliary Building batteries in MODE, 2, 3, or4.Verify battery capacity is adequate to su ply, and maintain in OPERABLE status, the req ired emergency loads for-the design load pofile describ in the Final Safety Analysis Report, S ction 8.3.2 y subjecting the battery to a service te t.Insert 1 Farley Units 1 and 2 3.8.4-3 Amendment No. (Unit 1)Amendment (Unit 2)

DC Sources-Operating

3.8.4 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.8--- ---NOTE ----------------

This Surveillance shall not be performed for the Auxiliary Building batteries 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.AND 18 months when battery shows degradation or has reached 85% of expected life or 17 years, whichever comes first Insert 1 O Farley Units 1 and 2 3.8.4-4 Amendment No. (Unit 1)Amendment No. (Unit 2)

Battery Cell Parameters

3.8.6 ACTIONS

CONDITION REQUIRED ACTION [COMPLETION TIME B. Required Action and associated Completion Time of Condition A not met.OR One or more required batteries with average electrolyte temperature of the representative cells< 60°F for the Auxiliary Building batteries or < 350F for the SWIS batteries.

OR One or more required batteries with one or more battery cell parameters not within Category C values.OR-NOTE --------Battery terminal voltage of 127.8 volts as measured by SR 3.8.4.1 is equivalent to average cell float voltage of 2.13 volts per cell.One or more required batteries with the average cell float voltage < 2.13 volts.B.1 Declare associated battery inoperable.

Immediately Insert 1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet Table 3.8.6-1 Category A limits.Farley Units 1 and 2 3.8.6-2 Amendment No. f (Unit 1)Amendment No. (Unit 2)

Battery Cell Parameters

3.8.6 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6-1 Category B limits.J AND Once within 7 days after a battery discharge< 110V AND Once within 7 days after a battery overcharge

> 150 V SR 3.8.6.3 Verify average electrolyte temperature of representative cells is _ 60°F for the Auxiliary Building batteries and > 35°F for the SWIS batteries.

Farley Units 1 and 2 3.8.6-3 Amendment No. (Unit 1)Amendment No.* (Unit 2)

Inverters -Operating

3.8.7 ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Timenot met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, frequency, and alignment to required AC vital buses. A Insert 1 Farley Units 1 and 2 3.8.7-2 Amendment No. FT (Unit 1)Amendment No. (Unit 2)

Inverters

-Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.2.4 Initiate action to restore Immediately required inverters to OPERABLE status.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage, frequency, and alignments to required AC vital buses.Insert 1 Farley Units 1 and 2 3.8.8-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

Distribution Systems--

Operating 3.8.9 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A, B, or AND C not met.D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. One Service Water Intake E.1 Declare the associated Immediately Structure (SWIS) DC Service Water train electrical power distribution inoperable.

subsystem inoperable.

F. Two trains with inoperable F.1 Enter LCO 3.0.3. Immediately distribution subsystems that result in a loss of safety function.SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to required AC, DC, and ACqvital bus electrical power distribution subsystems.

.7 Insert I Farley Units 1 and 2 3.8.9-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

Distribution Systems--

Shutdown 3.8.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.2.4 Initiate actions to restore Immediately required AC, DC, -and AC vital bus electrical power distribution subsystems to OPERABLE status.AND A.2.5 Declare associated Immediately required residual heat removal 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 bus electrical po distribution subsystems.

Insert I~Farley Units 1 and 2 318.10-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

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, the refueling canal, and.the refueling cavity shall be maintained within the limit specified in the COLR.MODE 6.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration not A.1 Suspend CORE Immediately within limit. ALTERATIONS.

IIns ert1 I AND.A.2 Suspend positive Immediately reactivity additions.

AN__D\ ' *A.3 itiate action to restore Immediately bol- ' n concentration to withi imi.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit specified in COLR.Farley Units 1 and 2 3.9.1-1 Amendment No. (Unit 1)Amendment No. (Unit 2)

Nuclear. nstrumentation

3.9.2 Farley

Units 1 and 2 3.9.2-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

Containment Penetrations

3.9.3 Farley

Units 1 and 2 3.9.3-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

RHR and Coolant Circulation

-High Water Level 3.9.4 ACTIONS.CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.4 Close equipment hatch and secure with four bolts.AND A.5 Close one door in each air lock.AND A.6.1 Close each penetration providing direct access.from the containment atmosphere to the outside atmosphere with a manual or automatic isolation valve, blind flange, or equivalent.

OR A.6.2 Verify each penetration is capable of being closed by an.OPERABLE Containment Purge and exhaust Isolation System.4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 4 hours 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 4 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify one RHR loop is in operation and circulating reactor coolant at a flow rate of > 3000 gpm..Insert 1 Farley Units 1 and 2 3.9.4-2 Amendment No. (Unit 1)Amendment No. (Unit 2)

RHR and Coolant Circulation-Low Water Level 3.9.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY S R 3.9.5.1 Verify one RHR loop is in operation and circulating

]2hu reactor coolant at a flow rate of >! 3000 gpm..SR 3.9.5.2 Verify correct breaker alignment and indicated per available to the required RHR pump that is not*operation.

Insert 1 -Farley Units 1 and 2 3.9.5-3 Amendment No. = (Unit 1)Amendment No. tl (unit 2)

Refueling Cavity Water Level 3.9.6 3.9 REFUELING OPERATIONS

3.9.6 Refueling

Cavity Water Level LCO 3.9.6 APPLICABILITY:

Refueling cavity water level shall be maintained

> 23 ft above the top of reactor vessel flange.During CORE ALTERATIONS, except during latching and unlatching of control rod drive shafts, During movement of irradiated fuel assemblies within containment.

ACTIONS .CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling cavity water level A.1 Suspend CORE Immediately not within limit. ALTERATIONS.

AND A.2 Suspend movement of Immediately irradiated fuel assemblies within Insert 1 [containment.

SURVEILLANCE REQUIREMENTS

_ _'___.SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify refueling cavity water level is > 23 ft above the top of reactor vessel flange.Farley Units 1 and 2 3.9.6-1 Amendment No. (Unit 1)Amendment No. (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.18 Control Room Integrity Program (CRIP) (continued)

A CRIP shall be established to implement the following:

a. Demonstrate, using Regulatory Guide (RG) 1.197 and ASTM E741, that CRE inleakage is less than the below values. The values listed below do not include 10 cfm assumed in accident analysis for ingress / egress.i) 43 cfm when the control room ventilation systems are aligned in the emergency recirculation mode of operation, ii) 600 cfm when the control room ventilation systems are aligned in the isolation mode of operation, and iii) 2,340 cfm when the control room ventilation systems are aligned in the normal mode of operation;

b. Demonstrate that the leakage characteristics of the CRE will not result in simultaneous loss of reactor control capability from the control room and the hot shutdown panels;c. Maintain a CRE configuration control and a design and licensing bases control program and a preventative maintenance program. As a minimum, the CRE configuration control program will determine whether the i) CRE differential pressure relative to adjacent areas and ii) the control room ventilation system flow rates, as determined in accordance with ASME N510-1989 or ASTM E2029-99, are consistent with the values measured at theotime-the ASTM E741 test was performed.

If item i or ii has changed, determine how this change has affected the inleakage characteristics of the CRE. If there has been degradation in the inleakage characteristics of the CRE since the E741 test, then a determination should be made whether the licensing basis analyses remain valid. If the licensing basis analyses remain valid, the CRE remains OPERABLE.d. Test the CRE in accordance with the testing methods and at the frequencies specified in RG 1.197, Revision" 0, May 2003.The provisions of SR 3.0.2 are applicable to the control room inleakage testing frequencies.

,'~ ~ ~ ~ ~~ .., ..........

.. ' -, Farley Units 1 and 2 5.5-15 Amendment No. (Unit 1)Amendment No. (Unit 2)

Joseph M. Farley Nuclear Plant License Amendment Request for Adoption of TSTF-425-A, Revision 3, Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program Using the Consolidated Line Item Improvement Process Enclosure 4 Clean Typed Pages for FNP Proposed TS Changes SDM 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)LCO 3.1.1 SDM shall be within the limits provided in the COLR.APPLICABILITY:

MODE 2 with keff < 1.0, MODES 3, 4, and 5.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Initiate boration to restore Immediately SDM to within limit.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM to be within limits. In accordance with the Surveillance Frequency Control Program Farley Units 1 & 2 3.1.1-1 Amendment No.Amendment No.(Unit 1)(Unit 2)

Core Reactivity

3.1.2 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1------------------

NOTE ----------------

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 measured core reactivity is within +/- 1% Ak/k of predicted values.Once prior to entering MODE 1 after each refueling AND-------- NOTE --------Only required after 60 EFPD In accordance with the Surveillance Frequency Control Program.Farley Units 1 and 2 3.1.2-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Rod Group Alignment Limits 3.1.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. More than one rod not D.1.1 Verify SDM to be within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months within alignment limit, the limits provided in the COLR.OR D.1.2 Initiate boration to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore required SDM to within limit.AND D.2 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify individual rod positions within alignment limit. In accordance with the Surveillance Frequency Control Program SR 3.1.4.2 Verify rod freedom of movement (trippability) by In accordance with moving each rod not fully inserted in the core the Surveillance

> 10 steps in either direction.

Frequency Control Program SR 3.1.4.3 Verify rod drop time of each rod, from the fully Prior to reactor withdrawn position, is < 2.7 seconds from the criticality after beginning of decay of stationary gripper coil voltage each removal of to dashpot entry, with: the reactor head a. Tavg -541 OF; and b. All reactor coolant pumps operating.

Farley Units 1 and 2 3.1.4-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

Shutdown Bank Insertion Limits 3.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each shutdown bank is within the limits In accordance with specified in the COLR. the Surveillance Frequency Control Program Farley Units 1 and 2 3.1.5-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Control Bank Insertion Limits 3.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.2 Verify each control bank insertion is within the limits In accordance with specified in the COLR. the Surveillance Frequency Control Program SR 3.1.6.3 Verify sequence and overlap limits specified in the In accordance with COLR are met for control banks not fully withdrawn the Surveillance from the core. Frequency Control Program Farley Units 1 and 2 3.1.6-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

PHYSICS TESTS Exceptions-MODE 2 3.1.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. RCS lowest loop average C.1 Restore RCS lowest 15 minutes temperature not within loop average limit. temperature to within limit.D. Required Action and D.1 Be in MODE 3. 15 minutes associated Completion Time of Condition C not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 Perform a CHANNEL OPERATION TEST on Prior to initiation of power range and intermediate range channels per PHYSICS TESTS SR 3.3.1.7, SR 3.3.1.8, and Table 3.3.1-1.SR 3.1.8.2 Verify the RCS lowest loop average temperature is In accordance with the> 531 OF. Surveillance Frequency Control Program SR 3.1.8.3 Verify THERMAL POWER is < 5% RTP. In accordance with the Surveillance Frequency Control Program SR 3.1.8.4 Verify SDM to be within the limits provided in the In accordance with the COLR. Surveillance Frequency Control Program Farley Units 1 and 2 3.1.8-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

F 0 (Z)3.2.1 SURVEILLANCE REQUIREMENTS

NOTE -------------------------------------------------------------

During power escalation at the beginning of each cycle, THERMAL POWER may be increased until an equilibrium power level has been achieved, at which a power distribution map is obtained SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify FQ(Z) is within steady state limit.Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND Once after achieving equilibrium conditions after exceeding, by 20% RTP, the THERMAL POWER at which FQ(Z) was last verified AND In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.2.1-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

FQ(Z)3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY.1.SR 3.2.1.2 (continued)

Once after achieving equilibrium conditions after exceeding, by 20% RTP, the THERMAL POWER at which FQ(Z) was last verified AND In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.2.1-5 Amendment No.Amendment No.(Unit 1)(Unit 2)

F.2 3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify FNH is within limits specified in the COLR.Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.2.2-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

AFD 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD)LCO 3.2.3 The AFD in % flux difference units shall be maintained within the limits specified in the COLR.-------------------------

NOTE ------------------------

The AFD shall be considered outside limits when two or more OPERABLE excore channels indicate AFD to be outside limits.APPLICABILITY:

MODE 1 with THERMAL POWER > 50% RTP.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AFD not within limits. A.1 Reduce THERMAL 30 minutes POWER to < 50% RTP.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD within limits for each OPERABLE excore In accordance with channel. the Surveillance Frequency Control Program Farley Units 1 and 2 3.2.3-1 Amendment No.Amendment No.(Unit 1)(Unit 2)

QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY i SR 3.2.4.1-----------------

NOTES---------------

1. With input from one Power Range Neutron Flux channel inoperable and THERMAL POWER< 75% RTP, the remaining three power range channels can be used for calculating QPTR.2. SR 3.2.4.2 may be performed in lieu of this Surveillance.

Verify QPTR is within limit by calculation.

In accordance with the Surveillance Frequency Control Program SR 3.2.4.2 --------------------

NOTE ----------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after input from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWER> 75% RTP.Confirm that the normalized symmetric power In accordance with distribution is consistent with QPTR. the Surveillance Frequency Control Program Farley Units 1 and 2 3.2.4-4 Amendment No.Amendment No.(Unit 1)(Unit 2)

RTS Instrumentation

3.3.1 SURVEILLANCE

REQUIREMENTS

NOTE Refer to Table 3.3.1-1 to determine which SRs apply for each RTS Function.SURVEILLANCE FREQUENCY SR 3.3.1.1 ------------------

NOTE ----------------

Not required to be performed for source range instrumentation until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after THERMAL POWER is < P-6.Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.1.2 -------------------

NOTES---------------

1. Adjust NIS channel if calorimetric calculated power exceeds NIS indicated power by more than +2% RTP.2. Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER is > 15% RTP.Compare results of calorimetric heat balance In accordance with calculation to Nuclear Instrumentation System (NIS) the Surveillance channel output. Frequency Control Program SR 3.3.1.3 -------------------

NOTES---------------

1. Adjust NIS channel if absolute difference is>3%.2. Not required to be performed until 7 days after THERMAL POWER is > 50% RTP.3. Performance of SR 3.3.1.9 satisfies this SR.Compare results of the incore detector In accordance with measurements to NIS AFD. the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.1-9 Amendment No.Amendment No.(Unit 1)(Unit 2)

RTS Instrumentation

3.3.1 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.4 -- ----------------

NOTE ----------------

This Surveillance must be performed on the reactor trip bypass breaker prior to placing the bypass breaker in service.Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.5 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.1.6 Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.7 -- ----------------

NOTE ---------------

Not required to be performed for source range instrumentation prior to entering MODE 3 from MODE 2 until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entry into MODE 3.Perform COT. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.1-10 Amendment No.Amendment No.(Unit 1)(Unit 2)

RTS Instrumentation

3.3.1 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.8---------------

NOTE -----------------

This Surveillance shall include verification that interlocks P-6 and P-10 are in their required state for existing unit conditions.

Perform COT.-------- NOTE --------Only required when not performed in accordance with the Surveillance Frequency Control Program Prior to reactor startup AND Four hours after reducing power below P-6 for source range instrumentation AND Twelve hours after reducing power below P-1 0 for power range and intermediate range instrumentation AND In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.1-11 Amendment No.Amendment No.(Unit 1)(Unit 2)

RTS Instrumentation

3.3.1 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY S R 3.3.1.9----------------

NOTES ---------------

1. Neutron detectors are excluded from the calibration.

2. Not required to be performed until 7 days after THERMAL POWER is > 50% RTP.Calibrate excore channels to agree with incore detector measurements.

In accordance with the Surveillance Frequency Control Program.1.SR 3.3.1.10---------------

NOTES---------------

1. Neutron detectors are excluded from CHANNEL CALIBRATION.

2. This Surveillance shall include verification that the time constants are adjusted to the prescribed values.Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program+SR 3.3.1.11 Perform COT.In accordance with the Surveillance Frequency Control Program AND-------.NOTE ---------Only required when not performed in accordance with the Surveillance Frequency Control Program.(continued)

Farley Units 1 and 2 3.3.1-12 Amendment No.Amendment No.(Unit 1)(Unit 2)

RTS Instrumentation

3.3.1 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.11 (continued)

Prior to reactor startup SR 3.3.1.12 ------------------

NOTE -----------------

Verification of setpoint is not required.Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.13 ------------------

NOTE ----------------

Verification of setpoint is not required.Perform TADOT. Prior to exceeding the P-9 interlock whenever the unit has been in MODE 3, if not performed within the previous 31 days SR 3.3.1.14 -------------------

NOTE ----------------

Neutron detectors are excluded from response time testing.Verify RTS RESPONSE TIME is within limits. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.1-13 Amendment No.Amendment No.(Unit 1)(Unit 2)

ESFAS Instrumentation

3.3.2 ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME L. (continued)

L.2 ---------NOTE -----One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for Surveillance testing, provided the other train is OPERABLE.Restore train to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.OR L.3.1 Be in MODE 3. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months AND L.3.2 Be in MODE 5 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months SURVEILLANCE REQUIREMENTS

NOTE -----------------------------

Refer to Table 3.3.2-1 to determine which SRs apply for each ESFAS Function.SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.2.2 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.2.3 Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.2-6 Amendment No.Amendment No.(Unit 1)(Unit 2)

ESFAS Instrumentation

3.3.2 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.2.4 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.5 Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.6 ---------------------

NOTE ----------------

Verification of setpoint not required.Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.2.7 ---------------------

NOTE ----------------

This Surveillance shall include verification that the time constants are adjusted to the prescribed values.Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.2.8 Perform SLAVE RELAY TEST In accordance with the Surveillance Frequency Control Program SR 3.3.2.9 ---------------------

NOTE ----------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SG pressure is>_ 1005 psig.Verify ESFAS RESPONSE TIMES are within limit. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.2-7 Amendment No.Amendment No.(Unit 1)(Unit 2)

ESFAS Instrumentation

3.3.2 SURVEILLANCE

REQUIREMENTS SR 3.3.2.10 -------------------

NOTE ------------------------

NOTE -----Verification of setpoint not required.

Only required when not performed within previous 92 days.Perform TADOT. Prior to reactor startup Farley Units 1 and 2 3.3.2-8 Amendment No.Amendment No.(Unit 1)(Unit 2)

ESFAS Instrumentation

3.3.2 Table

3.3.2-1 (page 1 of 4)Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT 1. Safety Injection a. Manual Initiation

b. Automatic Actuation Logic and Actuation Relays c. Containment Pressure -High 1 d. Pressurizer Pressure -Low 1,2,3,4 1,2,3,4 2 2 trains 1,2,3 3 B SR 3.3.2.6 C SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.8 D SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9 D SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9 NA NA NA NA<4.5 psig <4.0 psig> 1847 psig > 1850 psig 3 e. Steam Line Pressure (1) Low (2) High Differential Pressure Between Steam Lines 1 per steam line 3 per steam line D SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9 D SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9 2> 5 7 5 (c) psig 2! 5 8 5 (c) psig< 112 psig < 100 psig 1,2,3 (a) Above the P-11 (Pressurizer Pressure) interlock.(b) Above the P-12 (Tavg -Low Low) interlock.(c) Time constants used in the lead/lag controller are t, > 50 seconds and t 2< 5 seconds.Farley Units 1 and 2 3.3.2-9 Amendment No.Amendment No.(Unit 1)(Unit 2)

ESFAS Instrumentation

3.3.2 Table

3.3.2-1 (page 2 of 4)Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT 2. Containment Spray a. Manual Initiation

b. Automatic Actuation Logic and Actuation Relays 1,2,3,4 1,2,3,4 2 2 trains B SR 3.3.2.6 C SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.8 E SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9 NA NA NA NA c. Containment Pressure High -3 1,2,3 4< 28.3 psig 27 psig 3. Containment Isolation a. Phase A Isolation (1) Manual Initiation (2) Automatic Actuation Logic and Actuation Relays (3) Safety Injection b. Phase B Isolation 1,2,3,4 1,2,3,4 2 2 trains B SR 3.3.2.6 C SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.8 NA NA NA NA Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

(1) Manual Initiation (2) Automatic Actuation Logic and Actuation Relays (3) Containment Pressure High -3 1,2,3,4 1,2,3,4 2 2 trains B SR 3.3.2.6 C SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.8 E SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9 NA NA NA NA 1,2,3 4< 28.3 psig 27 psig Farley Units 1 and 2 3.3.2-10 Amendment No.Amendment No.(Unit 1)(Unit 2)

ESFAS Instrumentation

3.3.2 Table

3.3.2-1 (page 3 of 4)Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT 4. Steam Line Isolation 1 per steam a. Manual Initiation 1 , 2 (d), 3 (d) line F SR 3.3.2.6 NA NA b. Automatic 1 , 2 (d), 3 (d) 2 trains G SR 3.3.2.2 NA NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.2.8 Relays c. Containment 1 , 2 (d), 3 (d) 3 D SR 3.3.2.1 17.5 psig 16.2 psig Pressure -High 2 SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9 d. Steam Line 1 , 2 (d), 3 (b)(d) 1 per steam D SR 3.3.2.1 > 5 7 5 (c) psig > 5 8 5 (c) psig Pressure Low line SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9 e. High Steam Flow 1 , 2 (d), 3 (d) 2 per steam D SR 3.3.2.1 (e) (f)in Two Steam line SR 3.3.2.4 Lines SR 3.3.2.7 Coincident with 1 , 2 (d), 3 (d) 1 per loop D SR 3.3.2.1 _542.6°F _543°F Tavg -Low Low SR 3.3.2.4 SR 3.3.2.7 Above the P-1 2 (Tavg -Low Low) interlock.

Time constants used in the lead/lag controller are tl > 50 seconds and t 2 < 5 seconds.Except when one MSIV is closed in each steam line.Less than or equal to a function defined as AP corresponding to 40.3% full steam flow below 20% load, AP increasing linearly from 40.3% full steam flow at 20% load to 110.3% full steam flow at 100% load.Less than or equal to a function defined as AP corresponding to 40% full steam flow between 0% and 20% load and then a AP increasing linearly from 40% steam flow at 20% load to 110% full steam flow at 100% load.(b)(c)(d)(e)(f)Farley Units 1 and 2 3.3.2-11 Amendment No.Amendment No.(Unit 1)(Unit 2)

ESFAS Instrumentation

3.3.2 Table

3.3.2-1 (page 4 of 4)Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT 5. Turbine Trip and Feedwater Isolation 1,2 2 trains a. Automatic Actuation Logic and Actuation Relays b. SG Water Level -High High (P-14)c. Safety Injection H SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.8 SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9 NA NA< 82.4%1,2 3 per SG< 82%Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

6. Auxiliary Feedwater a. Automatic Actuation Logic and Actuation Relays b. SG Water Level -Low Low c. Safety Injection d. Undervoltage Reactor Coolant Pump e. Trip of all Main Feedwater Pumps 1,2,3 1,2,3 2 trains 3 per SG G SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.8 D SR 3.3.2.1 SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.9 (g)NA> 27.6%NA> 28%Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

1,2 3 I SR 3.3.2.5 SR 3.3.2.7 SR 3.3.2.9 J SR 3.3.2.10_ 2640 volts >_ 2680 volts 1 2 per pump NA NA 7. ESFAS Interlocks

a. Automatic Actuation Logic and Actuation Relays b. Reactor Trip, P-4 c. Pressurizer Pressure, P-11 d. Tavg -Low Low, P-12 (Decreasing)(Increasing) 1,2,3 1,2,3 1,2,3 1,2,3 2 trains 1 per train, 2 trains 3 1 per loop L SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.8 C SR 3.3.2.6 K SR 3.3.2.4 SR 3.3.2.7 K SR 3.3.2.4 SR 3.3.2.7 NA NA NA NA 5 2003 psig < 2000 psig>_ 542.6°F >_ 543°F 5 545.4°F < 545°F (g) Applicable to MDAFW pumps only.Farley Units 1 and 2 3.3.2-12 Amendment No.Amendment No.(Unit 1)(Unit 2)

PAM Instrumentation

3.3.3 ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition C Table 3.3.3-1 for the not met. channel.E. As required by Required E.1 Be in MODE 3. 6'hours Action D.1 and referenced in AND Table 3.3.3-1.E.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. As required by Required F.1 Initiate action in Immediately Action D.1 and accordance with referenced in Specification 5.6.8.Table 3.3.3-1.SURVEILLANCE REQUIREMENTS

NOTE--------------------------------

SR 3.3.3.1 and SR 3.3.3.2 apply to each PAM instrumentation Function in Table 3.3.3-1.SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required In accordance with instrumentation channel that is normally energized.

the Surveillance Frequency Control Program SR 3.3.3.2 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.3-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Remote Shutdown System 3.3.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Submit a report to the 14 days associated Completion NRC outlining the Time not met for Source preplanned alternate Range Neutron Flux method of ensuring the function.

reactor remains shutdown in the event of a control room evacuation, the cause of the inoperability, and the plans and schedule for restoring the Source Range Neutron Flux monitor to OPERABLE status.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK for each required In accordance with monitoring instrumentation channel that is normally' the Surveillance energized.

Frequency Control Program SR 3.3.4.2 Verify each required control circuit and transfer In accordance with switch is capable of performing the intended function.

the Surveillance Frequency Control Program SR 3.3.4.3 -- ------------------

NOTE ---------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION for each required In accordance with monitoring instrumentation channel. the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.4-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

LOP DG Start Instrumentation

3.3.5 ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME D. ----------

NOTE --------D.1 Verify voltage on Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Only applicable to associated bus is > 3850 Function 3. volts.One Alarm Function channel inoperable on one or more trains.E. Required Action and E.1 Restore bus voltage to > 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion 3850 volts.Time of Condition D not met.F. Required Action and F.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition E AND not met.F.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY S R 3.3.5.1 -------------------

NOTES ----------------

1. TADOT shall exclude actuation of the final trip actuation relay for LOP Functions 1 and 2.2. Setpoint verification not required.Perform TADOT. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.5-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

LOP DG Start Instrumentation

3.3.5 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.2 ---------------------

NOTE---------------

CHANNEL CALIBRATION shall exclude actuation of the final trip actuation relay for Functions 1 and 2.Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.3 -- ------------------

Note ----------------

Response time testing shall include actuation of the final trip actuation relay.Verify ESF RESPONSE TIME within limit. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.5-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

Containment Purge and Exhaust Isolation Instrumentation

3.3.6 SURVEILLANCE

REQUIREMENTS

NOTE -----------------------------

Refer to Table 3.3.6-1 to determine which SRs apply for each Containment Purge and Exhaust Isolation Function.SURVEILLANCE FREQUENCY SR 3.3.6.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.6.2 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.3 Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.4 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.6.5 Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.6 ---------------------

NOTE---------------

Verification of setpoint is not required.Perform TADOT. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.6-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

Containment Purge and Exhaust Isolation Instrumentation

3.3.6 SURVEILLANCE

REQUIREMENTS SR 3.3.6.7 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.8 Verify ESF RESPONSE TIME within limit. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.6-4 Amendment No.Amendment No.(Unit 1)(Unit 2)

Containment Purge and Exhaust Isolation Instrumentation

3.3.6 Table

3.3.6-1 (page 1 of 1)Containment Purge and Exhaust Isolation Instrumentation FUNCTION APPLICABLE REQUIRED SURVEILLANCE TRIP SETPOINT MODES OR OTHER CHANNELS REQUIREMENTS SPECIFIED CONDITIONS

1. Manual Initiation 1,2,3,4, (a), (b) 2 SR 3.3.6.6 NA 2. Automatic Actuation Logic 1,2,3,4 2 trains SR 3.3.6.2 NA and Actuation Relays SR 3.3.6.3 SR 3.3.6.5 SR 3.3.6.8 Containment Radiation 1,2,3,4 1 SR 3.3.6.1 < 2.27 X 10-2 /cc Gaseous (R-24A, B) (a), (b) 2 SR 3.3.6.4 (c)(d)SR 3.3.6.7 5 4.54 X 10-3 pCi/cc (c)(e)2.27 X 10-3 pCi/cc (c)(f)4. Containment Isolation

-Refer to LCO 3.3.2, "ESFAS Instrumentation," Function 3.a., for all initiation functions and Phase A requirements.(a)(b)(c)(d)(e)(f)During CORE ALTERATIONS.

During movement of irradiated fuel assemblies within containment.

Above background with no flow.With mini-purge in operation.

With slow speed main purge in operation.

With fast speed main purge in operation.

Farley Units 1 and 2 3.3.6-5 Amendment No.Amendment No.(Unit 1)(Unit 2)

CREFS Actuation Instrumentation

3.3.7 ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued)

B.2 Place both CREFS trains Immediately in emergency recirculation mode.C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for Condition A AND or B not met in MODE 1, 2, 3, or 4. C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. Required Action and D.1 Suspend CORE Immediately associated Completion ALTERATIONS.

Time for Condition A or B not met during AND movement of irradiated fuel assemblies or D.2 Suspend movement of Immediately during CORE irradiated fuel assemblies.

ALTERATIONS.

SURVEILLANCE REQUIREMENTS-NOTE -------------------------------

SRs apply for each CREFS Actuation Function.Refer to Table 3.3.7-1 to determine which SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.7.2 Perform COT. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.7-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

CREFS Actuation Instrumentation

3.3.7 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.3 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.7.4 Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.7.5 Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.7.6 -- ----------------

NOTE -----------------

Verification of setpoint is not required.Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.7.7 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.7-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

PRF Actuation Instrumentation

3.3.8 SURVEILLANCE

REQUIREMENTS

NOTE--------------------------------

Refer to Table 3.3.8-1 to determine which SRs apply for each PRF Actuation Function.SURVEILLANCE FREQUENCY SR 3.3.8.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.8.2 Perform COT. In accordance with the Surveillance Frequency Control Program SR 3.3.8.3 Perform ACTUATION LOGIC TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.4 Perform MASTER RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.5 Perform SLAVE RELAY TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.8.6 --------------------

NOTE ---------------------

Verification of setpoint is not required.Perform TADOT. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.8-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

PRF Actuation Instrumentation

3.3.8 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.7 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.3.8-4 Amendment No.Amendment No.(Unit 1)(Unit 2)

PRF Actuation Instrumentation

3.3.8 Table

3.3.8-1 (page 1 of 1)PRF Actuation Instrumentation FUNCTION APPLICABLE REQUIRED SURVEILLANCE TRIP SETPOINT MODES OR OTHER CHANNELS REQUIREMENTS SPECIFIED CONDITIONS

1. Manual Initiation 1,2,3,4, (a) 2 trains SR 3.3.8.6 NA 2. Automatic Actuation Logic 1,2,3,4 2 trains SR 3.3.8.3 NA and Actuation Relays SR 3.3.8.4 SR 3.3.8.5 3. Spent Fuel Pool Room (a) 2 SR 3.3.8.1 < 8.73 x 10-3 pCi/cc (b)Radiation Gaseous SR 3.3.8.2 (R-25A, B) SR 3.3.8.7 4. Spent Fuel Pool Room (a) 2 SR 3.3.8.6 NA Ventilation Differential SR 3.3.8.7 Pressure (PDSL-3989A and B)5. Containment Isolation

-Refer to LCO 3.3.2, "ESFAS Instrumentation" Function 3.b, for all initiation Functions and Phase B requirements.(a) During movement of irradiated fuel assemblies in the spent fuel pool room.(b) Above background with no flow.Farley Units 1 and 2 3.3.8-5 Amendment No.Amendment No.(Unit 1)(Unit 2)

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is within the limit In accordance with specified in the COLR. the Surveillance Frequency Control Program SR 3.4.1.2 Verify RCS average temperature is within the limit In accordance with specified in the COLR. the Surveillance Frequency Control Program SR 3.4.1.3 Verify RCS total flow rate is within the limits. In accordance with the Surveillance Frequency Control Program SR 3.4.1.4 ---------------------

NOTE ------------

Not required to be performed until 7 days after90% RTP.Verify by measurement that RCS total flow rate is In accordance with within the limits. the Surveillance Frequency Control Program Farley Units 1 and 2 3.4.1-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

RCS P/T Limits 3.4.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. --------NOTE 1---------C Initiate action to restore Immediately Required Action C.2 shall parameter(s) to within be completed whenever limits.this Condition is entered.AND Requirements of LCO not C.2 Determine RCS is Prior to entering met any time in other acceptable for continued MODE 4 than MODE 1, 2, 3, or 4. operation.

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 In accordance with heatup and cooldown rates are within the limits the Surveillance specified in the PTLR. Frequency Control Program Farley Units 1 and 2 3.4.3-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

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 APPLICABILITY:

Three RCS loops shall be OPERABLE and in operation.

MODES 1 and 2.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of LCO not A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 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 Farley Units 1 and 2 3.4.4-1 Amendment No.Amendment No.(Unit 1)(Unit 2)

RCS Loops--MODE 3 3.4.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. One required RCS loop C.1 Restore required RCS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not in operation, and loop to operation.

reactor trip breakers closed and Rod Control OR System capable of rod withdrawal.

C.2 De-energize all control 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months rod drive mechanisms (CRDMs).D. Two required RCS loops D.1 De-energize all CRDMs. Immediately inoperable.

AND OR D.2 Suspend all operations Immediately No RCS loop in involving a reduction of operation.

RCS boron concentration.

AND D.3 Initiate action to restore Immediately one RCS loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loops are in operation.

In accordance with the Surveillance Frequency Control Program SR 3.4.5.2 Verify steam generator secondary side water levels In accordance with are > 30% (narrow range) for required RCS loops, the Surveillance Frequency Control Program SR 3.4.5.3 Verify correct breaker alignment and indicated power In accordance with are available to the required pump that is not in the Surveillance operation.

Frequency Control Program Farley Units 1 and 2 3.4.5-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

RCS Loops -MODE 4 3.4.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. One required RHR loop B.1 Be in MODE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable.

AND Two required RCS loops inoperable.

C. Required RCS or RHR C.1 Suspend all operations Immediately loops inoperable, involving a reduction of RCS boron concentration.

OR AND No RCS or RHR loop in operation.

C.2 Initiate action to restore Immediately one loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RHR or RCS loop is in operation.

In accordance with the Surveillance Frequency Control Program SR 3.4.6.2 Verify SG secondary side water levels are _> 75% In accordance (wide range) for required RCS loops, with the Surveillance Frequency Control Program SR 3.4.6.3 Verify correct breaker alignment and indicated power In accordance are available to the required pump that is not in with the operation.

Surveillance Frequency Control Program Farley Units 1 and 2 3.4.6-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

RCS Loops -MODE 5, Loops Filled 3.4.7 APPLICABILITY:

MODE 5 with RCS loops filled.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR loop A.1 Initiate action to restore a Immediately inoperable, second RHR loop to OPERABLE status.AND OR Required SGs secondary side water levels not A.2 Initiate action to restore Immediately within limits, required SG secondary side water levels to within limits.B. Required RHR loops B.1 Suspend all operations Immediately inoperable, involving a reduction of RCS boron concentration.

OR AND No RHR loop in operation.

B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation.

In accordance with the Surveillance Frequency Control Program SR 3.4.7.2 Verify SG secondary side water level is > 75% (wide In accordance range) in required SGs. with the Surveillance Frequency Control Program Farley Units 1 and 2 3.4.7-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

RCS Loops--MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.3 Verify correct breaker alignment and indicated power In accordance with are available to the required RHR pump that is not in the Surveillance operation.

Frequency Control Program Farley Units 1 and 2 3.4.7-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

RCS Loops--MODE 5, Loops Not Filled 3.4.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required RHR loops B.1 Suspend all operations Immediately inoperable, involving reduction in RCS boron concentration.

OR AND No RHR loop in operation.

B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation.

In accordance with the Surveillance Frequency Control Program SR 3.4.8.2 Verify correct breaker alignment and indicated power In accordance with are available to the required RHR pump that is not in the Surveillance operation.

Frequency Control Program Farley Units 1 and 2 3.4.8-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Pressurizer

3.4.9 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is < 63.5% indicated.

In accordance with the Surveillance Frequency Control Program SR 3.4.9.2 Verify capacity of each required group of pressurizer In accordance with heaters is > 125 kW. the Surveillance Frequency Control Program SR 3.4.9.3 Verify required pressurizer heaters are capable of In accordance with being powered from an emergency power supply. the Surveillance Frequency Control Program Farley Units 1 and 2 3.4.9-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Pressurizer PORVs 3.4.11 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. More than one block valve F.1 Place associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable.

PORVs in manual control.AND F.2 Restore one block valve 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to OPERABLE status.AND F.3 Restore remaining 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months block valve to OPERABLE status.G. Required Action and G.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition F not AND met.G.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 --------------------

NOTES---------------

1. Not required to be met with block valve closed in accordance with the Required Action of Condition B or E.2. Not required to be performed prior to entry into MODE 3.3. Not required to be performed for Unit 2 for the remainder of operating cycle 16 for block valve Q2B31 MOV8000B.Perform a complete cycle of each block valve. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.4.11-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

Pressurizer PORVs 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.2 ------------------

NOTE -----------------

Not required to be performed prior to entry into MODE 3.Perform a complete cycle of each PORV during In accordance with MODE 3 or 4. the Surveillance Frequency Control Program SR 3.4.11.3 Perform a complete cycle of each PORV using the In accordance with backup PORV control system. the Surveillance Frequency Control Program SR 3.4.11.4 ------------------

NOTE -----------------

Required to be performed only for Unit 2 for the remainder of operating cycle 16.Check power available to the Unit Two PORV block In accordance with valve Q2B31 MOV8000B.

the Surveillance Frequency Control Program Farley Units 1 and 2 3.4.11-4 Amendment No.Amendment No.(Unit 1)(Unit 2)

LTOP System 3.4.12 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. One required RHR relief D.1 Reduce pressurizer level 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months valve inoperable, to < 30% (cold calibrated).

AND D.2 Assign a dedicated 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months operator for RCS pressure monitoring and control.AND D.3 Restore required RHR 7 days relief valve to OPERABLE status.E. Two required RHR relief E.1 Depressurize RCS and 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months valves inoperable, establish RCS vent of> 2.85 square inches.OR Required Action and associated Completion Time of Condition A, C, or D not met.OR LTOP System inoperable for any reason other than Condition A, B, C, or D.Farley Units 1 and 2 3.4.12-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

LTOP System 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify a maximum of one charging pump is In accordance with capable of injecting into the RCS. the Surveillance Frequency Control Program SR 3.4.12.2 Verify each accumulator is isolated.

In accordance with the Surveillance Frequency Control Program SR 3.4.12.3 Verify RHR suction isolation valves are open for each In accordance with required RHR suction relief valve. the Surveillance Frequency Control Program SR 3.4.12.4 -------------------

NOTE ----------------

Only required to be performed when complying with LCO 3.4.12.b.Verify RCS vent -> 2.85 square inches open. In accordance with the Surveillance Frequency Control Program SR 3.4.12.5 Verify each required RHR suction relief valve In accordance with setpoint.

the Inservice Testing Program AND In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.4.12-4 Amendment No.Amendment No.(Unit 1)(Unit 2)

RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1------------------

NOTES ----------------

1. Not required to be performed in MODE 3 or 4 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state operation.

2. Not applicable to primary to secondary LEAKAGE.Verify RCS operational LEAKAGE is within limits by performance of RCS water inventory balance.------- NOTE --------Only required to be performed during steady state operation In accordance with the Surveillance Frequency Control Program SR 3.4.13.2 -- -----------------

NOTE ----------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

Verify primary to secondary LEAKAGE is < 150 In accordance gallons per day through any one SG. with the Surveillance Frequency Control Program Farley Units 1 and 2 3.4.13-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 ----------------

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 RHR 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 inch of valve size up to a maximum of 5 gpm at an RCS pressure > 2215 psig and < 2255 psig.18 months, prior to entering MODE 2 AND Following valve actuation due to automatic or manual action or flow through the valve (except for RCS PIVs located in the RHR flow path)SR 3.4.14.2 ------------------

NOTE---------------

Not required to be met when the RHR System valves are required open in accordance with SR 3.4.12.3.Verify RHR System autoclosure interlock In accordance with causes the valves to close automatically the Surveillance with a simulated or actual RCS pressure Frequency Control signal __ 700 psig and _< 750 psig. Program Farley Units 1 and 2 3.4.14-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SIR 3.4.14.3 ------------------

NOTE -----------------

Not required to be met when the RHR System valves valves are required open in accordance with SIR 3.4.12.3.Verify RHR System open permissive interlock In accordance with prevents the valves from being opened with a the Surveillance simulated or actual RCS pressure signal Frequency Control> 295 psig and _< 415 psig. Program Farley Units 1 and 2 3.4.14-4 Amendment No.Amendment No.(Unit 1)(Unit 2)

RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of the required In accordance with containment atmosphere radioactivity monitor. the Surveillance Frequency Control Program SR 3.4.15.2 Perform COT of the required containment In accordance with atmosphere radioactivity monitor. the Surveillance Frequency Control Program SR 3.4.15.3 Perform CHANNEL CALIBRATION of the required In accordance with containment atmosphere radioactivity monitor. the Surveillance Frequency Control Program SR 3.4.15.4 Perform CHANNEL CALIBRATION of the required In accordance with containment air cooler condensate level monitor. the Surveillance Frequency Control Program Farley Units I and 2 3.4.15-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

RCS Specific Activity 3.4.16 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Tavg < 500°F.Time of Condition A not met.OR DOSE EQUIVALENT 1-131 in the unacceptable region of Figure 3.4.16-1.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify reactor coolant gross specific activity In accordance with< 100/E pCi/gm. the Surveillance Frequency Control Program SR 3.4.16.2 -- ------------------

NOTE ---------------

Only required to be performed in MODE 1.Verify reactor coolant DOSE EQUIVALENT 1-131 In accordance with specific activity < 0.5 pCi/gm. the Surveillance Frequency Control Program AND Between 2 and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a THERMAL POWER change of > 15% RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period Farley Units 1 and 2 3.4.16-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

RCS Specific Activity 3.4.16 SURVIELLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.3 ---------------------

NOTE---------------

Not required to be performed until 31 days after a minimum of 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 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .Determine E from a sample taken in MODE 1 after a In accordance with minimum of 2 effective full power days and 20 days the Surveillance of MODE 1 operation have elapsed since the reactor Frequency Control was last subcritical for > 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months . Program Farley Units 1 and 2 3.4.16-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

Accumulators

3.5.1 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each accumulator isolation valve is fully open. In accordance with the Surveillance Frequency Control Program S R 3.5.1.2 Verify borated water volume in each accumulator is In accordance with> 7555 gallons (31.4%) and < 7780 gallons (58.4%). the Surveillance Frequency Control Program SR 3.5.1.3 Verify nitrogen cover pressure in each accumulator is In accordance with> 601 psig and _< 649 psig. the Surveillance Frequency Control Program SR 3.5.1.4 Verify boron concentration in each accumulator is In accordance with> 2200 ppm and < 2500 ppm. the Surveillance Frequency Control Program AND------- NOTE -------Only required to be performed for affected accumulators Once within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of > 12%level, indicated, that is not the result of addition from the refueling water storage tank SR 3.5.1.5 Verify power is removed from each accumulator In accordance with isolation valve operator when RCS pressure is the Surveillance

> 2000 psig. Frequency Control Program Farley Units 1 and 2 3.5.1-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

ECCS -Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1----------------

NOTE ---------------------------------

Only required to be performed for valves 8132A and 8132B when Centrifugal Charging Pump A is inoperable.

Verify the following valves are in the listed position with power to the valve operator removed.In accordance with the Surveillance Frequency Control Program Number 8884,8886 8132A, 8132B 8889 Position Closed Open Closed Function Centrifugal Charging Pump to RCS Hot Leg Centrifugal Charging Pump discharge isolation RHR to RCS Hot Leg Injection SR 3.5.2.2 Verify each ECCS manual, power operated, and In accordance with automatic valve in the flow path, that is not locked, the Surveillance sealed, or otherwise secured in position, is in the Frequency Control correct position.

Program SR 3.5.2.3 Verify each ECCS pump's developed head at the test In accordance with flow point is greater than or equal to the required the Inservice developed head. Testing Program SR 3.5.2.4 Verify each ECCS automatic valve in the flow path In accordance with that is not locked, sealed, or otherwise secured in the Surveillance position, actuates to the correct position on an actual Frequency Control or simulated actuation signal. Program Farley Units 1 and 2 3.5.2-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

ECCS -Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify each ECCS pump starts automatically on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program SR 3.5.2.6 Verify, for each ECCS throttle valve listed below, In accordance with each position stop is in the correct position.

the Surveillance Valve Number Frequency Control Program CVC-V-8991 A/B/C CVC-V-8989 A/B/C CVC-V-8996 A/B/C CVC-V-8994 A/B/C RHR-HV 603 A/B SR 3.5.2.7 Verify, by visual inspection, each ECCS train In accordance with containment sump suction inlet is not restricted by the Surveillance debris and the suction inlet trash racks, screens, and Frequency Control inner cages are properly installed and show no Program evidence of structural distress or abnormal corrosion.

Farley Units 1 and 2 3.5.2-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

ECCS -Shutdown 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.2 Verify the following valves are in the listed position with power to the valve operator removed.In accordance with the Surveillance Frequency Control Program Number 8706A, 8706B 8884, 8886 Position Function Closed RHR pump discharge to centrifugal charging pump suction Closed Centrifugal charging pump discharge to RCS hot legs Farley Units 1 and 2 3.5.3-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 --------------------

NOTE---------------

Only required to be performed when ambient air temperature is < 35 0 F.Verify RWST borated water temperature is _> 350 F. In accordance with the Surveillance Frequency Control Program SR 3.5.4.2 Verify RWST borated water volume is >_ 471,000 In accordance with gallons. the Surveillance Frequency Control Program SR 3.5.4.3 Verify RWST boron concentration is > 2300 ppm and In accordance with<_ 2500 ppm. the Surveillance Frequency Control Program Farley Units 1 and 2 3.5.4-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Seal Injection Flow 3.5.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 -- ------------------

NOTE ---------------

Not required to be performed until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after the Reactor Coolant System pressure stabilizes at> 2215 psig and < 2255 psig.Verify manual seal injection throttle valves are In accordance with adjusted to give a flow within the limits of Figure the Surveillance 3.5.5-1 with the seal water injection flow control Frequency Control valve full open. Program Farley Units 1 and 2 3.5.5-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

ECCS Recirculation Fluid pH Control System 3.5.6 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)3.5.6 ECCS Recirculation Fluid pH Control System LCO 3.5.6 APPLICABILITY:

The ECCS Recirculation Fluid pH Control System shall be OPERABLE.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ECCS Recirculation Fluid A.1 Restore system to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months pH Control System OPERABLE status.inoperable.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.6.1 Perform a visual inspection of the ECCS In accordance with Recirculation Fluid pH Control System and verify the the Surveillance following:

Frequency Control a. Three (3) storage baskets are in place, and Program b. Have maintained their integrity, and c. Each basket is filled with trisodium phosphate compound such that the level is between the indicated fill marks on the baskets.Farley Units 1 and 2 3.5.6-1 Amendment No.Amendment No.(Unit 1)(Unit 2)

Containment Air Locks 3.6.2 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 testing in accordance with the Containment Leakage Rate Testing Program.In accordance with the Containment Leakage Rate Testing Program SR 3.6.2.2 Verify only one door in the air lock can be opened at In accordance with a time. the Surveillance Frequency Control Program Farley Units 1 and 2 3.6.2-5 Amendment No.Amendment No.(Unit 1)(Unit 2)

Containment Isolation Valves 3.6.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A, B, AND C, or D not met.E.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. One or more penetration F.1 Reduce leakage to within Prior to entering flow paths containing limit. MODE 4 from MODE containment purge 5 if the existing valves, with penetration leakage is determined leakage not within the during quarterly penetration limits. testing per SR 3.6.3.5 OR Prior to entering MODE 4 if excess leakage is determined during MODE 5 per SR 3.6.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each 48 inch purge valve is sealed closed, In accordance with except for one purge valve in a penetration flow path the Surveillance while in Condition D of this LCO. Frequency Control Program SR 3.6.3.2 -- ----------------

NOTE -----------------

Valves and blind flanges in high radiation areas may be verified by use of administrative controls.Verify each containment isolation manual valve and In accordance with blind flange that is located outside containment and the Surveillance not locked, sealed, or otherwise secured and Frequency Control required to be closed during accident conditions is Program closed, except for containment isolation valves that are open under administrative controls.Farley Units 1 and 2 3.6.3-5 Amendment No.Amendment No.(Unit 1)(Unit 2)

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.3-----------------

NOTES ----------------

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.2. The blind flange on the fuel transfer canal flange is only required to be verified closed after each draining of the canal.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 3.6.3.4 Verify the isolation time of each power operated or In accordance with automatic containment isolation valve in the IST the Inservice Program is within limits. Testing Program SR 3.6.3.5 Perform leakage rate testing for containment In accordance with penetrations containing containment purge valves the Surveillance with resilient seals. Frequency Control Program AND Within 92 days after opening the valve SR 3.6.3.6 Verify each automatic containment isolation valve In accordance with that is not locked, sealed or otherwise secured in the Surveillance position, actuates to the isolation position on an Frequency Control actual or simulated actuation signal. Program Farley Units land 2 3.6.3-6 Amendment No.Amendment No.(Unit 1)(Unit 2)

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 APPLICABILITY:

Containment pressure shall be > -1.5 psig and < +3.0 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 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not within limits, pressure to within limits.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.6.4-1 Amendment No.Amendment No.(Unit 1)(Unit 2)

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 < 120'F.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment average air A.1 Restore containment 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months temperature not within average air temperature limit, to within limit.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment average air temperature is within In accordance with limit. the Surveillance Frequency Control Program Farley Units 1 and 2 3.6.5-1 Amendment No.Amendment No.(Unit 1)(Unit 2)

Containment Spray and Cooling Systems 3.6.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Two containment cooling D.1 Restore one containment 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months trains inoperable, cooling train to OPERABLE status.E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition C or D AND not met.E.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. Two containment spray F.1 Enter LCO 3.0.3. Immediately trains inoperable.

OR Any combination of three or more trains inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power In accordance with operated, and automatic valve in the flow path that is the Surveillance not locked, sealed, or otherwise secured in position is Frequency Control in the correct position.

Program SR 3.6.6.2 Operate each required containment cooling train fan In accordance with unit for >_ 15 minutes. the Surveillance Frequency Control Program SR 3.6.6.3 Verify each containment cooling train cooling water In accordance with flow rate is >_ 1600 gpm. the Surveillance Frequency Control Program Farley Units 1 and 2 3.6.6-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.4 Verify each containment spray pump's developed In accordance with head at the flow test point is greater than or equal to the Inservice the required developed head. Testing Program SR 3.6.6.5 Verify each automatic containment spray valve in the In accordance with flow path that is not locked, sealed, or otherwise the Surveillance secured in position, actuates to the correct position Frequency Control on an actual or simulated actuation signal. Program SR 3.6.6.6 Verify each containment spray pump starts In accordance with automatically on an actual or simulated actuation the Surveillance signal. Frequency Control Program SR 3.6.6.7 Verify each containment cooling train starts In accordance with automatically on an actual or simulated actuation the Surveillance signal. Frequency Control Program SR 3.6.6.8 Verify each spray nozzle is unobstructed.

In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.6.6-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

HMS 3.6.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.8.1 Operate each HMS train for >_ 15 minutes. In accordance with the Surveillance Frequency Control Program SR 3.6.8.2 Verify each HMS fan speed is > 1320 rpm. In accordance with the Surveillance Frequency Control Program SR 3.6.8.3 Verify each HMS train starts on an actual or In accordance with simulated actuation signal. the Surveillance Frequency Control Program Farley Units 1 and 2 3.6.8-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Reactor Cavity Hydrogen Dilution System 3.6.9 3.6 CONTAINMENT SYSTEMS 3.6.9 Reactor Cavity Hydrogen Dilution System LCO 3.6.9 Two Reactor Cavity Hydrogen Dilution trains shall be OPERABLE.APPLICABILITY:

MODES 1 and 2.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Reactor Cavity A.1 Restore the train to 30 days Hydrogen Dilution train OPERABLE status.inoperable.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.9.1 Operate each Reactor Cavity Hydrogen Dilution train In accordance with for > 15 minutes. the Surveillance Frequency Control Program SR 3.6.9.2 Verify each Reactor Cavity Hydrogen Dilution train In accordance with starts on an actual or simulated actuation signal. the Surveillance Frequency Control Program Farley Units 1 and 2 3.6.9-1 Amendment No.Amendment No.(Unit 1)(Unit 2)

ARVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each ARV. In accordance with the Surveillance Frequency Control Program SR 3.7.4.2 Verify one complete cycle of at least one manual In accordance with isolation valve in each ARV Line. the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.4-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

AFW System 3.7.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Three AFW trains D.1 -----------

NOTE -------inoperable.

LCO 3.0.3 and all other LCO Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status.Initiate action to restore Immediately one AFW train to OPERABLE status.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 -------------------

NOTE ----------------

Not required to be performed for the AFW flow control valves when _< 10% RTP or when the AFW system is not in automatic control.Verify each AFW manual, power operated, and In accordance automatic valve in each water flow path, and in both with the steam supply flow paths to the steam turbine driven Surveillance pump, that is not locked, sealed, or otherwise Frequency secured in position, is in the correct position.

Control Program Farley Units 1 and 2 3.7.5-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.2 --------------------

NOTE -----------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after >_ 1005 psig in the steam generator.

Verify the developed head of each AFW pump at the In accordance flow test point is greater than or equal to the required with the Inservice developed head. Testing Program.SR 3.7.5.3 Verify each AFW automatic valve that is not locked, In accordance sealed, or otherwise secured in position, actuates to with the the correct position on an actual or simulated Surveillance actuation signal. Frequency Control Program SR 3.7.5.4 -- ----------------

NOTE -----------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after _ 1005 psig in the steam generator.

Verify each AFW pump starts automatically on an In accordance actual or simulated actuation signal. with the Surveillance Frequency Control Program SR 3.7.5.5 Verify the turbine driven AFW pump steam admission In accordance valves open when air is supplied from their respective with the air accumulators.

Surveillance Frequency Control Program Farley Units 1 and 2 3.7.5-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

CST 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Condensate Storage Tank (CST)LCO 3.7.6 The CST shall be OPERABLE.APPLICABILITY:

MODES 1, 2, and 3.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. CST inoperable.

A.1 Verify by administrative 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months means OPERABILITY of backup water supply. AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND A.2 Restore CST to 7 days OPERABLE status.B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the CST level is > 150,000 gal. In accordance with the Surveillance Frequency Control Program Farley Units I and 2 3.7.6-1 Amendment No.Amendment No.(Unit 1)(Unit 2)

CCW System 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 -- -----------------

NOTE ----------------

Isolation of CCW flow to individual components does not render the CCW System inoperable.

Verify each accessible CCW manual, power In accordance with operated, and automatic valve in the flow path the Surveillance servicing safety related equipment, that is not locked, Frequency Control sealed, or otherwise secured in position, is in the Program correct position.SR 3.7.7.2 Verify each CCW automatic valve in the flow path In accordance with that is not locked, sealed, or otherwise secured in the Surveillance position, actuates to the correct position on an actual Frequency Control or simulated actuation signal. Program SR 3.7.7.3 Verify each CCW pump starts automatically on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.7-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

SWS 3.7.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A or B AND not met.C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 -- -----------------

NOTE ----------------

Isolation of SWS flow to individual components does not render the SWS inoperable.

Verify each accessible SWS manual, power In accordance with operated, and automatic valve in the flow path the Surveillance servicing safety related equipment, that is not locked, Frequency Control sealed, or otherwise secured in position, is in the Program correct position.SR 3.7.8.2 Verify each SWS automatic valve in the flow path that In accordance with is not locked, sealed, or otherwise secured in the Surveillance position, actuates to the correct position on an actual Frequency Control or simulated actuation signal. Program SR 3.7.8.3 Verify each SWS pump starts automatically on an In accordance with actual or simulated actuation signal. the Surveillance Frequency Control Program SR 3.7.8.4 Verify the integrity of the SWS buried piping by visual In accordance with inspection of the ground area. the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.8-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

UHS 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Ultimate Heat Sink (UHS)LCO 3.7.9 The UHS (Service Water Pond) shall be OPERABLE.APPLICABILITY:

MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. UHS water level or A.1 Be in MODE 4. 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months temperature not within the required limit(s).

AND A.2 Be in MODE 5. 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Verify water level of UHS is >_ 184 ft In accordance with mean sea level. the Surveillance Frequency Control Program SR 3.7.9.2 Verify water temperature of < 95 0 F at the discharge In accordance with of the Service Water Pumps the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.9-1 Amendment No.Amendment No.(Unit 1)(Unit 2)

Control Room 3.7.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Suspend CORE Immediately associated Completion ALTERATIONS.

Time of Condition B not met during movement of AND irradiated fuel assemblies or during CORE E.2 Suspend movement of Immediately ALTERATIONS.

irradiated fuel assemblies.

OR Two CREFS trains inoperable during movement of irradiated fuel assemblies or during CORE ALTERATIONS.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Operate each CREFS Pressurization train with the In accordance with heaters operating and each CREFS Recirculation and the Surveillance Filtration train for >_ 15 minutes. Frequency Control Program SR 3.7.10.2 Perform required CREFS filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). VFTP SR 3.7.10.3 ------------------

NOTE -----------------

Not required to be performed in MODES 5 and 6.In accordance with Verify each CREFS train actuates on an actual or th Sureance simulated actuation signal. the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.10-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

CRACS 3.7.11 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Two CRACS trains D.1 Suspend CORE Immediately inoperable during ALTERATIONS.

movement of irradiated fuel assemblies or during AND CORE ALTERATIONS.

D.2 Suspend movement of Immediately irradiated fuel assemblies.

E. Two CRACS trains E.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, 3, or4.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Verify each CRACS train has the capability to In accordance with remove the assumed heat load. the Surveillance Frequency Control Program I Farley Units 1 and 2 3.7.11-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

PRF 3.7.12 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Two PRF trains inoperable E.1 Suspend movement of Immediately during movement of irradiated fuel irradiated fuel assemblies assemblies in the SFPR.in the SFPR.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 ------------------

NOTE -----------------

Only required to be performed during movement of irradiated fuel assemblies in the SFPR.Verify two PRF trains aligned to the SFPR. In accordance with the Surveillance Frequency Control Program SR 3.7.12.2 Operate each PRF train for > 15 minutes in the In accordance with applicable mode of operation (post LOCA and/or the Surveillance refueling accident).

Frequency Control Program SR 3.7.12.3 Perform required PRF filter testing in accordance with In accordance with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.7.12.4 Verify each PRF train actuates and the normal spent In accordance with fuel pool room ventilation system isolates on an the Surveillance actual or simulated actuation signal. Frequency Control Program SR 3.7.12.5 Verify one PRF train can maintain a pressure In accordance with< -0.125 inches water gauge with respect to adjacent the Surveillance areas during the post LOCA mode of operation at a Frequency Control flow rate 5500 cfm. Program SR 3.7.12.6 Verify one PRF train can maintain a slightly negative In accordance with pressure with respect to adjacent areas during the the Surveillance fuel handling accident mode of operation at a flow Frequency Control rate 5500 cfm. Program Farley Units 1 and 2 3.7.12-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Fuel Storage Pool Water Level 3.7.13 3.7 PLANT SYSTEMS 3.7.13 Fuel Storage Pool Water Level LCO 3.7.13 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 water A.1 ----------NOTE------

level not within limit. LCO 3.0.3 is not applicable.

Suspend movement of Immediately irradiated fuel assemblies in the fuel storage pool.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.13.1 Verify the fuel storage pool water level is 23 ft In accordance with above the top of the irradiated fuel assemblies seated the Surveillance in the storage racks. Frequency Control Program Farley Units 1 and 2 3.7.13-1 Amendment No.Amendment No.(Unit 1)(Unit 2)

Fuel Storage Pool Boron Concentration 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Fuel Storage Pool Boron Concentration LCO 3.7.14 APPLICABILITY:

The fuel storage pool boron concentration shall be > 2000 ppm.When fuel assemblies are stored in the fuel storage pool.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool boron ------------

NOTE ----------

concentration not within LCO 3.0.3 is not applicable.

lim it.A.1 Suspend movement of fuel Immediately assemblies in the fuel storage pool.AND A.2 Initiate action to restore Immediately fuel storage pool boron concentration to within limit.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.14.1 Verify the fuel storage pool boron concentration is In accordance with within limit. the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.14-1 Amendment No.Amendment No.(Unit 1)(Unit 2)

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 IpCi/gm DOSE EQUIVALENT 1-131.MODES 1, 2, 3, and 4.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Specific activity not within A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months limit.AND A.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.16.1 Verify the specific activity of the secondary coolant is In accordance with0.10 pCi/gm DOSE EQUIVALENT 1-131. the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.16-1 Amendment No.Amendment No.(Unit 1)(Unit 2)

Cask Storage Area Boron Concentration Cask Loading Operations 3.7.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.17.1 Verify the cask storage area boron concentration is within limit.Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months prior to entering the Applicability of this LCO.AND In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.7.17-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

ESF Room Coolers 3.7.19 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.19.1 Verify each ESF Room Cooler system manual valve In accordance with servicing safety-related equipment that is not locked, the Surveillance sealed, or otherwise secured in position, is in the Frequency Control correct position.

Program SR 3.7.19.2 Verify each ESF Room Cooler fan starts In accordance with automatically on an actual or simulated actuation the Surveillance signal. Frequency Control Program Farley Units 1 and 2 3.7.19-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

AC Sources--

Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power In accordance with availability for each required offsite circuit. the Surveillance Frequency Control Program SR 3.8.1.2 --------------------

NOTES ----------------

1. Performance of SR 3.8.1.6 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 3.8.1.6 must be met.Verify each DG starts from standby conditions and In accordance with achieves steady state voltage > 3740 V and the Surveillance

_ 4580 V, and frequency

> 58.8 Hz and < 61.2 Hz. Frequency Control Program Farley Units 1 and 2 3.8.1-6 Amendment No.Amendment No.(Unit 1)(Unit 2)

AC Sources--

Operating 3.8.1 SURVEILLANCE REQUREMENTS 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 3.8.1.6.Verify each DG is synchronized and loaded and operates for _> 60 minutes at a load > 2700 kW and 2850 kW for the 2850 kW DG and 3875 kW and: 4075 kW for the 4075 kW DGs.In accordance with the Surveillance Frequency Control Program SR 3.8.1.4 Verify each day tank contains > 900 gal of fuel oil for In accordance with the 4075 kW DGs and 700 gal of fuel oil for the the Surveillance 2850 kW DG. Frequency Control Program SR 3.8.1.5 Verify the fuel oil transfer system operates to transfer In accordance with fuel oil from storage tank to the day tank. the Surveillance Frequency Control Program SR 3.8.1.6 --------------------

NOTE ----------------

All DG starts may be preceded by an engine prelube period.Verify each DG starts from standby condition and In accordance with achieves in < 12 seconds, voltage > 3952 V and the Surveillance frequency

_> 60 Hz. Frequency Control Program Farley Units 1 and 2 3.8.1-7 Amendment No.Amendment No.(Unit 1)(Unit 2)

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.7 -- -----------------

NOTE ----------------

This Surveillance shall not be performed in MODE 1 or 2.Verify manual transfer of AC power sources from the In accordance with normal offsite circuit to the alternate required offsite the Surveillance circuit. Frequency Control Program SR 3.8.1.8 Verify each DG rejects a load greater than or equal to In accordance with its associated single largest post-accident load, and: the Surveillance

a. Following load rejection, the speed is < 75% of Frequency Control the difference between nominal speed and the Program overspeed trip setpoint; and b. Following load rejection, the voltage is> 3740 V and < 4580 V.Farley Units 1 and 2 3.8.1-8 Amendment No.Amendment No.(Unit 1)(Unit 2)

AC Sources- Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.9---------------

NOTES---------------

1. All DG starts may be preceded by an engine prelube period.2. This Surveillance shall not be performed in MODE 1, 2, 3, or 4.Verify on an actual or simulated loss of offsite power 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 < 12 seconds, 2. energizes auto-connected shutdown loads through automatic load sequencer, 3. maintains steady state voltage> 3740 V and < 4580 V, 4. maintains steady state frequency> 58.8 Hz and < 61.2 Hz, and 5. supplies permanently connected and auto-connected shutdown loads for_> 5 minutes.In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.8.1-9 Amendment No.Amendment No.(Unit 1)(Unit 2)

AC Sources--

Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.10-----------------

NOTE ----------------

All DG starts may be preceded by prelube period.Verify on an actual or simulated Engineered Safety Feature (ESF) actuation signal each DG auto-starts from standby condition and: a. In < 12 seconds after auto-start and during tests, achieves voltage _> 3952 V;b. In < 12 seconds after auto-start and during tests, achieves frequency

> 60 Hz;c. Operates for >_ 5 minutes and maintains a steady state generator voltage and frequency of _> 3740 V and < 4580 V and > 58.8 Hz and< 61.2 Hz;------------------

NOTE ----------------

SR 3.8.1.10.d and e shall not be performed in MODE 1 or 2.d. Permanently connected loads remain energized from the offsite power system; and e. Emergency loads are energized from the offsite power system.In accordance with the Surveillance Frequency Control Program Farley Units 1 and 2 3.8.1-10 Amendment No.Amendment No.(Unit 1)(Unit 2)

AC Sources--

Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.11 Verify each DG's automatic trips are bypassed on In accordance with actual or simulated loss of voltage signal on the the Surveillance emergency bus and/or an actual or simulated ESF Frequency Control actuation signal except: Program a. Engine overspeed;

b. Generator differential current; and c. Low lube oil pressure.SR 3.8.1.12 --------------------

NOTE ----------------

Momentary transients below the minimum load specified do not invalidate this test.Verify each DG operates for > 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s: In accordance with the Surveillance

a. For _> 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded _> 4353 for the 4075 kW Frequency DGs and > 3100 kW for the 2850 kW DG; and Frequency Control Program b. For the remaining hours of the test loaded>_ 4075 kW for the 4075 kW DGs and > 2850 kW for the 2850 kW DG.Farley Units 1 and 2 3.8.1-11 Amendment No.Amendment No.(Unit 1)(Unit 2)

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.13----------------

NOTES ---------------

1. This Surveillance shall be performed within 10 minutes of shutting down the DG after the DG has operated _> 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded _> 4075 kW for the 4075 kW DGs and _> 2850 kW for the 2850 kW DG.Momentary transients below the minimum load specified do not invalidate this test.2. All DG starts may be preceded by an engine prelube period.Verify each DG starts and achieves, in < 12 seconds, voltage > 3952 V and frequency

> 60 Hz.In accordance with the Surveillance Frequency Control Program SR 3.8.1.14---------------

NOTE ---------------

This Surveillance shall not be performed in MODE 1, 2, 3, or 4.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 Farley Units 1 and 2 3.8.1-12 Amendment No.Amendment No.(Unit 1)(Unit 2)

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.15 Verify, with a DG operating in test mode and In accordance with connected to its bus, an actual or simulated ESF the Surveillance actuation signal overrides the test mode by returning Frequency Control DG to ready-to-load operation.

Program SR 3.8.1.16 Verify interval between each sequenced load block is In accordance with within +/- 10% of design interval or 0.5 seconds, the Surveillance whichever is greater, for each emergency load Frequency Control sequencer.

Program SR 3.8.1.17 --------------------

NOTES---------------

1. All DG starts may be preceded by an engine prelube period.2. This Surveillance shall not be performed in MODE 1, 2, 3, or 4.Verify on an actual or simulated loss of offsite power In accordance with signal in conjunction with an actual or simulated ESF the Surveillance actuation signal: Frequency Control a. De-energization of emergency buses; Program b. Load shedding from emergency buses; and c. DG auto-starts from standby condition and: 1. energizes permanently connected loads in < 12 seconds, (continued)

Farley Units 1 and 2 3.8.1-13 Amendment No.Amendment No.(Unit 1)(Unit 2)

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY I SR 3.8.1.17 (continued)

2. energizes auto-connected emergency loads through load sequencer, 3. achieves steady state voltage> 3740 V and < 4580 V, 4. achieves steady state frequency> 58.8 Hz and < 61.2 Hz, and 5. supplies permanently connected and auto-connected emergency loads for> 5 minutes.SR 3.8.1.18 --------------------

NOTE---------------

Testing of the shared Emergency Diesel Generator (EDG) set (EDG 1-2A or EDG 1C) on either unit may be used to satisfy this surveillance requirement for these EDGs for both units.Verify each DG does not trip and voltage is In accordance with maintained

< 4990 V and > 3330 V during and the Surveillance following a load rejection of > 1200 kW and < 2400 Frequency Control kW. Program SR 3.8.1.19 --------------------

NOTE--------------

All DG starts may be preceded by an engine prelube period.Verify when started simultaneously from standby In accordance with condition, each DG achieves, in < 12 seconds, the Surveillance voltage >_ 3952 V and frequency

> 60 Hz. Frequency Control Program Farley Units 1 and 2 3.8.1-14 Amendment No.Amendment No.(Unit 1)(Unit 2)

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. One or more DGs with new D.1 Restore stored fuel oil 30 days fuel oil properties not within properties to within limits, limits.E. One or more DGs with the E.1 Restore at least one 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months required starting air starting air receiver receiver pressure < 350 pressure per affected psig and > 150 psig (for DG to _> 350 psig (for DG DG 1-2A, 1B, and 2B), or 1-2A, 1B, and 2B) or< 200 psig and > 90 psig > 200 psig (for DG 1C).(for DG 1 C).F. Required Action and F.1 Declare associated DG Immediately associated Completion inoperable.

Time not met.OR One or more DGs diesel fuel oil, lube oil, or starting*air subsystem not within limits for reasons other than Condition A, B, C, D, or E.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains>

25,000 gal In accordance with of useable fuel. the Surveillance Frequency Control Program Farley Units 1 and 2 3.8.3-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.2 Verify lubricating oil inventory is > 238 gal (for In accordance with DG 1-2A, 1B, and 2B) or 167 gal (for DG 1C). the Surveillance Frequency Control Program S R 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are In accordance with tested in accordance with, and maintained within the the Diesel Fuel Oil limits of, the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.4 Verify each DG has at least one air start receiver with In accordance with a pressure > 350 psig (for DG 1-2A, 1B, and 2B) and the Surveillance

> 200 psig (for DG 1C). Frequency Control Program Farley Units 1 and 2 3.8.3-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

DC Sources--

Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is _> 127.8 V on float In accordance charge. with the Surveillance Frequency Control Program SR 3.8.4.2 Verify no visible corrosion at battery terminals and In accordance connectors.

with the Surveillance OR Frequency Verify post-to-post battery connection resistance of Control Program each cell-to-cell and terminal connection is < 150 microhms for the Auxiliary Building batteries and< 1500 microhms for the SWIS batteries.

SR 3.8.4.3 Verify battery cells, cell plates, and racks show no In accordance visual indication of physical damage or abnormal with the deterioration.

Surveillance Frequency Control Program SR 3.8.4.4 Remove visible terminal corrosion, verify battery In accordance cell- to-cell and terminal connections are coated with with the anti-corrosion material.

Surveillance Frequency Control Program SR 3.8.4.5 Verify post-to-post battery connection resistance of In accordance each cell-to-cell and terminal connection is _< 150 with the microhms for the Auxiliary Building batteries and Surveillance

< 1500 microhms for the SWIS batteries Frequency Control Program Farley Units 1 and 2 3.8.4-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

DC Sources--

Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.6 ---------------------

NOTE ----------------

This Surveillance may be performed in MODE 1, 2, 3, 4, 5, or 6 provided spare or redundant charger(s) placed in service are within surveillance frequency to maintain DC subsystem(s)

OPERABLE.Verify each required Auxiliary Building battery In accordance with charger supplies > 536 amps at > 125 V for > 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months the Surveillance and each required SWIS battery charger supplies Frequency Control> 3 amps at > 125 V for > 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . Program SR 3.8.4.7 --------------------

NOTES ----------------

1. The performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test in SR 3.8.4.7 once per 60 months.2. The modified performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test at any time.3. This Surveillance shall not be performed for the Auxiliary Building batteries in MODE 1, 2, 3, or 4.Verify battery capacity is adequate to supply, and In accordance with maintain in OPERABLE status, the required the Surveillance emergency loads for the design load profile described Frequency Control in the Final Safety Analysis Report, Section 8.3.2, by Program subjecting the battery to a service test.Farley Units 1 and 2 3.8.4-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

DC Sources--

Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.8-NOTE -------------------------------

This Surveillance shall not be performed for the Auxiliary Building batteries 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 18 months when battery shows degradation or has reached 85% of expected life or 17 years, whichever comes first Farley Units 1 and 2 3.8.4-4 Amendment No.Amendment No.(Unit 1)(Unit 2)

Battery Cell Parameters

3.8.6 ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and associated Completion Time of Condition A not met.OR One or more required batteries with average electrolyte temperature of the representative cells< 60°F for the Auxiliary Building batteries or < 35°F for the SWIS batteries.

OR One or more required batteries with one or more battery cell parameters not within Category C values.OR------NOTE-------

Battery terminal voltage of 127.8 volts as measured by SR 3.8.4.1 is equivalent to average cell float voltage of 2.13 volts per cell.B.1 Declare associated battery inoperable.

Immediately One or more required batteries with the average cell float voltage 2.13 volts.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet Table 3.8.6-1 In accordance with Category A limits, the Surveillance Frequency Control Program Farley Units 1 and 2 3.8.6-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Battery Cell Parameters

3.8.6 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6-1 Category B limits.In accordance with the Surveillance Frequency Control Program AND Once within 7 days after a battery discharge< 110V AND Once within 7 days after a battery overcharge

> 150V SR 3.8.6.3 Verify average electrolyte temperature of In accordance with representative cells is > 60°F for the Auxiliary the Surveillance Building batteries and > 35 0 F for the SWIS batteries.

Frequency Control Program Farley Units 1 and 2 3.8.6-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

Inverters

-Operating 3.8.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, frequency, and In accordance with alignment to required AC vital buses. the Surveillance Frequency Control Program Farley Units 1 and 2 3.8.7-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Inverters

-Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.2.4 Initiate action to restore Immediately required inverters to OPERABLE status.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage, frequency, and In accordance with alignments to required AC vital buses. the Surveillance Frequency Control Program Farley Units 1 and 2 3.8.8-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Distribution Systems--

Operating 3.8.9 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A, B, or AND C not met.D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. One Service Water Intake E.1 Declare the associated Immediately Structure (SWIS) DC Service Water train electrical power distribution inoperable.

subsystem inoperable.

F. Two trains with inoperable F.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 In accordance with required AC, DC, and AC vital bus electrical power the Surveillance distribution subsystems.

Frequency Control Program Farley Units 1 and 2 3.8.9-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Distribution Systems--

Shutdown 3.8.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

A.2.4 Initiate actions to restore Immediately required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.AND A.2.5 Declare associated Immediately required residual heat removal subsystem(s) inoperable and not in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to In accordance with required AC, DC, and AC vital bus electrical power the Surveillance distribution subsystems.

Frequency Control Program Farley Units 1 and 2 3.8.10-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

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, the refueling canal, and the refueling cavity shall be maintained within the limit specified in the COLR.MODE 6.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration not A.1 Suspend CORE Immediately within limit. ALTERATIONS.

AND A.2 Suspend positive Immediately reactivity additions.

AND A.3 Initiate action to restore Immediately boron concentration to within limit.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit specified In accordance with in COLR. the Surveillance Frequency Control Program Farley Units 1 and 2 3.9.1-1 Amendment No.Amendment No.(Unit 1)(Unit 2)

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 Farley Units 1 and 2 3.9.2-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

Containment Penetrations

3.9.3 SURVEILLANCE

REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify each required containment penetration is in the In accordance required status. with the Surveillance Frequency Control Program SR 3.9.3.2 Verify each required containment purge and exhaust In accordance valve actuates to the isolation position on an actual or with the simulated actuation signal Surveillance Frequency Control Program SR 3.9.3.3 ---------------------

NOTE -----------------------------

In accordance Only required for an open equipment hatch. with the Surveillance Verify the capability to install the equipment Frequency Control hatch. Program Farley Units 1 and 2 3.9.3-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

RHR and Coolant Circulation-High Water Level 3.9.4 ACTIONS CONDITION

[ REQUIRED ACTION I COMPLETION TIME A. (continued)

A.4 Close equipment hatch and secure with four bolts.AND A.5 Close one door in each air lock.AND A.6.1 Close each penetration providing direct access from the containment atmosphere to the outside atmosphere with a manual or automatic isolation valve, blind flange, or equivalent.

OR A.6.2 Verify each penetration is capable of being closed by an OPERABLE Containment Purge and exhaust Isolation System.4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 4 hours 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 4 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify one RHR loop is in operation and circulating In accordance with reactor coolant at a flow rate of > 3000 gpm. the Surveillance Frequency Control Program Farley Units 1 and 2 3.9.4-2 Amendment No.Amendment No.(Unit 1)(Unit 2)

RHR and Coolant Circulation--

Low Water Level 3.9.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and circulating In accordance with reactor coolant at a flow rate of > 3000 gpm. the Surveillance Frequency Control Program SR 3.9.5.2 Verify correct breaker alignment and indicated power In accordance with available to the required RHR pump that is not in the Surveillance operation.

Frequency Control Program Farley Units 1 and 2 3.9.5-3 Amendment No.Amendment No.(Unit 1)(Unit 2)

Refueling Cavity Water Level 3.9.6 3.9 REFUELING OPERATIONS

3.9.6 Refueling

Cavity Water Level LCO 3.9.6 APPLICABILITY:

Refueling cavity water level shall be maintained

_> 23 ft above the top of reactor vessel flange.During CORE ALTERATIONS, except during latching and unlatching of control rod drive shafts, During movement of irradiated fuel assemblies within containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling cavity water level A.1 Suspend CORE Immediately not within limit. ALTERATIONS.

AND A.2 Suspend movement of Immediately irradiated fuel assemblies within containment.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify refueling cavity water level is > 23 ft above the In accordance with top of reactor vessel flange. the Surveillance Frequency Control Program Farley Units 1 and 2 3.9.6-1 Amendment No.Amendment No.(Unit 1)(Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.18 Control Room Integrity Program (CRIP) (continued)

A CRIP shall be established to implement the following:

a. Demonstrate, using Regulatory Guide (RG) 1.197 and ASTM E741, that CRE inleakage is less than the below values. The values listed below do not include 10 cfm assumed in accident analysis for ingress / egress.i) 43 cfm when the control room ventilation systems are aligned in the emergency recirculation mode of operation, ii) 600 cfm when the control room ventilation systems are aligned in the isolation mode of operation, and iii) 2,340 cfm when the control room ventilation systems are aligned in the normal mode of operation;

b. Demonstrate that the leakage characteristics of the CRE will not result in simultaneous loss of reactor control capability from the control room and the hot shutdown panels;c. Maintain a CRE configuration control and a design and licensing bases control program and a preventative maintenance program. As a minimum, the CRE configuration control program will determine whether the i) CRE differential pressure relative to adjacent areas and ii) the control room ventilation system flow rates, as determined in accordance with ASME N510-1989 or ASTM E2029-99, are consistent with the values measured at the time the ASTM E741 test was performed.

If item i or ii has changed, determine how this change has affected the inleakage characteristics of the CRE. If there has been degradation in the inleakage characteristics of the CRE since the E741 test, then a determination should be made whether the licensing basis analyses remain valid. If the licensing basis analyses remain valid, the CRE remains OPERABLE.d. Test the CRE in accordance with the testing methods and at the frequencies specified in RG 1.197, Revision 0, May 2003.The provisions of SR 3.0.2 are applicable to the control room inleakage testing frequencies.

5.5.19 Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies.

The program shall ensure that Surveillance Requirements specified in the Technical Specifications (continued)

Farley Units 1 and 2 5.5-15 Amendment No. (Unit 1)Amendment No. (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.19 Surveillance Frequency Control Program (continued) 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.Farley Units 1 and 2 5.5-16 Amendment No.Amendment No.(Unit 1)(Unit 2)

Joseph M. Farley Nuclear Plant License Amendment Request for Adoption of TSTF-425-A, Revision 3, Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program Using the Consolidated Line Item Improvement Process Enclosure 5 Markup for FNP Proposed TS Bases Changes Enclosure 5 Markups for FNP Proposed TS Bases Changes Insert 1 In accordance with the Surveillance Frequency Control Program Insert 2 The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.Insert 3 5.5.19 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 interval 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 E5-1 SDM B 3.1.1 BASES SURVEILLANCE SR 3.1.1.1 (continued)

REQUIREMENTS

e. Xenon concentration;

f. Samarium concentration; and g. Isothermal temperature coefficient (ITC).Using the ITC accounts for Doppler reactivity in this calculation because the reactor is subcritical, and the fuel temperature will be S Insert 2 .changing at the same rate as the RCS.The FrogenceRY of 24 ho-urs; isb dOn the gonreally Glow chango i requir*ed beoro concentrationm and- the low probability of an accident occrrig ithout the required SD.Thsalwtiofrheprto to colloct tho required data, Which fincludes pe~f,9Fming a beoro concentration analysis, and comFplete the calculation.I REFERENCES

1. 10 CFR 50, AppendixA, GDC 26.2. FSAR, Section 15.4.2.3. FSAR, Section 15.2.4.4. 10 CFR 100.5. Letter from D.E. McKinnon to L.K. Mathews, "Operating Procedure for Mode 4/5 Boron Dilution," 90 AP*-G-0041, July 6, 1990.Farley Units 1 and 2 B 3.1.1-6 Revision 9 Core Reactivity B 3.1.2 BASES SURVEILLANCE REQUIREMENTS SR 3.1.2.1 Core reactivity is verified by periodic comparisons of measured and predicted RCS boron concentrations.

The comparison is made, considering that other core conditions are fixed or stable, including control rod position, moderator temperature, fuel temperature, fuel depletion, xenon concentration, and samarium concentration.

The Surveillance is performed prior to entering MODE 1 as an initial check on core conditions and design calculations at BOL. The SR is Isr20 b a Note. The Note indicates that the normalization of predicted cor tQivity to the measured value must take place within the first 60 effective fu r days (EFPD) after each fuel loading.This allows sufficient time for cor itions to reach steady state, but prevents operation for a large fraction o uel cycle without establishing a benchmark for the desin calculations.

Pve subsequent FrFeqUencY Of 31 EI-D, following the initial 60 EFnPD After entering MODE 1, is acceptable, baGe-dn oUV the cIeW rate of corFe changes due to fuel depletionR and the presenceP ef ether idctr (QPT-R, AFID, etc.) for promnpt indic-ation o-f anA anomaly.REFERENCES

1. 10 CFR 50, Appendix A, GDC 26, GDC 28, and GDC 29.2. FSAR, Chapter 15.Farley Units 1 and 2 B 3.1.2-6 Revision 12 Rod Group Alignment Limits B 3.1.4 BASES ACTIONS D.2 (continued) accident analysis assumptions.

Since automatic bank sequencing would continue to cause misalignment, the unit must be brought to a MODE or Condition in which the LCO requirements are not applicable.

To achieve this status, the unit must be brought to at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .The allowed Completion Time 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 3.1.4.1 thFat iRdividual rod poitionS are within alignment lirmitS at a detet arodtha isbeginning to deviate fromA it6 expected position TI-he specified Frequency takes account othei, Frd position information that is continuously available to the operator in the cnrol room, so that during ac;tu al rond motion, deviation caimdiately be dete~ted-.

S Insert 2 S R 3.1.4.2 Verifying each control rod is OPERABLE would require that each rod be ipped. However, in MODES 1 and 2, tripping each control rod would r suIt in radial or axial power tilts, or oscillations.

Exercising each in vidual control rod 2-day provides increased confidence that all ds continue to be OPERABLE without exceeding the alignment limit, yen if they are not regularly tripped. Moving each control rod by 10 Ste s will not cause radial or axial power tilts, or oscillations, to occur.Fe'ec-

~e ne esdrtinohrinomto available.to.

I operat in7......

the ontro .and.. SR3.1.....

.wih. ...is availab!e to the eperatOr iR the centre!l rect and SR 3.! .4.!, which !

of the rods. Between required performances of SR 3.1.4.2 (determination of control rod OPERABILITY by movement), if a control rod(s) is discovered to be immovable, but remains trippable and aligned, the control rod(s) is considered to be OPERABLE.

At any time, if a control rod(s) is immovable, a determination of the trippability (OPERABILITY) of the control rod(s) must be made, and appropriate action taken.(continued)(continued)

Farley Units 1 and 2 B 3.1.4-9 Revision 19 Shutdown Bank Insertion Limits B 3.1.5 BASES SURVEILLANCE SR 3.1.5.1 (continued)

REQUIREMENTS shut down the reactor, and the required SDM will be maintained following a reactor trip. This SR and Frequency ensure that the shutdown banks are withdrawn before the control banks are S Insert 2 wihdan during a unit startup.oporator, a verification o-f shutAdown bank position at a FrFequoncy ot 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , after the reactor is taken critical, is adequate to eRsure that they are within their insetion limits. Also, the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months FrequenR y takes into account other information available in the room f-r the Ipurpose Of monitoring the status of shutdown rod&.REFERENCES

1. 10 CFR 50, AppendixA, GDC 10, GDC 26, and GDC 28.2. 10 CFR 50.46.3. FSAR, Chapter 15.Farley Units 1 and 2 B 3.1.5-5 Revision 12 Control Bank Insertion Limits B 3.1.6 BASES ACTIONS A.1.1, A.1.2, A.2, B.1.1, B.1.2, and B.2 (continued)

The allowed Completion Time of 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for restoring the banks to within the insertion, sequence, and overlaps limits provides an acceptable time or evaluating and repairing minor problems without allowing the plant to remain in an unacceptable condition for an extended period of time.C. 1 If Required Actions A.1 and A.2, or B.1 and B.2 cannot be completed within the associated Completion Times, the plant must be brought to MODE 3, where the LCO is not applicable.

The allowed Completion Time of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 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 SR 3.1.6.1 REQUIREMENTS This Surveillance is required to ensure that the reactor does not achieve criticality with the control banks below their insertion limits.The estimated critical position (ECP) depends upon a number of factors, one of which is xenon concentration.

If the ECP was calculated long before criticality, xenon concentration could change to make the ECP substantially in error. Conversely, determining the ECP immediately before criticality could be an unnecessary burden. There are a number of unit parameters requiring operator attention at that point. Performing the ECP calculation within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months prior to criticality avoids a large error from changes in xenon concentration, but allows the operator some flexibility to schedule the ECP calculation with other startup activities.

Insert 2 SR 3.1.6.2 Vorificati0on Of the control bank insortion limits at a FroequencY-ot 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is to detect control bhanks that ,may be approaching the insertion imits sice, rnormally, little rod motion occurs in I 2 heurs.(continued)

Farley Units 1 and 2 B 3.1.6-5 Revision 19 Control Bank Insertion Limits B 3.1.6 BASES SURVEILLANCE REQUIREMENTS SR 3.1.6.3 (continued)

When control banks are maintained within their insertion limits as checked by SR 3.1.6.2 above, it is unlikely that their sequence and Insert 2 verlap will not be in accordance with requirements provided in the HCOL.A, Fo'-onc",'

of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ic cnciitont Aith thP Fneo,6t1on limit I chock above in SR 3.1.6.2.REFERENCES

1. 10 CFR 50, Appendix A, GDC 10, GDC 26, GDC 28.2. 10 CFR 50.46,1988.

3. FSAR, Section 15.4. FSAR, Section 4.3.2.6.5. FSAR, Section 4.3.2.5.Farley Units 1 and 2 B 3.1.6-6 Revision 9 PHYSICS TESTS Exceptions

-MODE 2 B 3.1.8 BASES ACTIONS D.1 (continued) brought to at least MODE 3 within an additional 15 minutes. The Completion Time of 15 additional minutes is reasonable, based on operating experience, for reaching MODE 3 in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.1.8.1 REQUIREMENTS The power range and intermediate range neutron detectors must be verified to be OPERABLE in MODE 2 by LCO 3.3.1, "Reactor Trip System (RTS) Instrumentation." A CHANNEL OPERATIONAL TEST is performed on each power range and intermediate range channel prior to initiation of the PHYSICS TESTS. This will ensure that the RTS is properly aligned to provide the required degree of core protection during the performance of the PHYSICS TESTS.SR 3.1.8.2 Verification that the RCS lowest loop Tavg is -> 531'F will ensure that the unit is not operating in a condition that could invalidate the safety 30 min'-bk d'-ring the pef ermance of the PHYSICS TESTS w:!!il..... .... the n ot3! nditiens of the safety analyses are no~t Ver 'ation that the THERMAL POWER is -5% RTP will ensure that the pla s not operating in a condition that could invalidate the safety anavses_-

-.Vrfcteqo h T.HERM.AIL POWER at a FrFequepw-Vef

!the initial cdtcnsf the sGfat analyses a;e net '-*eRted.SR 3.1.8.4 The SDM is verified by performing a reactivity balance calculation, considering the following reactivity effects: (continued)

Farley Units 1 and 2 B 3.1.8-7 Revision 19 PHYSICS TESTS Exceptions

-MODE 2 B 3.1.8 BASES SURVEILLANCE REQUIREMENTS SR 3.1.8.4 (continued)

a. RCS boron concentration;

b. Control bank position;c. RCS average temperature;

d. Fuel burnup based on gross thermal energy generation;

e. Xenon concentration;

f. Samarium concentration; and g. Isothermal temperature coefficient (ITC).Using the ITC accounts for Doppler reactivity in this calculation because the reactor is relatively steady-state, and the fuel temperature will be changing at the same rate as the RCS.REFERENCES 2.2.3.4.5.6.7.10 CFR 50, Appendix B, Section XI.10 CFR 50.59.Regulatory Guide 1.68, Revision 2, August, 1978.ANSI/ANS-1 9.6.1-1985, December 13, 1985.WCAP-9273-NP-A, "Westinghouse Reload Safety Evaluation Methodology Report," July 1985.WCAP-1 1618, including Addendum 1, April 1989.WCAP-1 3361-NP-A, "Westinghouse Dynamic Rod Worth Measurement Technique," January 1996.Farley Units 1 and 2 B 3.1.8-8 Revision 12 FQ(Z)B 3.2.1 BASES SURVEILLANCE SR 3.2.1.1 (continued)

REQUIREMENTS If THERMAL POWER has been increased by -> 20% RTP since the last determination of FQ(Z), another evaluation of this factor is required after achieving equilibrium conditions at this higher power level (to ensure that FQ(Z) values are being reduced sufficiently with Insert 2 power increase to stay within the LCO limits).'*'The Frequency of 31 EFPD is adequate to monitor the change of power distribution With coro burnup becauso such changes are slow and well controlled when the plant is operated in accordance w-th the Technical Specifications (TS).SR 3.2.1.2 This surveillance is performed using the movable incore detectors to obtain a power distribution map at THERMAL POWER Levels greater than 5% RTP.This surveillance determines if FQ(Z) (i.e. (Fm (Z)) 1.0815, obtained from incore flux map results) will remain within its limit during a normal operational transient.

If FQ(Z) is determined to exceed the transient limit, Action B.1 requires that the AFD limit be reduced 1% for each 1% FQ(Z) exceeds the transient limit. This will ensure that FQ(Z) will not exceed the transient limit during a normal operational transient within the reduced AFD limit.For this surveillance, the FQ(Z) evaluations are not applicable for the following axial core regions, measured in percent of core height: a. Lower core region, from 0 to 8% inclusive; and b. Upper core region, from 92 to 100% inclusive.

The top and bottom 8% of the core are excluded from the evaluation because of the low probability that these regions would be more limiting in the safety analyses and because of the difficulty of making a precise measurement in these regions.Demonstrating that Fo(Z) is within the transient limit or reducing the AFD limit if the transient FQ(Z) limit was initially exceeded, only (continued)

Farley Units 1 and 2 B 3.2.1-8 Revision [P FQ(Z)B 3.2.1 BASES SURVEILLANCE REQUIREMENTS Insert 2 SR 3.2.1.2 (continued)

I ho Sur'.'eilanco FrFequency of 31 EF=PD is adequate to monitor tho GhaffRgmett ofnn m~n +kne d nlnn+tie Weth1111 nnnrnawr 66,, a Ghak h iinILl V t Vii I 4V.........-- I riof~tmhtecn3 i I ~ to nrocludo advorr~e n~ur. Wel n .Also, the result of this su.h eillaGc .a result i mor.frequent of F1(Z) of REFERENCES

1. 10 CFR 50.46, 1988.2. FSAR, Section 15.4.6.3. 10 CFR 50, Appendix A, GDC 26.4. WCAP-7308-L-P-A, "Evaluation of Nuclear Hot Channel Factor Uncertainties," June 1988.5. WCAP-10216-P-A, Revision 1A, "Relaxation of Constant Axial Offset Control FQ Surveillance Technical Specification," February 1994.Farley Units 1 and 2 B 3.2.1 -10 Revision 9 F N B3H B 3.2.2 BASES SURVEILLANCE REQUIREMENTS Insert 2 1 SR 3.2.2.1 The value of FN is determined by using the movable incore detector system to obtain a flux distribution map. A data reduction computer program then calculates the maximum value of FNHfrom the measured flux distributions.

The measured value of FNH must be multiplied by 1.04 to account for measurement uncertainty before making comparisons to the FAH limit.After each refueling, FNH must be determined in MODE 1 prior to exceeding 75% RTP. This requirement ensures that FNH limits are met at the beginning of each fuel cycle.The 31 EF-FPD FrFequency is accoptable becauso the power distribu tion changos relatively slowly ovor this amoGunt of fulel buRnup. Accordfingly, this FrequoncGy is short enough that the IF2liit cannot be exceeded ror any Gignificant period of operation.

!REFERENCES

1. FSAR, Section 15.4.6.2. 10 CFR 50, Appendix A, GDC 26.3. 10CFR50.46, 1988.4. FSAR, Section 4.4.1.Farley Units 1 and 2 B 3.2.2-7 Revision 19 AFD B 3.2.3 BASES SURVEILLANCE REQUIREMENTS Insert 2 SR 3.2.3.1 This Surveillance verifies that the AFD, as indicated by the NIS excore channel, is within its sned~ifi ,,The Surleillance FrFequencyeof I "7 .J..... Ar ZI. ... -!. ..... .:.J-: -44. L .- { -A I-rn :.. .. 4_ .I_.. -I-+e GARr-RIAPAPCI 1A-q+ +Re Ar=W IS GRITOR914 by a I andI anY doviation fromr rogui*Fre onts is ýAlarmed.GEWREMO REFERENCES

1. WCAP-8403 (nonproprietary), "Power Distribution Control and Load Following Procedures," Westinghouse Electric Corporation, September 1974.2. R. W. Miller et al., "Relaxation of Constant Axial Offset Control: F Q Surveillance Technical Specification," WCAP-10217-A, Rev. I (NP), February 1994.Farley Units 1 and 2 B 3.2.3-4 Revision 9 QPTR B 3.2.4 BASES ACTIONS A.6 (continued) surveillances performed at operating power levels, which can only be accomplished after the excore detectors are normalized to restore QPTR to within limits and the core returned to power.B.1 If Required Actions A.1 through A.6 are not completed within their associated Completion Times, the unit must be brought to a MODE or condition in which the requirements do not apply. To achieve this status, THERMAL POWER must be reduced to < 50% RTP within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . The allowed Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is reasonable, based on operating experience regarding the amount of time required to reach the reduced power level without challenging plant systems.SURVEILLANCE SR 3.2.4.1 REQUIREMENTS SR 3.2.4.1 is modified by two Notes. Note 1 allows QPTR to be calculated with three power range channels if THERMAL POWER is_< 75% RTP and the input from one Power Range Neutron Flux channel is inoperable.

Note 2 allows performance of SR 3.2.4.2 in Insert 2 lieu of SR 3.2.4.1.This Surveillance verifies that the QPTR, as indicated by the Nuclear ,nstrumentation System (NIS) excore channels, is within its limits.larc ..A.. ilY.lablo to th o ritho c;onrol room. For those causes of QPT that occur quickly (e.g., a dropped rod), there typically are other indications of abnormality that prompt a verification of core power tilt.SR 3.2.4.2 This Surveillance is modified by a Note, which states that it is not required until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after the input from one or more Power Range Neutron Flux channels are inoperable and the THERMAL POWER is>75% RTP.(continued)

Farley Units 1 and 2 B 3.2.4-6 Revision 19 QPTR B 3.2.4 BASES SURVEILLANCE REQUIREMENTS SR 3.2.4.2 (continued)

With an NIS power range channel inoperable, tilt monitoring for a portion of the reactor core becomes degraded.

Large tilts are likely detected with the remaining channels, but the capability for detection of small power tilts in some quadrants is der-e -- Ri a. FE q. AL.- ----na. euuL .. ril r u 7 altemative 111- 1u 01 GRPFIRiii tw aGGUracy Of tme QP2I mo8acuFeromot via excore dotoctors and oncuring that any tilt romains, Within its limts-.For purposes of monitoring the QPTR when one power range channel is inoperable, the moveable incore detectors are used to confirm that the normalized symmetric power distribution is consistent with the indicated QPTR and any previous data indicating a tilt. The incore detector monitoring is performed with a full incore flux map or two sets of four thimble locations with quarter core symmetry.

The two sets of four symmetric thimbles is a set of eight unique detector locations.

These locations are C-8, E-5, E-11, H-3, H-13, L-5, L-11, and N-8.The power flux map can be used to generate power "tilt." This can be compared to a reference power tilt, from the most recent calibration flux map. Therefore, incore monitoring of QPTR can be used to confirm the accuracy of the QPTR as indicated by the excore detectors and that QPTR is within limits.REFERENCES

1. 10 CFR 50.46,1988.

2. FSAR, Section 15.4.6.3. 10 CFR 50, Appendix A, GDC 26.Farley Units 1 and 2 B 3.2.4-7 Revision 0 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.1.1 Performance of the CHANNEL CHECK 1GRce er4 !2 he'.'! 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. 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 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 Insert 2 the signal processing equipment has drifted outside its limit.A Note modifies SR 3.3.1.1. The Note provides a clarification that the source range instrumentation surveillance is only required when reactor power is < P-6 and that 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after power is reduced below P-6 is lIlowed for performing the surveillance for this instrumentation.

channel failuro is r.ar. he CHANNEL CHECI4K supplements eI foFrmal, but Moro froquont, chocGkr of channels durFing normFal operational

,,p nf thp d!qn'RvF; w;,th thp I CO rhARRP-Ir SR 3.3.1.2 SR 3.3.1.2 compares the calorimetric heat balance calculation to the NIS channel output every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . If the calorimetric calculated power exceeds the NIS channel indicated power by more than + 2% RTP, the NIS channel is not declared inoperable, but must be adjusted.

If the NIS channel output cannot be properly adjusted, the channel is declared inoperable.

If the calorimetric is performed at part power (< 50% RTP), adjusting the NIS channel indication in the increasing power direction will assure a reactor trip below the safety analysis limit (_< 118% RTP). Making no adjustment to the NIS channel indication in the decreasing power direction due to a part power calorimetric assures a reactor trip consistent with the safety analyses.(continued)

Farley Units 1 and 2 B 3.3.1-50 Revision P I RTS Instrumentation B 3.3.1 BASES SURVEILLANCE SR 3.3.1.2 (continued)

REQUIREMENTS This allowance does not preclude making indicated power adjustments, if desired, when the calorimetric calculated power is less than the NIS channel indicated power. To provide close agreement between indicated power and calorimetric power and to preserve operating margin, the NIS channels are normally adjusted when operating at or near full power during steady-state conditions.

However, discretion must be exercised if the NIS channel indicated power is adjusted in the decreasing power direction due to a part power calorimetric

(< 50%RTP). This action could introduce a non-conservative bias at higher power levels which could result in an NIS reactor trip above the safety analysis limit (> 118% RTP). The cause of the non-conservative bias is the decreased accuracy of the calorimetric at reduced power conditions, as discussed in Westinghouse Technical Bulletin, ESBU-TB-92-14-R1,"Decalibration Effects of Calorimetric Power Level Measurements On The NIS High Power Reactor Trip At Power Levels Less Than 70%RTP," (Ref. 14). To assure a reactor trip below the safety analysis limit, the Power Range Neutron Flux -High bistables are set < 85% RTP: 1)whenever the NIS channel indicated power is adjusted in the decreasing power direction due to a part power calorimetric below 50%RTP; and 2) for a post refueling startup. Before the Power Range Neutron Flux -High bistables are reset < 109% RTP, the NIS channel calibration must be confirmed based on a calorimetric performed

_ 50%RTP.Two Notes modify SR 3.3.1.2. The first Note indicates that the NIS channel output shall be adjusted consistent with the calorimetric calculated power if the calorimetric calculated power exceeds the NIS channel output by more than + 2% RTP. The second Note clarifies that this Surveillance is required only if reactor power is _> 15% RTP and that 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is allowed for performing the first Surveillance after reaching 15% RTP. A power level of 15% RTP is chosen based on plant stability, i.e., automatic rod control capability and turbine generator S Insert 2 sycrnzed to the grid.'T A-r =FW G of ....y .-he 6 .... adequate..

.It. i6 -h-A--- .... .'t operating exoioc, osidering instrument reliability and po)Wer dtrui T.gethor these demon.trate that a diffeFrence

_Abotwoen.

tho- hoa-t bhalance calculated power and the Nils;c-hannel1 6Rindia~tion of mere than + 2%A RTP is nt expected in any In addition, rom operators mRo(n9itor ind s "and- al-arms to detec. deviations0 ion c-,hannel outputs-.(continued)

Farley Units 1 and 2 B 3.3.1-51 Revision P RTS Instrumentation B 3.3.1 BASES SURVEILLANCE SR 3.3.1.3 REQUIREMENTS (continued)

SR 3.3.1.3 compares the incore system to the NIS channel outpu Ft If the absolute difference is > 3% the NIS channel is still OPERABLE, but it must be adjusted.

When the channel is outside the 3% allowance assumed in the setpoint uncertainty calculation, the channel must be adjusted (i.e., normalized) based on incore surveillance data.If the NIS channel cannot be properly adjusted, the channel is declared inoperable.

This Surveillance is performed to periodically verify the f(AI) input to the overtemperature AT Function.Three Notes modify SR 3.3.1.3. Note 1 indicates that the excore NIS channel shall be adjusted if the absolute difference between the incore and excore AFD is _> 3% .Note 2 clarifies that the Surveillance is required only if reactor power is >_ 50% RTP and that 7 days are allowed for performing the Surveillance and channel adjustment, if necessary, after reaching 50% RTP. A power level of >_ 50% RTP is consistent with the requirements of SR 3.3.1.9. Note 3 allows SR 3.3.1.9 to be performed in lieu of SR 3.3.1.3, since SR 3.3.1.9 calibrates (i.e., requires channel adjustment) the excore channels to the incore iInsert 2 an.,b els, it envelopes the performance of SIR 3.3.1.3.For each o tig cycle, the initial channel normalization is performed unde. SR. .3....... ... "ueI ...............

... a t a .. G Of .. evep 'duarig the fuol cyclo, Which cani be dotoctoed during this nevl SR 3.3.1.4 SR 3.3.1.4 is the performance of a TADOT OTVP..2 --ST ERED TEST EMS.I This test shall verify OPERABILITY by actuation of the end devices.The RTB test shall include separate verification of the undervoltage trip via the Reactor Protection System and the local manual shunt trip mechanism.

The bypass breaker test shall include a local manual shunt trip and local manual undervoltage trip. A Note has been added to indicate that this test must be performed on a bypass breaker prior to placing it in service. The independent test of undervoltage and shunt (continued)

Farley Units 1 and 2 B 3.3.1-52 Revision Rq RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS SR 3.3.1.4 (continued) trip circuitry for the bypass breakers for the manual reactor trip function is included in SR 3.3.1.12.

No capability is provided for performing such a test at power.TheF62qWGGYef v Ls6 dy on a STAGGERED TEST B3ASISi R 3.3.1.5 S 3.3.1.5 is the performance of an ACTUATION LOGIC TEST. The S PS is tested F .. dy ,4 a STAGGERED TEST 12 ...... using t e semiautomatic tester. The train being tested is placed in the bypass c(ndition, thus preventing inadvertent actuation.

Through the s miautomatic tester, all possible logic combinations, with and without aI iplicable permissives, are tested for each protection and permissive 1 fE z 5 38.1.6 is the performance of a TADOT if iý -as Refe~ The function is tested up to the SS S logic circuit. Setpoints must be found within the Allowable Values lfed in Table 3.3.1-1 .The test inclu he undervoltage and underfrequency sensing devices that provide actuatio nals directly to the SSPS. The test functionally demonstrates channel OP ILITY including verification of the trip setpoint.

If necessary, the undervebttge/underfrequency setpoint is restored to within calibration tolerance.

I-with retpoint uncortainty calculation allowancoes for rack drifti Refe-renc-e 7 .;nd- analysis moedeled i Re~fe~renc 15.SR 3.3.1.7 is the performance o a A COT is performed on each required channel to ensure the rack components will perform the intended Function.(continued)

Farley Units 1 and 2 B 3.3.1-53 Revision P RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS SR 3.3.1.7 (continued)

Setpoints must be within the Allowable Values specified in Table 3.3.1-1.The "as found" and "as left" data have been evaluated to ensure consistency with (i.e., bounded by) the drift allowance used in the setpoint methodology.

The COT "as found" limits are based, in part, on expected performance of a healthy instrument channel. Appropriate corrective action is taken when the "as found" values exceed the prescribed values. The setpoint shall be left set consistent with the assumptions of the current unit specific setpoint methodology.

SR 3.3.1.7 is modified by a Note that provides a 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months delay in the requirement to perform this Surveillance for source range Insert 2 instrumentation when entering MODE 3 from MODE 2. This Note allows a normal shutdown to proceed without a delay for testing in MODE 2 and for a short time in MODE 3 until the RTBs are open and SR 3.3.1.7 is no longer required to be performed.

If the unit is to be in MODE 3 with the RTBs closed for > 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months this Surveillance must be performed prior to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entry into MODE 3.the Frequency specified in the Surveillance Frequency Control Program specified in the Surveillance Frequency Control Program-R .4 -1 .8 SR 3.3.1.8 is the pe o ce of a COT as described in SR 3.3.1.7, except it is modified by a Note is test shall include verification that the P-6 and P-10 interlocks are in their ed state for the existing unit condition.

The Frequency is modified by a hat allows this surveillance to be satisfied if it has been performed with of the Frequencies prior to reactor startup and four hours after reducing power below P-10 and P-6. The Frequency of "prior to startup" ensures this surveillance is performed prior to critical operations and applies to the source, intermediate and power range low instrument channels.The Frequency of "12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reducing power below P-10" plicable to the intermediate range and the power range low ch nels) and "4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after reducing power below P-6" (applicable to sourc range channels) allows a normal shutdown to be completed and the unit moved from the MODE of Applicability for this surveillance without a lay to perform the testing required by this surveillance.

The Frequency

.84 days th ,Fee applies if the plant remains in the MODE of Applicability after the initial performances of prior to reactor startup and twelve and four hours after reducing power below (continued)

Farley Units 1 and 2 B 3.3.1-54 Revision RR RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS SR 3.3.1.8 (continued)

P-1 0 or P-6, respectively.

The MODE of Applicability for this surveillance is < P-1 0 for the power range low and intermediate range channels and < P-6 for the source range channels.

Once the unit is in MODE 3, this surveillance is no longer required.

If power is to be maintained

< P-10 for more than 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or < P-6 for more than 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , then the testing required by this surveillance must be performed prior to the expiration of the time limit. Twelve hours and four hours are reasonable times to complete the required testing or place the unit in a MODE where this surveillance is no longer required.

This test ensures that the NIS source, intermediate, and power range low channels are OPERABLE prior to taking the reactor critical and after reducing power into the applicable MODE (< P-10 or < P-6) for periods > 12 and 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , respectively, -k ...... U e O ,f ,4 days .'i.'

SR 3.3.1.9~Insert 2 I SR 3.3.1.9 is a calibration of the excore channels to the incore channels based on analysis of a range of core flux distributions or a single core flux distribution coupled with core design information.

If the measurements do not agree, the excore channels are not declared inoperable but must be adjusted (i.e., normalized) to agree with the incore detector measurements.

If the excore channels cannot be adjusted, the channels are declared inoperable.

This Surveillance is performed at BOL to normalize the excore f(AI) input to the overtemperature AT Function fora given operating cycle. The surveillance also normalizes the excore Al indications.

Two Notes modify SR 3.3.1.9. Note 1 states that neutron detectors are excluded from the calibration.

Note 2 specifies that this Surveillance is required only if reactor power is > 50% RTP and that 7 days are allowed for completing the surveillance after reaching 50% RTP. Based on operating experience, a time allowance of 7 days for test performance, data analysis, and channel adjustments is sufficient.

A power level of > 50% RTP corresponds to the power level for the AFD surveillance (SR 3.2.3.1), which requires calibrated excore Al I Insert 2 indications.

The148- Fr=,quncY of 18 monhths i ba6ed6o8n plant exprionc and has proven sufficiont to ostablish the cycle pciccaibration ot the eXcore Al indications and f(AI).-(continued)

Farley Units 1 and 2 B 3.3.1-55 Revision FM RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)

I nsert 2 -SR 3.3.1.10 A CHANELr CAL.1IB8RAT-ION i6 eve.y 18 .months-, or approximately at eveor! rtueling.

CHANNEL CALIBRAI ION is a complete check of the instrument loop, including the sensor. The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.CHANNEL CALIBRATIONS must be performed consistent with the assumptions of the unit specific setpoint methodology.

The "as found" and "as left" data have been evaluated to ensure consistency with (i.e., bounded by) the drift allowance used in the setpoint methodology.

'The PFroquoncy Of 18 monPths; isbaseAd_

on tho- _assumption of anM 18 month calibration interval inthe of the magnitude o, equipmet drif-t in the setpe-fRnt mFethedelogy and the need to pefform this surveillance under the conditions that apply durin~g a plant outage., Operating experience haG shoWn these com~poenets usually pass the surveilance when perfoFrmed OR the 18 mon~th FrFequency.

This SR is modified by two Notes. Note 1 states that neutron detectors are excluded from the CHANNEL CALIBRATION where applicable.

The CHANNEL CALIBRATION for the power range neutron detectors consists of a normalization of the detector outputs based on an incore/excore cross-calibration (SR 3.3.1.9).

In addition, the CHANNEL CALIBRATION for the power range neutron detector outputs includes normalization of the channel output based on a power calorimetric (SR 3.3.1.2) performed above 15% RTP. The CHANNEL CALIBRATION for the intermediate range neutron detector outputs includes normalization of the high flux bistable based on a power calorimetric.

The CHANNEL CALIBRATION for the source range neutron detectors consists of obtaining new detector plateau and preamp discriminator curves after a detector is replaced.

This Surveillance is not required for the NIS power range detectors for entry into MODE 2 or 1, and is not required for the NIS intermediate range detectors for entry into MODE 2, because the unit must be in at least MODE 2 to perform the test for the intermediate range detectors and MODE 1 for the power range detectors.

Note 2 states that this test shall include verification that the time constants are adjusted to the prescribed values where applicable.

The OTAT, OPAT, and the power range neutron flux rate functions contain required time constants.(continued)

Farley Units 1 and 2 B 3.3.1-56 Revision P Frequency specified in the Surveillance Frequency Control Program.BASES RTS Instrumentation B 3.3.1 pIZZ SURVEILLANCE SR 3.3.1.11 REQUIREMENTS (continued)

SR 3.3.1.11 is the perfor nce of a COT of RTS interlocksblee This COT is al intended to verify the interlock prior to Insert 2 startup, if not perform ed in thel. ,84 ... ... ..-The 8mot FrFequoncGY i based on the knoWn reliability of th interlocksO anRd the- multic-hanne1 re-dundancy avail able, and- hiabn shown to be acceptable through operating experience.

The 181 day FrFequiencY fr RTS Interlock COT perfo~rmance prier to startup is conGsitent with the uncertainty allowances for racrk drf inte0ten calculations (Ref. 7) and the COT (SR 3.3.1.7- and SR 3.3.148),ur......

,, ... IaR ...eq ois .or the aocated tr-p .U.ti. .i, Pertormance of the RTS Interlock COTs in conjunction with periodic actuation logic tests (SR 3.3.1.5) provides assurance that the total interlock function is OPERABLE prior to reactor startup and power ascension.

SR 3.3.1.12 SR 3.3.1.12 is the performance of a TADOT of the Manual Reactor Trip, RCP Breaker Position, and the SI Input from ESFAS. Rho-T822T-

,...e. .... y18 i atho rhe test shall independently verify the OPERABILITY of the undervoltage and shunt trip mechanisms for the Manual Reactor Trip Function for the Reactor Trip Breakers and Reactor Trip Bypass Breakers.

The Reactor Trip Bypass Breaker test shall include testing of the automatic undervoltage trip.The SR is modified by a Note that excludes verification of setpoints from the TADOT. The Functions affected have no setpoints associated with them.SR 3.3.1.13 SR 3.3.1.13 is the performance of a TADOT of Turbine Trip Functions prior to exceeding P-9. This TADOT consists of verifying that each channel indicates a Turbine trip before Latching the turbine and indicates no turbine trip after the turbine is latched prior to exceeding the P-9 interlock whenever the unit has been in MODE 3. A Note states that this Surveillance is not required if it has been performed within the (continued)

Farley Units 1 and 2 B 3.3.1-57 Revision FR RTS Instrumentation B 3.3.1 BASES SURVEILLANCE SR 3.3.1.14 (continued)

REQUIREMENTS types must be demonstrated by test.WCAP-14036-P-A, Revision 1, "Elimination of Periodic Protection Channel Response Time Tests," (Ref. 19) provides the basis and methodology for using allocated signal processing and actuation logic response times in the overall verification of the protection system channel response time. The allocations for the sensor, signal conditioning and actuation logic response times must be verified prior to placing the component in operational service and re-verified following maintenance that may adversely affect response time. In general, electric repair work does not impact response time provided the parts used for repair are of the same type and value. Specific components identified in the WCAP may be replaced without verification testing.One example where time response could be affected is replacing the Insert 2sensing assembly of a transmitter.

ýqA6 appropriato, oach 9channo-l's-ro-sponse must be verified evor,'

R ona STAGGERED TEST BASIS. Each Vo.. .ifcation shall linclat oAs. t Rone Lgic train GWuh that both Logic trains aro Yerifiod at least once per 36 moneths. Testing of the final actuatioen devicos is incl~uded in the testing. Response timnes cannot be dottoerirpmined during unit operation because equipment operatfion i6 required to mneasur~e response times. Experienco has shown that thoso com~poenets usually pass6 this surveillance when pe~fermed at the 18 month FrFequency.

Therefore, the FrFequency waG concluded to be acceptable from a reliability standpoint.

SR 3.3.1.14 is modified by a Note stating that neutron detectors are excluded from RTS RESPONSE TIME testing. This Note is necessary because of the difficulty in generating an appropriate detector input signal. Excluding the detectors is acceptable because the principles of detector operation ensure a virtually instantaneous response.REFERENCES

1. FSAR, Chapter 7.2. FSAR, Chapter 6.3. FSAR, Chapter 15.4. Joseph M. Farley Nuclear Power Plant Unit 1 (2) Precautions, Limitations and Setpoints U-266647 (U-280912).(continued)

Farley Units 1 and 2 B 3.3.1-59 Revision Rq ESFAS Instrumentation B 3.3.2 BASES SURVEILLANCE REQUIREMENTS The SRs for each ESFAS Function are identified by the SRs column of Table 3.3.2-1.A Note has been added to the SR Table to clarify that Table 3.3.2-1 determines which SRs apply to which ESFAS Functions.

Note that each channel of process protection supplies both trains of the ESFAS. When testing channel I, train A and train B must be examined.

Similarly, train A and train B must be examined when testing channel II, channel III, and channel IV (if applicable).

The CHANNEL CALIBRATION and COTs are performed in a manner that is consistent with the assumptions used in analytically calculating the required channel accuracies.

SR 3.3.2.1 Performance of the CHANNEL CHECK jGR.e eve.-,/2 her 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 based on a combination of the channel instrument uncertainties, including indication and reliability.

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.Insert 2 channel failuro israre. The CHANNEL CHECK supplemernts loss fo~rmal, but more8 freqIuent, chocks Of channels during norma operational use of the displays associatod With the LCOG requio-hni n SR 3.3.2.2 SR 3.3.2.2 is the performance of an ACTUATION LOGIC TEST.SSPSs tested e,-92 days o.n, a STAGGERED TEST BASSI using the semiautomatic tester. The train being tested is placed in the (continued)

Farley Units 1 and 2 B 3.3.2-42 Revision RQ ESFAS Instrumentation B 3.3.2 BASES SURVEILLANCE REQUIREMENTS SR 3.3.2.2 (continued) bypass condition, thus preventing inadvertent actuation.

Through the semiautomatic tester, all possible logic combinations, with and without Insert ý2 applicable permissives, are tested for each protection and permissive function excluding the automatic actuation Logic for the trip of all main feedwater pumps. In addition, the master relay coil is pulse tested for continuity.

This verifies that the logic modules are OPERABLE and that there is an intact voltage signal path to the master relay coils.Tho FroqueRcy of ovp'y 92 days on a STAGGERED TEST BASIS ic justified in Reference 12.on a STAGGERED TEST BASIS I £ 3.3.2.3 SR 3.3. .is the performance of a MASTER RELAY TEST. The MASTER AY TEST is the energizing of the master relay, verifying contact operati and a low voltage continuity check of the slave relay coil. Upon maste lay contact operation, a low voltage is injected to the slave relay coil. s voltage is insufficient to pick up the slave relay, but large enough signal path contin~uity.

T.4s I Me time allowed for The testing k4. nours) is juUMtne in ReTerence 10.Insert 2 SR 3.3.2.4 SR 3.3.2.4 is the performance of a COT.A COT is performed on each required channel to ensure the rack components will perform the intended Function.

Setpoints must be found within the Allowable Values specified in Table 3.3.2-1. With the exception of P-1 1, the COT also confirms the channel inputs to both actuation logic trains. The P-11 inputs are tested 19R a, !8 FA F under SR 3.3.2.7.The "as found" and "as left" data have been evaluated to ensure consistency with (i.e., bounded by) the drift allowance used in the setpoint methodology.

The COT "as found" limits are based, in part, on expected performance of a healthy instrument channel.Appropriate corrective action is taken when the "as found" values exceed the prescribed values. The setpoint shall be left set consistent (continued)

Farley Units 1 and 2 B 3.3.2-43 Revision P ESFAS Instrumentation B 3.3.2 BASES SURVEILLANCE SR 3.3.2.4 (continued)

REQUIREMENTS with the assumptions of the current unit specific setpoint methodology.

Inser 2-4T .o rqu .c f 184 days is Wustmfned .R ,Refcrcjicc 12.I~ ~~~ SR 3.3.2..5 SR 3.3.2.5 is the performance of a TADOT every 184 days. This test*s a check of the Undervoltage RCP Function.

The Function is tested to the SSPS logic circuit. Setpoints must be found within the 11 wable Values specified in Table 3.3.2-1.Th t st includes undervoltage sensing devices that provide actuation sign Is irectly to the SSPS. The test functionally demonstrates chan el PERABILITY including verification of the trip setpoint.

If neces a the undervoltage setpoint is restored to within calibration SR 3.3.2.6 is th performance of a TADOT. This test is a check of the Man tatioFunctions and the P-4 interlock Function, including turbine trip, auto- tic SI block, and seal-in of FWI by SI. F R- .............

I A- ...... Each Manual Actuation Function is tested up to, and inc\uding, the master relay coils. In some instances, the test includes actu tion of the end device (i.e., pump starts, valve cycles, etc.). The turb e trip by reactor trip (P-4) is independently ve*rifiedl for both trains. 19R, ,, ad-- e, quateh, , ,.a÷,. d 9R,., o,, b .1 hb i ,A,. I Me 6H1 is modiiedi by a Note t~at -excludes verification of setpoints during the TADOT. The manual initiation and P-4 interlock Functions have no associated setpoints.(continued)

Farley Units 1 and 2 B 3.3.2-44 , Revision Pq ESFAS Instrumentation B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.2.7 SR 3.3.2.7 is the performance of a CHANNEL CALIBRATION.

^CHANREL CA.LIBRATION is performded oVr,', 18 o-r approximately at .ve..' roTuelflig.

0HANNEL UALIb/A I IUN IS a complete check of the instrument loop, including the sensor. The test verifies that the channel responds to measured parameter within the necessary range and accuracy.CHANNEL CALIBRATIONS must be performed consistent with the assumptions of the unit specific setpoint methodology.

The "as found" and "as left" data have been evaluated to ensure consistency with (i.e., bounded by) the drift allowance used in the setpoint methodology.

h =vlue whreappic)

~trable te.tFR~tG e h ngi~8 This SR is modified by a Note stating that this test should include verification that the time constants are adjusted to the prescribed values where applicable.

SR 3.3.2.8 SR 3.3.2.8 is the performance of a SLAVE RELAY TEST. The Insert 2 SLAVE RELAY TEST is the energizing of the slave relays. Contact operation is verified in one of two ways. Actuation equipment that may be operated in the design mitigation MODE is either allowed to function, or is placed in a condition where the relay contact operation can be verified without operation of the equipment.

Actuation equipment that may not be operated in the design mitigation MODE is prevented from operation by the SLAVE RELAY TEST circuit or is tested when there will be no adverse impact on the plant. For this latter ase, when using the SLAVE RELAY TEST circuit, contact operation is erified by a continuity check of the circuit containing the slave relay.bhis test i pelfnoeraed e peren ,8 M cRthsi The riFeq-e.Gy is based OR plant eperating

.pr. c. ccnsideding iRstr'-mnet Feliabiiffiý, I I and operatiRg hiit9r,' data. While the AS is designed to accommodate online testing at power, slave relay testing is normally conducted during refueling to minimize the potential for plant transients and unnecessary challenges to plant equipment.(continued)

Farley Units 1 and 2 B 3.3.2-45 Revision P ESFAS Instrumentation B 3.3.2 BASES SURVEILLANCE SR 3.3.2.9 (continued)

REQUIREMENTS electric repair work does not impact response time provided the parts used for repair are of the same type and value. Specific components identified in the WCAP may be replaced without verification testing.One example where time response could be affected is replacing the ti Insert 2IX sensing assembly of a transmitter.

E=SE= RE-SPONSE TIME tests are cOnductod on an 18 mon~th STAGGERED TEST BASIS. Each verfication shall includo at least one Loic, t SUch that both LoGgic trains are verified at leat once per 36 months. Testing of the final actuation devicos, which-makc

'the bulk of the response timne, is incuided in the testing of eachTho final actuation device in one train is tested with eh channel. Thorefore, staggered testing results in response tio verification of those devices every' 18 monthS. The 18 moneth FmroquncGY is consistent With the typical refueling cycle and is based On Unit Operating experience, Which shows that random failro in~trum~entation comRponents causing serious response time degradation, but not channel Afaiue, are infrequent occurrencs This SR is modified by a Note that clarifies that the turbine driven AFW pump is tested within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after reaching 1005 psig in the SGs. Based on operating experience, 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is a sufficient time duration for performance of the TDAFW pump response time test. A steam pressure of 1005 psig corresponds to the RCS no-load Tavg for MODE 2. Valid response time tests can be performed at lower SG pressures.

SR 3.3.2.10 SR 3.3.2.10 is the performance of a TADOT as described in SR 3.3.2.6, except that it is performed for the AFW pump start on trip of all MFW pumps Function and the Frequency is prior to reactor startup if not performed within the previous 92 days. This Frequency is based on operating experience.

The SR is modified by a Note that excludes verification of setpoints during the TADOT. The Function tested has no associated setpoint.REFERENCES

1. FSAR, Chapter 6.2. FSAR, Chapter 7.(continued)

Farley Units 1 and 2 B 3.3.2-47 Revision RM ESFAS Instrumentation B 3.3.2 BASES REFERENCES (continued)

3. FSAR, Chapter 15.4. Joseph M. Farley Nuclear Power Plant Unit 1 (2) Precautions, Limitations, and Setpoints U-266647 (U-280912).

5. IEEE-279-1971.

6. WCAP 13751, Rev. 1, Westinghouse Setpoint Methodology for Protection Systems Farley Nuclear Plant Units 1 and 2.7. 10 CFR 50.49.8. WCAP 13751 Rev. 0, Westinghouse Setpoint Methodology for Protection Systems SNOC Farley Nuclear Plant Units 1 and 2.9. Joseph M. Farley Nuclear Power Plant Units 1 & 2 Precautions, Limitations, and Setpoints for Nuclear Steam Supply Systems, March 1978, U258631/U278997 Rev. 5.10. WCAP-10271-P-A, Supplement 2, Rev. 1, "Updated Approved Version," June 1990.11. WCAP-14333-P-A, Revision 1, "Probabilistic Risk Analysis of the RPS and ESFAS Test Times and Completion Times," October 1998.Not used.12.15376 P A, Rev-oseen

!, "Risk 'Rnfcrmed Assessment OfI the RT-9 and ESFAS SurvofillancGe Test Intervals and Reactor Tr-ip Breako Tes, t and Completion Times," March .13. FSAR, Table 7.3-16.14. WCAP-1 3632-P-A, Revision 2, "Elimination of Pressure Sensor Response Time Testing Requirements," Jan., 1996.15. WCAP-14036-P-A, Revision 1, "Elimination of Periodic Protection Channel Response Time Tests," Oct. 1998.16. NUREG-1218, April 1988.17. A-181007 Reactor Protection System FSD.18. Westinghouse Functional Diagrams U-166231 thru U-166245.Farley Units 1 and 2 B 3.3.2-48 Revision P PAM Instrumentation B 3.3.3 BASES SURVEILLANCE A Note has been added to the SR Table to clarify that SR 3.3.3.1 and REQUIREMENTS SR 3.3.3.2 apply to each PAM instrumentation Function in Table 3.3.3-1.SR 3.3.3.1 Performance of the CHANNEL CHECK ensures that a gross instrumentation failure has not occurred.

A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.

It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between 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.

The high radiation instrumentation should be compared to similar unit instruments.

Agreement criteria are based on a combination of the channel instrument uncertainties, including isolation, indication, and readability.

If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. If the channels are within the criteria, it is an indication that the channels are OPERABLE.As specified in the SR, a CHANNEL CHECK is only required for those Insert 2 channels that are normally energized.

'The- Fro-quoncY of 31 days is bared on operating oxoiochat demontr~ates that channol-4 fa-11ilur is raro. The CH4NNE CHEK supplom,.ts loss frmal, but moefro ,equeRt, chceks Of channels during normal opeational use- of the displays associated withth LCOG required channels-.

SR 3.3.3.2 IA CHANNEiLr-CALIBRDATION lil ev,'w 19 rmths, imael atevFYFefe"q.CHANNEL CALIBRATION is a complete check of the instrument loop, including the sensor. The test verifies that the channel responds to measured parameter with the necessary range and accuracy.(continued)

Farley Units 1 and 2 B 3.3.3-15 Revision PAM Instrumentation B 3.3.3 BASES SURVEILLANCE SR 3.3.3.2 (continued)

REQUIREMENTS Insert 2 Ha tRanssna bas ed OnR~al nnrnspe a~ar na 'In exeAe~ rancjnGGRSO l, with Wthetpcl_

inut refueling cycle.REFERENCES

1. A-181866 Unit 1 RG 1.97 Compliance Review A-204866 Unit 2 RG 1.97 Compliance Review NRC SER for FNP RG 1.97 Compliance Report, Letter, Reeves to McDonald, 2/12/87.2. Regulatory Guide 1.97.3. NUREG-0737, Supplement 1, "TMI Action Items." Farley Units 1 and 2 B 3.3.3-16 Revision 0 Remote Shutdown System B 3.3.4 BASES ACTIONS A.1 (continued)

The Required Action is to restore the required Function to OPERABLE status within 30 days. The Completion Time is based on operating experience and the low probability of an event that would require evacuation of the control room.B.1 and B.2 A Note modifies Condition B indicating that it is not applicable to the Source Range Neutron Flux (Gammametrics)

Function.

This Function is covered under Condition C.if the Required Action and associated Completion Time of Condition A is not met, the unit must be brought to a MODE in which the LCO does not apply. To achieve this status, the unit must be brought to at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . 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.C._1 Condition C applies when the Required Action and associated Completion Time for Condition A are not met for the Source Range Neutron Flux (Gammametrics) monitor. This Required Action requires a written report be submitted to the NRC. This report discusses the results of the root cause evaluation of the inoperability, if performed, and identifies proposed restorative actions. This action is appropriate in lieu of a shutdown requirement since alternative actions are identified before loss of functional capability, and given the likelihood of unit conditions that would require information provided by this instrumentation.

SURVEILLANCE SR 3.3.4.1 REQUIREMENTS Performance of the CHANNEL CHECK 0R, .... 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 (continued)

Farley Units 1 and 2 B 3.3.4-4 Revision 93 Remote Shutdown System B 3.3.4 BASES SURVEILLANCE SR 3.3.4.1 (continued)

REQUIREMENTS 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 based on a combination of the channel instrument uncertainties, including indication and readability.

If the channels are within the criteria, it is an indication that the channels are OPERABLE.

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 which are normally energized.

u p p -, -m ,n t ,le ss fo rm a l, b u t m o re frneG-qe t, c h k o f c h an n o lsýduFrig normnal oporational use of the displays associated with the LCOG required channels-.

S Insert 2 SR 3.3.4.2 R 3.3.4.2 verifies each required Remote Shutdown System control ci uit and transfer switch performs the intended function.

This veri ation is performed from the remote shutdown panel and locally, as app priate. Operation of the equipment from the remote shutdowr anel is not necessary.

The Surveillance can be satisfied by perform ce of a continuity check. This will ensure that if the control room comes inaccessible, the unit can be placed and maintained in DIE 3 from the remote shutdown panel and the local control stations.

1e1 nnhFFqe~ sbsd9 ~~e perform this Surveillance un~der the conditions that apply during a plant outage and the potential for an unplanned transient ifth Surveillance wore performned with the reactor at power. (However, this SuWA1rveilance is- not required to be porfermed only dur~ing a unit Iu.rn \ * (nrf;~m 14nrnn ,-nnn+rn+n

+k-,+ r n.+n nk +14rj (continued) vF~r1 v r ing,, u p ur 0 nmnrnm ua V0 an nrm nf K7 nC vv wni contrl. c.hannels uually pass the Su .eillance test when perform.ed at the 18 month FrFecqU9cY.(continued)

Farley Units 1 and 2 B 3.3.4-5 Revision 9 Remote Shutdown System B 3.3.4 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.4.3 CHANNEL CALIBRATION is a complete check of the monitoring instrument loop and the sensor. The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.REFERENCES

1. 10 CFR 50, Appendix A, GDC 19.Farley Units 1 and 2 B 3.3.4-6 Revision 12 LOP DG Start Instrumentation B 3.3.5 BASES ACTIONS (continued)

F.1 and F.2 Condition F becomes applicable when the Required Action and associated Completion Time of Condition E is not met. If the emergency bus voltage cannot be restored to >_ 3850 volts within the Completion Time of Condition E, action must be taken to place the unit in a MODE where the LCO requirement for the Alarm function is not applicable.

To achieve this status, the unit must be brought to MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . 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 3.3.5.1 SR 3.3.5.1 is the performance of a TADOT. test 0- Pe 1 T h 3:95;7&.ýhe test checks trip devices that provide actuation signals directly, bypassing the analog process control equipment.

The TADOT surveillance is modified by two Notes. The first Note excludes the actuation of the final trip actuation relay for LOP Functions 1 and 2 from this TADOT. The actuation of this relay would cause the DG start and separation of the emergency buses from the Igrid. The actual DG start and connection to the emergency bus is everified by other surveillance testing (SR 3.3.5.3) accomplished during shutdown conditions.

The second Note provides an exception to the everification of the LOP function setpoints during performance of this onthly TADOT. The TADOT includes verification of the\dervoltage device operation upon removal of the input voltage and do s not require the setpoint be verified or adjusted.

The LOP funcd on setpoints are verified during the CHANNEL CALI ATION. In addition, the TADOT includes verification of the operati of the two-out-of-three logic associated with LOP Functions 1 and 2. 35The F.e2ue ncy *s based OR th8 k neW n rel!ab!!mt f the reays S R 3.3.5.2 SR 3.3.5.2 is the performance of a CHANNEL CALIBRATION.

The setpoints, as well as the response to a loss of voltage and a degraded grid voltage test, shall include a single point verification that (continued)

BASES Farley Units 1 and 2 B 3.3.5-7 Revision Pq LOP DG Start Instrumentation B 3.3.5 SR 3.3.5.2 (co inued)the trip occurs within t required time delay (refer to appropriate relay setting sheet calibra in requirements).

SURVEILLANCE REQUIREMENTS nrx.......

a .. .... I F ....,CHANNEL CALIBRATION is a check of the major instrument components in the loop, including the sensor (relay or digital voltmeter).

The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.The CHANNEL CALIBRATION is modified by a Note. The Note excludes the actuation of the final trip actuation relay for LOP functions 1 and 2 from this CHANNEL CALIBRATION.

The actuation of this relay would cause the DG start and separation of the emergency buses from the grid. The actual DG start and connection to the emergency bus is verified by other surveillance testing (SR 3.3.5.3) accomplished during shutdown conditions.

InsertK[~~~G ToFqunyOf 18 mRonths is based on operating oxporio~nco and c t............

with the ... '. al i. dust.. ' re.fuelig Gcyle.SR 3.3.5.3 This SR ensures the individual channel response times are less than or equal to the maximum values assumed in the safety analysis.

The response time testing acceptance criteria are included in FSAR Table 7.3-16. This surveillance is performed in accordance with the guidance provided in the ESF RESPONSE TIME surveillance requirement in LCO 3.3.2, ESFAS.This surveillance is modified by a Note. The Note states that this surveillance shall include verification of the actuation of the final trip actuation relay associated with LOP Functions 1 and 2.REFERENCES

1. FSAR, Section 8.3.2. FSAR, Chapter 15.3. SNC Calculations E-35.1.A, E-35.2.A, and SE-94-0470-006.

4. FSAR, Section 7.3.Farley Units 1 and 2 B 3.3.5-8 Revision P Containment Purge and Exhaust Isolation Instrumentation B 3.3.6 BASES ACTIONS C.1 and C.2 (continued)

A Note states that Condition C is applicable during the Applicability of CORE ALTERATIONS and during movement of irradiated fuel assemblies within containment.

SURVEILLANCE REQUIREMENTS A Note has been added to the SR Table to clarify that Table 3.3.6-1 determines which SRs apply to which Containment Purge and Exhaust Isolation Functions.

SR 3.3.6.1 Performance of the CHANNEL CHECK eVG,' 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 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 I Insert 2 orte inal processing equipment has drifted outside its limit.The CHANNEL CHECK supplements less formnal, but oroF frequent, checks, of channels during norma perfatiGnal use of the displays assci;ated with the ICO required SR 3.3.6.2 SR 3.3.6.2 is the performance of an ACTUATION LOGIC TEST. The train being tested is placed in the bypass condition, thus preventing inadvertent actuation.

Through the semiautomatic tester, all possible logic combinations, with and without applicable permissives, are tested for each protection function.

In addition, the master relay (continued)

Farley Units 1 and 2 B 3.3.6-6 Revision 12 Containment Purge and Exhaust Isolation Instrumentation B 3.3.6 BASES SURVEILLANCE SR 3.3.6.2 (continued)

REQUIREMENTS coil is pulse tested for continuity.

This verifies that the logic modules are OPERABLE and there is an intact voltage signal path to the master relay coilsf k" ,, -' This test ....Fne ,4 ic .... day , ....Insert 23.3.6.3 SR 3.3. is rformance of a MASTER RELAY TEST. The MASTER RY TES e energizing of the master relay, verifying contact operatio nd a low vol a ntinuity check of the slave relay coil. Upon ma ter re contac operation, voltage is injected to the slave relay coil. This age is insufficient to pi the slave relay, but large enough to dem strate siqnal path continui .Trhie S R 3.3.6.4 A COT is performed leey 2d on each required cha to ensure the entire channel will perform the intended Function.

The FrFequencY is based On the staff recom~mendation for nrasn h availability of radiation moneitorcs according to NUREG 1366 (Ref. 3).I his test verities the capability ot the instrumentation to provide the containment purge and exhaust system isolation.

The setpoint shall be left consistent with the current unit specific calibration procedure tolerance.

SR 3.3.6.5 SR 3.3.6.5 is the performance of a SLAVE RELAY TEST. The SLAVE RELAY TEST is the energizing of the slave relays. Contact operation is verified in one of two ways. Actuation equipment that may be operated in the design mitigation mode is either allowed to function or is placed in a condition where the relay contact operation can be verified without operation of the equipment.

Actuation equipment that may not be operated in the design mitigation mode is prevented from operation by the SLAVE RELAY TEST circuit. For this latter case, contact operation is verified by a continuity check of the circuit containing the slave relay.(continued)

Farley Units 1 and 2 B 3.3.6-7 Revision FR Containment Purge and Exhaust Isolation Instrumentation B 3.3.6 BASES SURVEILLANCE REQUIREMENTS SR 3.3.6.5 (continued)

IThis. test is. pnrnrrnnrl penn, 4 9 Fne-ths. The FCrnn.;G Genit .~ptablen SR 3.3.6.6 SR 3.3.6.6 is the performance of a TADOT. This test is a check of the Manual Actuation Functions Each Manual Actuation Function is tested up to, and including, the master relay coils. In some instances, the test includes actuation of Insert 2 the end device (i.e., pump starts, valve cycles, etc.).The test also includes trip devices that provide actuation signals directly to the SSPS, bypassing the analog process control equipment.

The SR is modified by a Note that excludes verification of setpoints during the TADOT. The Functions tested have no setpoints associated with them.theredndacy vaiable, and has been shown to be acceptable throu~gh oprtn Wxeience.SR 3.3.6.7"'A CHANNEL CALIBRATION is a Ccomplete check of the instrument loop, including the sensor. The test erifies that the channel responds to a measured parameter within the ecessary range and accuracy.SR 3.3.6.8 This SR ensures the individual channel response times are less than or equal to the maximum values assumed in the safety analysis.

The response time testing acceptance criteria are included in FSAR Table 7.3-16 (Ref. 4). This surveillance is performed in accordance with the guidance provided in the ESF RESPONSE TIME surveillance requirement in LCO 3.3.2, ESFAS.Farley Units 1 and 2 B 3.3.6-8 Revision ~Farley Units 1 and 2 B 3.3.6-8 Revision RQ Containment Purge and Exhaust Isolation Instrumentation B 3.3.6 BASES REFERENCES

1. 10CFR100.11.

Not used. I.A. -15765-14 AR Tab. 7.. 3-16.....

..3. UREG 1 36, 4. FSAR Table 7.3-16 Farley Units 1 and 2 B 3.3.6-9 Revision FQ CREFS Actuation Instrumentation B 3.3.7 BASES ACTIONS D.1 and D.2 (continued)

ALTERATIONS or when irradiated fuel assemblies are being moved.Condition D is only applicable to those CREFS functions in Table 3.3.7-1 required OPERABLE during CORE ALTERATIONS or during movement of irradiated fuel assemblies.

Movement of irradiated fuel assemblies and CORE ALTERATIONS must be suspended immediately to reduce the risk of accidents that would require CREFS actuation or control room isolation.

SURVEILLANCE REQUIREMENTS A Note has been added to the SR Table to clarify that Table 3.3.7-1 determines which SRs apply to which CREFS Actuation Functions.

SR 3.3.7.1 Performance of the CHANNEL CHECK ..... 8V,- 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 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 Insert 2 .or the signal processing equipment has drifted outside its limit.The FrequencY i based on operating oxporionce that domonstratoc channel failure is are. The CHANNEL= CHECK supplomentG Ices formal, but More frequent, chocks of channels durin~g norma operational use of the dirplays associated with the LCO roquie (continued)

Farley Units 1 and 2 B 3.3.7-6 Revision 19 CREFS Actuation Instrumentation B 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.7.2 A COT is performed once .. on each required channel to ensure the entire channel will perform the intended function.

This test verifies the capability of the instrumentation to provide the actuation function.

The setpoints shall be left consistent with the unit specific calibration procedure tolerance.

T.he FrFeuenc,, is baed on the kmnowuqn rn-mndbilt" of th ihridan nmRt a -d has n shown tel SR 3.3.7.3 SR 3.3.7.3 is the perfor ance of an ACTUATION LOGIC TEST. The train being tested is plaed in the bypass condition, thus preventing inadvertent actuation.

Through the semiautomatic tester, all possible logic combinations, ith and without applicable permissives, are tested for each pro ection function.

In addition, the master relay coil is pulse tested for c ntinuity.

This verifies that the logic modules are OPERABLE an there is an intact voltage signal path to the master SR 3.3.7.4 is thelp mance of a MASTER RELAY TEST. The MASTER RELAY TEST is ergizing of the master relay, verifying contact operation and a low voltage ity check of the slave relay coil. Upon master relay contact operation, a is injected to the slave relay coil. This voltage is insufficient to pic e slave-1-a~ k ..4 I-,r-- --1, *-i A --rnm nfrof- eir l --+k 71mtnd , TI , tat c ororedever; 92 days On a;SAGEE T-EST BASIS.IThe Su, ola~lnco

interva-l ic u;tifod~~r Renference

1. I SR 3.3.7.5 SR 3.3.7.5 is the performance of a SLAVE RELAY TEST. The SLAVE RELAY TEST is the energizing of the slave relays. Contact operation is verified in one of two ways. Actuation equipment that may be operated in the design mitigation MODE is either allowed to function or is placed in a condition where the relay contact operation (continued)

Farley Units 1 and 2 B 3.3.7-7 Revision R CREFS Actuation Instrumentation B 3.3.7 BASES SURVEILLANCE REQUIREMENTS SR 3.3.7.5 (continued) can be verified without operation of the equipment.

Actuation equipment that may not be operated in the design mitigation MODE is prevented from operation by the SLAVE RELAY TEST circuit. For this latter case, contact operation is verified bv a continuitv check of S Insert 2 th slv " 'f-T4iýS SR 3.3.7.6 SR 3.3.7.6 is the performan .e of a TADOT. This test is a check of the Mal::nula:l Actuation Fulnctfion-"l'n A ;. ,-,ef,-,.-.ed

...... ,I mennn The test includes actuation of the end device (i.e., pump starts, valve'the FrFequency

6 based- AR the kRowR reliability Gf the FuRctoR and\the redunac i'a!ble, and has beeR showR to be acceptabko through operating oxperience.

The SR is modified by a Note that excludes verification of setpoints during the TADOT. The Functions tested have no setpoints associated with them.S =R 3.3.7.7Thl n ... rn÷l,, at ...... .ALIBRATION is complete check of the instrument loop, including the sensor. The test verifies that the channel responds to a measured parameter within the ecessary range and accuracy.With the ty'p!al inductr,'

rofueling cycle.I REFERENCES I 2 Not used.Farley Units 1 and 2 B 3.3.7-8 Revision FM PRF Actuation Instrumentation B 3.3.8 BASES ACTIONS C.1 (continued) required to mitigate the consequences of a LOCA (Phase B Isolation and associated automatic actuation logic and actuation relays).These Functions are not required OPERABLE when moving irradiated fuel assemblies and are unrelated to the mitigation of a fuel handling accident in the spent fuel pool room.D.1 and D.2 Condition D applies when the Required Action and associated Completion Time for Condition A or B have not been met and the unit is in MODE 1, 2, 3, or 4. The unit must be brought to a MODE in which the LCO requirements are not applicable.

To achieve this status, the unit must be brought to MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . 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.This Condition is modified by a Note which limits the applicability of this Condition to those Functions on Table 3.3.8-1 required OPERABLE during MODES 1, 2, 3, or 4 to mitigate the consequences of a LOCA. This Condition is not intended to be applied to Functions which are only required to mitigate the consequences of a fuel handling accident in the Spent Fuel Pool Room (radiation monitors and Spent Fuel Pool Room normal ventilation differential pressure).

These Functions are only required OPERABLE when moving irradiated fuel assemblies in the Spent Fuel Pool Room and are unrelated to the mitigation of the consequences of a LOCA.SURVEILLANCE A Note has been added to the SR Table to clarify that Table 3.3.8-1 REQUIREMENTS determines which SRs apply to which PRF Actuation Functions.

SR 3.3.8.1 Performance of the CHANNEL CHECK !once eve, 1 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 (continued)

Farley Units 1 and 2 B 3.3.8-6 Revision 9 PRF Actuation Instrumentation B 3.3.8 BASES SURVEILLANCE REQUIREMENTS SR 3.3.8.1 (continued) 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 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.ffrmal, but more frequent, cc neI I94k V 6iated with the LCO required;,.: ;. ..; ;. ;__ ..;,, ; ',t.,

.A-h-;AA P-1 r S R 3.3.8.2 ied ..... e on each required channel to channel will perform the intended function.

This test-ithof the instrumentation to provide the PRFbe left consistent with the unit specific Wre toleranc .The FrequecY of 92 days is based SR 3.3.8.3 SR 3.3.8.3 is the performance of an R 1091G 16 test All possible logic combinations, with an'permissives, are tested for each protection funcl laqp,ýeillaRGe IRtewal IS 161611118EI IR ketidFeRGe a., (continued)

Farley Units 1 and 2 B 3.3.8-7 Revision PR PRF Actuation Instrumentation B 3.3.8 BASES SURVEILLANCE SR 3.3.8.4 REQUIREMENTS (continued)

SR 3.3.8.4 is the performance of a MASTER RELAY TEST. The MASTER RELAY TEST is the energizing of the master relay, verifying contact operation and a low voltage continuity check of the slave relay coil. Upon master relay contact operation, a low voltage is injected to the slave relay coil. This voltage is insufficient to pick up the slave relay, but large enough to demonstrate signal path continu ay'Thi-s Insert 2 SR 3.3.8. is e performance of a SLAVE RELAY TEST. The SLAVE LAY ST is the energizing of the slave relays. Contact operatio is verifie n one of two ways. Actuation equipment that may be perated in th design mitigation MODE is either allowed to function r is placed in a ondition where the relay contact operation can be v rified without ope tion of the equipment.

Actuation equipm t that may not be op rated in the design mitigation MODE is prevent d from operation by the LAVE RELAY TEST circuit. For this latt r case, contact operation i verified by a continuity check of the circ it containing the slave relay.SR 3.318.6 SR 3.3.8.6 is the perfor nce o a TADOT. This test is a check of the manu I and Spent F I Pool Room ventilation Differential Pressure actuat on functionsnr is Pef,-F .... 1 Fn 9Rt,,- .he test includ s actuation of the end device (e.g., pump starts, valve cycles, etc.). _.oFraQG r ae n p~t~ xeIR8 1-... Wh tThe SR is modified by a Note that excludes verification of setpoints during the TADOT. The Functions tested have no required setpoints associated with them.(continued)

Farley Units 1 and 2 B 3.3.8-8 Revision PR PRF Actuation Instrumentation B 3.3.8 BASES SURVEILLANCE REQUIREMENTS (continued)

.m f at e F Iin,.I 'CHANNEL CALIBRATION is a S Insert 2 complete check of the instrument loop, including the sensor. The test ven ies dnelresponds to a measured parameter within the necessary range and accurac Iexperience and is cnsistent with the; typical! industp, refuelngn c-cle I I I REFERENCES

1. 10CFR100.11.

Not used. .2. FNP -1/2 -RCIP- 252.3.13, 6APA A, Rev., M aFr,'h Farley Units 1 and 2 B 3.3.8-9 Revision Pq RCS Pressure, Temperature, and Flow DNB Limits B 3.4.1 BASES ACTIONS (continued)

B.1 If Required Action A.1 is not met 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 2 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . In MODE 2, the reduced power condition eliminates the potential for violation of the accident analysis bounds.The Completion Time of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is reasonable to reach the required plant conditions in an orderly manner.SURVEILLANCE SR 3.4.1.1 REQUIREMENTS't - naaneer that Rotv' wfftho lo s th ,,e, 12 G FSi Frequoncy "Fr D...... is ufficiert to ent the pr.. SUr, en.. be restored to a noral operatio, steady state scndition folleoWig load chne an o thor expected transient oporations.

The 12 hour&interwal has, boon shP'A"own by operating practico to be sufficient to regularfly assess for pteRntial dlogadatio aRd to verify opeFrtioGn i within safety analysis assumptions&.

S R 3.4.1.2 o toe parame ht a n within limits, the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months uellae Insert 2Frequency for RCS average temperature is sufficient to ensur~e the practice to- be- su-ffic-ient to regularly assess forF potential degradation and to verify operation is within safety analysis assumptions.'

SR 3.4.1.3 qualitative verFification pe~feFmod using the installed flow indic~ators on the main conrol1 board fed by elbow tap mneasr~ements.

The 12 hour*intealh hasbon shown hby operaFinag practic-e to be sufficient to regularly assess potential significant flow degradation and to verify operation within safety analysirs assumnptions.(continued)

Farley Units 1 and 2 B 3.4.1-4 Revision 12 RCS Pressure, Temperature, and Flow DNB Limits B 3.4.1 BASES SURVEILLANCE REQUIREMENTS (continued)

Z Insert 2 SR 3.4.1.4 The surveillance of the total RCS flow rate may be performed by one of two alternate methods. One method is aa precision calorimetricth eeR ' .Ias documented in WCAP-1 2771, Rev. 1. The other method is based nn the Ap measurements from the cold leg elbow taps, which are correlated to past precision heat balance measurements.

Correla on of the flow indication channels with selected precision loop flow calorimetrics for this method is documented in WCAP-14750.

Us of the elbow tap Ap measurement method removes the requiremen for pfance of a precision RCS flow caloricmetric measurement Measurement of RCS total flow rate by performance of one of these two methods 5- .-i .v 1 moehs verifies the actual RCS flow rate is greater than or equal to the minimum required RCS flow rate.--I"'The FrequeRny Of 18 monGths refleGS the nimpotaRne of verifYing flow after a refueling mutago when the cor, ham boon altorod, whih m ay have caused an alteration of flow resistaRnc.

This SR is modified by a Note that allows entry into MODE 1, without having performed the SR, and placement of the unit in the best condition for performing the SR. The Note states that the SR is not required to be performed until 7 days after > 90% RTP. This exception is appropriate since the heat balance and elbow tap measurement methods both require the plant to be at a minimum of 90% RTP to obtain the stated RCS flow accuracies.

The Surveillance shall be performed within 7 days after reaching 90% RTP. The intent is that this Surveillance be performed near the beginning of the cycle as close as possible to 100% RTP.REFERENCES

1. FSAR, Section 4.4 and 15.Farley Units 1 and 2 B 3.4.1-5 Revision [2 RCS P/T Limits B 3.4.3 BASES SURVEILLANCE REQUIREMENT, Insert 2 S SR 3.4.3.1 Verification that operation is within the PTLR limits is required F;5 Fi when RCS pressure and temperature conditions are undergoing pqann cý -.esd~d eS~beO 49.1 I--.1- 0011-1" rw" ri provon adequate by operat Rg cxper enco. The0 I hour freoqusciY i a&e speGifod I w I, ... w ., .also consistent with flow the rate ot change limits Surveillance for heatup, cooldown, or ISLH testing may be discontinued when the definition given in the relevant plant procedure for ending the activity is satisfied.

This SR is modified by a Note that only requires this SR to be performed during system heatup, cooldown, and ISLH testing. No SR is given for criticality operations because LCO 3.4.2 contains a more restrictive requirement.

REFERENCES

1. WCAP-7924-A, April 1975.2. 10 CFR 50, Appendix G.3. ASME, Boiler and Pressure Vessel Code, Section XI, Appendix G.4. ASTM E 185-82, July 1982.5. 10 CFR 50, Appendix H.6. Regulatory Guide 1.99, Revision 2, May 1988.7. ASME, Boiler and Pressure Vessel Code, Section XI, Appendix E.Farley Units 1 and 2 B 3.4.3-7 Revision 19 RCS Loops -MODES 1 and 2 B 3.4.4 BASES SURVEILLANCE REQUIREMENTS SR 3.4.4.1 This SR requires verification 1y Q'--- that each RCS loop is in operation.

Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing heat REFERENCES

1. FSAR, Sections 15.2.2, 15.2.5, 15.3.4, 15.3.6, 15.4.4.3, and 15.4.6.3.Farley Units 1 and 2 B 3.4.4-4 Revision 19 RCS Loops -MODE 3 B 3.4.5 BASES ACTIONS C.1 and C.2 (continued) inadvertent control rod withdrawal.

This mandates having the heat transfer capacity of two RCS loops in operation.

If only one loop is in operation, the RTBs must be opened.The Completion Times of 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to restore the required RCS loop to operation or de-energize all CRDMs is adequate to perform these operations in an orderly manner without exposing the unit to risk for an undue time period.D.1, D.2, and D.3 If two required RCS loops are inoperable or no RCS loop is in operation, except as during conditions permitted by the Note in the LCO section, all CRDMs must be de-energized by opening the RTBs or de-energizing the MG sets. All operations involving a reduction of RCS boron concentration must be suspended, and action to restore one of the RCS loops to OPERABLE status and operation must be initiated.

Boron dilution requires forced circulation for proper mixing, and opening the RTBs or de-energizing the MG sets removes the possibility of an inadvertent rod withdrawal.

The immediate Completion Time reflects the importance of maintaining operation for heat removal. The action to restore must be continued until one loop is restored to OPERABLE status and operation.

SURVEILLANCE SR 3.4.5.1 REQUIREMENTS This SR requires verification

-,, tht the required loops are in operation.

Verification includes flow rate, temperature, and In rnlrfnr onitoring, which help ensure that forced flow is providing heat rm'Oa.TcFc'ec f! c-si 'f~~~consIG18Frng ctl~er '.nJ1catcns and al-iiii -.v.1-leb to mhe Gperater In the conro01Zlroml to oio RES loop pcrformane SR 3.4.5.2 SR 3.4.5.2 requires verification of SG OPERABILITY.

SG OPERABILITY is verified by ensuring that the secondary side narrow range water level is _> 30% for required RCS loops. If the SG (continued)

Farley Units 1 and 2 B 3.4.5-5 Revision 8 RCS Loops -MODE 3 B 3.4.5 BASES SURVEILLANCE REQUIREMENTS SR 3.4.5.2 (continued) secondary side narrow range water level is < 30%, the tubes may become uncovered and the associated loop may not be capable of providing the heat sink for removal oT-he--0 h--1+ 1) 1 i IIlIts lL -,'-ailablo in the i I 1 41 control room to aiort te operator to a loss ot levol.SR 4.5.3 Verification t the required RCPs are OPERABLE ensures that safety analyses*

its are met. The requirement also ensures that an additional RCP can laced in operation, if needed, to maintain decay heat removal andactor coolant circulation.

Verification is performedb ifyingprope'reaker alignment and power availability to the required RCPs.REFERENCES None.Farley Units 1 and 2 B 3.4.5-6 Revision IS RCS Loops -MODE 4 B 3.4.6 BASES ACTIONS B.1 (continued)

If one required RHR loop is OPERABLE and in operation and there are no RCS loops OPERABLE, an inoperable RCS or RHR loop must be restored to OPERABLE status to provide a redundant means for decay heat removal.If the parameters that are outside the limits cannot be restored, the unit must be brought to MODE 5 within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Bringing the unit to MODE 5 is a conservative action with regard to decay heat removal.With only one RHR loop OPERABLE, redundancy for decay heat removal is lost and, in the event of a loss of the remaining RHR loop, it would be safer to initiate that loss from MODE 5 (_< 200°F) rather than MODE 4 (200 to 350'F). The Completion Time of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is a reasonable time, based on operating experience, to reach MODE 5 from MODE 4 in an orderly manner and without challenging plant systems.C.1 and C.2 If no loop is OPERABLE or in operation, except during conditions permitted by Note 1 in the LCO section, all operations involving a reduction of RCS boron concentration must be suspended and action to restore one RCS or RHR loop to OPERABLE status and operation must be initiated.

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 Times reflect the importance of maintaining operation for decay heat removal. The action to restore must be continued until one loop is restored to OPERABLE status and operation.

SURVEILLANCE SR 3.4.6.1 REQUIREMENTS This SR requires verification

' that one RCS or RHR loop is in operation.

Verification includes flow rate, temperature, or Insert 2 ump status monitoring, which help ensure that forced flow is provi ing providering otoredia,,and alams available to the .p.. ator.in the Gcontrl room to moritor RCS and RHR loop performance.(continued)

Farley Units 1 and 2 B 3.4.6-4 Revision 12 RCS Loops -MODE 4 B 3.4.6 BASES SURVEILLANCE REQUIREMENTS SR 3.4.6.2 (continued)

SR 3.4.6.2 requires verification of SG OPERABILITY.

SG OPERABILITY is verified by ensuring that the secondary side wide range water level is >_ 75%. If the SG secondary side wide range Insert 2 Ievel is < 75%, the tubes may become uncovered and the associ d Ioop ýcaable of providing the heat sink necessar or removal of decay The !2 hcur PFrequepey4!

coGr#91 rFc to h prtort the less Gf SG lev-el.S R 3.4.6.3 Verification that the require ump is OPERABLE ensures that an additional RCS or RHR pump n be placed in operation, if needed, to maintain decay heat removal a d reactor coolant circulation.

Verification is performed by verifyin roper breaker alignment and power available to the required pump. Frquency efq7days 6 considered rasonable in VieW of other administrative controls available and has boon shown to be acceptable by operating REFERENCES None.Farley Units 1 and 2 B 3.4.6-5 Revision 19 RCS Loops -MODE 5, Loops Filled B 3.4.7 BASES SURVEILLANCE REQUIREMENTS SR 3.4.7.1 This SR requires verification leve,"y !2 he that the required loop is in operation.

Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing heat removal.Verifying that at least two SGs are OPERABLE by ensuring their secondary side wide range water levels are > 75% ensures an va methodvia n al circulation in the that the seond RHR Ifboth RHR loops a OPERABLE, this Surveillance is not nee .-he-1-2-h SR 3.4.7.3 Verification that a second RHR pump OPERABLE ensures that an additional pump can be placed in operatio ,nneeded, to maintain decay heat removal and reactor coolant circulai n. Verification is performed by verifying proper breaker alignment a ower available to the RHR pump. If secondary side water level is >_ 7 wide range) in at least two SGs, this Surveillance is not needed. The FrFequencY of 7 days is onsidered reasonRa-ble in viow of other F 1 acceptable by operating expo~Rionco REFERENCES

1. NRC Information Notice 95-35, "Degraded Ability of Steam Generators to Remove Decay Heat by Natural Circulation." Farley Units 1 and 2 B 3.4.7-5 Revision 19 RCS Loops, -MODE 5, Loops Not Filled B 3.4.8 BASES ACTIONS (continued)

B.1 and B.2 If no required RHR loops are OPERABLE or in operation, except during conditions permitted by Note 1, all operations involving a reduction of RCS boron concentration must be suspended and action must be initiated immediately to restore an RHR loop to OPERABLE status and operation.

Boron dilution requires forced circulation for uniform dilution, 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 heat removal. The action to restore must continue until one loop is restored to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SR 3.4.8.1 This SR requires verification that one loop is in operation.

Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing heat removal.-rhe F-..i.R, Of 12 hu, ,. s.ff;..g-i9Rt GG. 60;I9F;.. .th r.........

aljm .... ...' tG .... GpIte .. ........ .... .. ... the ......---oI t ... ... le/ .... ... ... ... .. ..S R .4.8.2 erification that the required number of pumps are OPERABLE ensu t additional pumps can be placed in operation, if needed, to maintain deca 7remýoval and reactor coolant circulation.

Verification is performed by proper breaker alignment and Dower available to the required pumps s........

.. 7 considered roascnablo in "iow of other administrative-controls availablo and has boon shown to be acceptable by oporating REFERENCES None.Farley Units 1 and 2 B 3.4.8-3 Revision 0 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 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . The Completion Time of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months is reasonable considering the anticipation 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 group of pressurizer heaters are inoperable and cannot be restored in 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . 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 Insert 2 SR 3.4.9.1 This SR requires that during steady state operation, pressurizer level is maintained below the nominal upper limit to provide a minimum space for a steam bubble. The Surveillance is performed by observ ing the indicated level _Th, .F=, e, wencJ .. ... .h...GOFl eSPOl d te ,ve-if -t4l pal a ete eV, ,V, Gh t Th,,, 12, htV ,,~ o 'A'raF:r. m ar e .;1169 av, i -b l for early d et 8Gto. R SR 3. .2 The SR is s sfied when the power supplies are demonstrated to be capable of pro cing the minimum power and the associated pressurizer heate are verified to be at their design rating. This may be done by measuri circuit current or testing the power supply output and by performi an electrical check on heater element continuity and resistance.he Froq'--G!A of 92 da'S 06 Gonsdered dqoto dotot heAtor de'gra*dtio and boon shown by oporating oxperionco to be acceptablc-.(continued)

Farley Units 1 and 2 B 3.4.9-4 Revision 9 Pressurizer B 3.4.9 BASES SURVEILLANCE REQUIREMENTS SR 3.4.9.3 (continued)

This Surveillance demonstrates that the heaters can be manually transferred from the normal to the emergency power supply and eýnergi -.dT-he F=e ue G .. .. ... 19 F ,n .is ,R ,,,,,.-l fuel... .. As~rtcnt with s.imelp ...... ,i;kA,,i,, A,{ ,M9, GR, ..........

I Insert 2

D..... ........ .. ... ....REFERENCES

1. FSAR, Sections 15.1, 15.2, and 6.2.2. NUREG-0737, November 1980.Farley Units 1 and 2 B 3.4.9-5 Revision 9 Pressurizer PORVs B 3.4.11 BASES ACTIONS G.1 and G.2 (continued)

If the Required Actions of Condition F are not met, then 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . 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. In MODES 4, 5, and 6, the PORVs are not required OPERABLE.SURVEILLANCE SR 3.4.11.1 REQUIREMENTS Block valve cdclinq verifies that the valve(s) can be closed if needed.J?.Te bs~sfcpr-the Freff'-encY

-9f 92 ,.y,. 's the .A.h.Mr C,,,dt Section X! (Rof. 3). If the block valve is closed to isolate a PORV that is capable of being manually cycled, the OPERABILITY of the Insert:2::

block valve is of ipracbecause oeigthe block valve is necessary to permit the PORV to be used for manual control of reactor pressure.

If the block valve is closed to isolate an Ise inoperable PORV, the maximum Completion Time store the PORV and open the block valve is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ,. well t the allowab, le imit (25%) to.extend the block le.reqny o 2 days.. Furthermore, these test requirements would be completed by the reopening of a recently closed block valve upon restoration of the PORV to OPERABLE status (i.e., completion of the Required Actions fulfills the SR).This SR is modified by two Notes. Note 1 modifies this SR by stating that it is not required to be met with the block valve closed, in accordance with the Required Action of this LCO. Note 2 modifies this SR to allow entry into and operation in MODE 3 prior to performing the SR. This allows the test to be performed in MODE 3 under operating temperature conditions, prior to entering MODE 1 or 2. A temporary third note has been added to suspend SR 3.4.11.1 for Unit Two PORV block valve Q2B31 MOV8000B for the remainder of operating cycle 16.(continued)

Farley Units 1 and 2 B 3.4.11-7 Revision 0 Pressurizer PORVs B 3.4.11 BASES SURVEILLANCE REQUIREMENTS SR 3.4.11.2 (continued)

SR 3.4.11.2 requires a complete cycle of each PORV in MODE 3 or 4.The PORVs are stroke tested during MODES 3 or 4 with the associated block valves closed in order to limit the uncertainty introduced by testing the PORVs at lesser system temperatures than I n.srrt 2 3puednduring actual operating conditions.

Operating a PORV MthrouD onec nsures that the PORV can be manually aeJfclTuart mifiaation of --'S'T"The I=FaWRG ...Olrf "8 The Not; modifibsehis SR to allow entry into and operation in MODE 3 prior to performing',toe SR. This allows the test to be performed in MODE 3 under operatin ~eperature conditions, prior to entering MODE 1 or 2.SR 3.4.11.3 SR 3.4.11.3 requires a complete cycle ot ch PORV using the backup PORV control system. This surveilla nme verifies the capability to operate the PORVs using the backup air and trogen supply systems. Additionally, this surveillance ensures thecorrect function of the associated air and nitrogen supply system valves. I Froequoncy is based on a typical refuelin g cyclo and industr; accepted practico for Surnveillances requiring thelPOIR-ks to be cycled.SR 3.4.11.4 SR 3.4.11.4 applies only to Unit 2 for the remainder of cycle 16 for PORV block valve Q2B31 MOV8000B.

It requires that power to the PORV block valve is checked to be available at least every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .This surveillance provides additional assurance that the PORV block valve could be stroked if demanded while SR 3.4.11.1 is suspended.

REFERENCES

1. Regulatory Guide 1.32, February 1977.2. FSAR Sections 5.5 and 15.2.Ae Be I;1 ef D-llll \/esw1 Vesse Gede, I Farley Units 1 and 2 B 3.4.11-8 Revision 0 LTOP System B 3.4.12 BASES SURVEILLANCE REQUIREMENTS SR 3.4.12.1 and SR 3.4.12.2 To minimize the potential for a low temperature overpressure event by limiting the mass input capability, a maximum of one charging pump is verified capable of injecting into the RCS and the accumulator discharge isolation valves are verified closed and locked out.The charging pumps are rendered incapable of injecting into the RCS through removing the power from the pumps by racking the breakers out under administrative control. An alternate method of LTOP control may be employed using at least two independent means to prevent a pump start such that a single failure or single action will not result in an injection into the RCS. This may be accomplished through the Hot Shutdown Panel Local/Remote and pump control switches being placed in the Local and Stop positions, respectively, and at least one valve in the discharge flow path being closed with the position of these components controlled administratively.

I f J I I Ffl I I no~~ ~~ -1 ^in *O Oi at ,i i no r.1 0I.-a,pp an ^f ngi o ^bn T khr n'Agmnin+,no-A ,.r~.nin~

o+,aa an a n+,a n~ aIrn, + ~r& h .~....., Vvt I I ,1 -qU.Feu status9t tH8equip effi.SIR 3.4.12.3 Eah requie OPRABL 871 B , 872 qerequired to S Insert 2 tto meet this L SSR 3.4.12.4 d RHR suction relief valve shall be demonstrated by verifying its RHR suction isolation valves (8701A, A and 8702B) are open. This Surveillance is only e performed if the RHR suction relief valve is being used-Co.The RCS vent of >_ 2.85 square s is proven OPERABLE by verifying its open condition..Oncoover; 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for a Vao that cannot bo lockod, coaodor (continued)

Farley Units 1 and 2 B 3.4.12-10 Revision 12 LTOP System B 3.4.12 BASES SURVEILLANCE REQUIREMENTS SR 3.4.12.4 (continued)

b. Onc8e ve~' 31 days for a valve that i6 locked, sealed, or secured i position.

A removed pressurizer safety valve fits this categ.....

The passive vent arrangement must only be open to be OPERABLE.This Surveillance is required to be performed if the vent is being used to satisfy the pressure relief requirements of the LCO 3.4.12b.in accordance with the qR 3..4.12.5 Surveillance Frequency I" Suroeilac Frequc The RHR reli yes are verified OPERABLE by testing the relief setpoint.

The setpo erification ensures proper relief valve mechanical motion as we verifying the setpoint.

Testing is performed in accordance with nservice Testing Program which is based on the requirements of the A Code, Section XI (Ref. 7).The RHR relief valve setpoints are verifie F;7&Fy1gmotg

.... T ............... ,Per the Inservice Testing Program, if Insert 2 exces the relief setpoint by 3% or greater, the remaining valve shall also T. ,--The freuenc-Y for test*- the RHR relief valves has boon shown to be adequate through operating I REFERENCES

1. 10 CFR 50, Appendix G.2. Generic Letter 88-11.3. ASME, Boiler and Pressure Vessel Code, Section II1.4. FSAR, Chapter 5.2.2.4.5. 10 CFR 50, Section 50.46.6. 10 CFR 50, Appendix K.7. ASME, Boiler and Pressure Vessel Code, Section XI.Farley Units 1 and 2 B 3.4.12-11 Revision 9 RCS Operational LEAKAGE B 3.4.13 BASES SURVEILLANCE SR 3.4.13.1 REQUIREMENTS Verifying RCS LEAKAGE to be within the LCO limits ensures the integrity of the RCPB is maintained.

Pressure boundary LEAKAGE would at first appear as unidentified LEAKAGE and can only be positively identified by inspection.

It should be noted that LEAKAGE past seals and gaskets is not pressure boundary LEAKAGE.Unidentified LEAKAGE and identified LEAKAGE are determined by performance of an RCS water inventory balance.The RCS water inventory balance must be met with the reactor at steady state operating conditions and near operating pressure.

The Surveillance is modified by two Notes. Note 1 states that this SR is not required to be performed in MODES 3 and 4 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state operation near operating pressure have been established.

Steady state operation is required to perform a proper inventory balance; calculations during maneuvering are not useful and a Note requires the Surveillance to be met when steady state is established.

For RCS operational LEAKAGE determination by water inventory balance, 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.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 air cooler condensate flow rate. It should be noted that LEAKAGE past seals and gaskets is not pressure boundary LEAKAGE. These leakage detection systems are specified in LCO 3.4.15, "RCS Leakage Detection Instrumentation." Note 2 states that this SR is not applicable to primary to secondary LEAKAGE. This is because LEAKAGE of 150 gpd cannot be S insert 2 I eS!!e accurately by an RCS water inventory balance.I T h e 2 h c -F r8 GI u e9 cy ro s n b le O .".' te t ero d L EA '-' .G E I a reOcgnizes the f ory leakage detectonR on the prevent'On of acc~dents.

A Note under the Frequency column states that this SR is required to be performed during steady state operation.(continued)

Farley Units 1 and 2 B 3.4.13-5 Revision R RCS Operational LEAKAGE B 3.4.13 BASES SURVEILLANCE SR 3.4.13.2 REQUIREMENTS This SR verifies that primary to secondary LEAKAGE is less than or equal to 150 gpd 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 3.4.17, "Steam Generator Tube Integrity," should be evaluated.

The 150 gpd limit is measured at room temperature as described in Reference

5. 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 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

For RCS primary to secondary LEAKAGE determination, steady state is defined as stable RCS pressure, temperature, power level, pressurizer and makeup tank Insert 2 levels, makeup and letdown, and RCP seal injection and return flows.= ThC aR S'-r- ell c FrFq'- cy , o f 7-2 h'r s rfis a Fsenabe mitcF-l to [of early detection in the prevention of accidents.

During normal operation the primary to secondary LEAKAGE is determined using continuous process radiation monitors or radiochemical grab sampling in accordance with EPRI guidelines.

REFERENCES

1. 10 CFR 50, AppendixA, GDC 30.2. Regulatory Guide 1.45, May 1973.3. FSAR, Section 3.1.2.6, 5.2.7, 10.4, 11.0, 12.0 and 15.0.4. NEI 97-06, "Steam Generator Program Guidelines." 5. EPRI TR-104788, "Pressurized Water Reactor Primary-to-Secondary Leak Guidelines." Farley Units 1 and 2 B 3.4.13-6 Revision R RCS PIV Leakage B 3.4.14 BASES SURVEILLANCE REQUIREMENTS SR 3.4.14.1 (continued) shutdown cooling mode of operation.

PIVs contained in the RHR shutdown cooling flow path must be leakage rate tested when RHR is secured and stable unit conditions and the necessary differential pressures are established.

Leak rate testing is performed manually, with test personnel in the vicinity of the system connections in containment during setup and testing. Should the check valve that was being tested rupture or pressure in the system cause a rupture of the test equipment, there would be a concern for the safety of the personnel in the area. In addition, testing with RCS temperature above 212 °F would result in any leakage past the RHR valves flashing into steam making accurate measurement of the leakage rate impossible.

Therefore, testing of the RHR System PIVs should normally be performed in Mode 5, as the test results are meaningful and plant conditions in Mode 5 minimize the potential impact on personnel safety.I Inert SR 3.4.14.2\ Verifying that the RHR autoclosure interlock is OPERABLE ensures tthat RCS pressure will not pressurize the RHR system beyond 125%of its design pressure of 600 psig. The autoclosure interlock isolates the RHR System from the RCS when the interlock setpoint is reached.setpoint ensures the RHR design pressure will not be exceeded.IT~he 18 mne-h isn-l base h-G-Rl the Reedf to nnrferm undeFr G1Gh-nditione that apply during a plant outage. The 18 monGth FrequcncY is also acceptable based on concidoration of the design reliability (and conffirmning operating experience) of the The SR is modified by a Note that provides an exception to the requirement to perform this surveillance when using the RHR System suction relief valves for cold overpressure protection in accordance with SR 3.4.12.3.(continued)

Farley Units 1 and 2 B 3.4.14-7 Revision R RCS PIV Leakage B 3.4.14 BASES SURVEILLANCE REQUIREMENTS SR 3.4.14.3 (continued)

Verifying that the RHR open permissive interlock is OPERABLE ensures that the RCS will not pressurize the RHR system beyond design of 600 psig. The open permissive interlock prevents opening the RHR System suction valves from the RCS when the RCS pressure is above the setpoint.

The setpoint upper value ensures the RHR System design pressure will not be exceeded at the RHR pump discharge and was chosen taking into account instrument uncertainty and calibration tolerances.

This value also provides assurance that the RHR I Insertuction relief valves setpoint will not be exceeded.The minimum value o oint range is chosen based upon operational considerations (differen ssure) for the RCP seals and thus does not have a safety-related func i .The 18 month Frequency.is based on the need to perform the Sur'-eillaR!

e ncuer conditions that apply during a plant outage. The 18 month Frequoncy is also acceptable based on consideratien o"f the design reliability (and confirmiRg operating exprience) of the equipfrert.

The SR is modified by a Note that provides an exception to the requirement to perform this surveillance when using the RHR System suction relief valves for cold overpressure protection in accordance with SR 3.4.12.3.REFERENCES

1. 10CFR50.2.

2. 10 CFR 50.55a(c).

3. 10 CFR 50, Appendix A, Section V, GDC 55.4. WASH-1400 (NUREG-75/014), Appendix V, October 1975.5. NUREG-0677, May 1980.6. Technical Requirement Manual (TRM).7. ASME, Boiler and Pressure Vessel Code, Section XI.8. 10 CFR 50.55a(g).

Farley Units 1 and 2 B 3.4.14-8 Revision PA I RCS Leakage Detection Instrumentation B 3.4.15 BASES ACTIONS C.1 and C.2 (continued) achieve this status, the plant must be brought to at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . 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 With all required monitors 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 3.4.15.1 SR 3.4.15.1 requires the performance of a CHANNEL CHECK of the required containment atmosphere radioactivity monitor. The check gives reasonable confidence that the channel is operating properly.rG12 us ORr

b:ily I J A I S SR 3.4.15.2 SR 3.4.15.2 requires the performance of a COT on the required containment atmosphere radioactivity monitor. The test ensures that the monitor can perform its function in the desired manner. The test es the alarm setpoint and relative accuracy of the instrument

....... ... ..onth t pep Ff4Fd te t~SR 3.4.15.3 adS' .415.These SRs require the perfo ance of a CHANNEL CALIBRATION for each of the RCS leakage det ion instrumentation channels.

The calibration verifies the accuracy of th strument string, including the instruments located inside containment.'Ihe F-eqeRcy 9f 18 FFth is6 a typical refueling cycle and concidors channel reliability.

Again, oporating oxporionco has proeven that this Froquec Is ccopablo.-

Farley Units 1 and 2 B 3.4.15-5 Revision 19 RCS Specific Activity B 3.4.16 BASES ACTIONS B..1 (continued)

With the gross specific activity in excess of the allowed limit, the unit must be placed in a MODE in which the requirement does not apply.The change within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months to MODE 3 and RCS average temperature

< 500'F lowers the saturation pressure of the reactor coolant below the setpoints of the main steam safety valves and prevents venting the SG to the environment in an SGTR event. The allowed Completion Time of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is reasonable, based on operating experience, to reach MODE 3 below 500'F from full power conditions in an orderly manner and without challenging plant systems.C.1 If a Required Action and the associated Completion Time of Condition A is not met or if the DOSE EQUIVALENT 1-131 is in the unacceptable region of Figure 3.4.16-1, the reactor must be brought to MODE 3 with RCS average temperature

< 500°F within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .The Completion Time of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is reasonable, based on operating experience, to reach MODE 3 below 500°F from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.4.16.1 REQUIREMENTS SR 3.4.16.1 requires performing a gamma isotopic analysis s a Isure of the gross specific activity of the reactor coolans hWhile basically a quantitative measure of radionu *d~es with half lives longer than 15 minutes, excluding iodines, th smeasurement is the sum of the degassed gamma activities andre gaseous gamma activities in the sample taken. This Surveillance pro *d~es an indication of any increase in gross specific activcby.Trending the results of th', Surveillance allows proper remedial action to be taken before reaching e LCO limit under normal operating conditions.

The Surveillanceis tplicable in MODES 1 and 2, and in (continued)

Farley Units 1 and 2 B 3.4.16-5 Revision 9 RCS Specific Activity B 3.4.16 BASES SURVEILLANCE SR 3.4.16.2 REQUIREMENTS (continued)

This Surveillance is performed in MODE 1 only to ensure iodine remains within limit during normal operation and following fast power changes when fuel failure is more apt to oc.,,-:-GG~sF -- aWityicr-entered ee~y7 dys.The Frequency, betweenonurs after a power change > 15% RTP withina Inet2our eriod, is established because the iodine levels peak during this time",fllowing fuel failure; samples at other times would provide inaccurate esults.SR 3.4.16.3 A radiochemical an lysis for E determination is required-ys (6 mcn9ths)Nith the plant operating in MODE 1 equilibrium conditions.

The E dete nination directly relates to the LCO and is required to verify plant op ration within the specified gross activity LCO limit. The analysis for -is a measurement of the average energies per disintegration fo isotopes with half lives longer than 1 5 m in uites exchnluin g inrlin es 18, 4 , a y-- ,,-Imcc~qn-z-G oe n t chan~q e rap!d!'.This SR has been modified by a Note that indicates sampling is required to be performed within 31 days after a minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for at least 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months . This ensures that the radioactive materials are at equilibrium so the analysis for E is representative and not skewed by a crud burst or other similar abnormal event.REFERENCES

1. 10 CFR 100.11, 1973.2. FSAR, Section 15.4.3.Farley Units 1 and 2 B 3.4.16-6 Revision 19 Accumulators B 3.5.1 BASES ACTIONS B.1 (continued)

If one accumulator is inoperable for a reason other than boron concentration, the accumulator must be returned to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . In this Condition, the required contents of two accumulators cannot be assumed to reach the core during a LOCA.Due to the severity of the consequences should a LOCA occur in these conditions, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time to open the valve, remove power to the valve, or restore the proper water volume or nitrogen cover pressure ensures that prompt action will be taken to return the inoperable accumulator to OPERABLE status. The Completion Time minimizes the potential for exposure of the plant to a LOCA under these conditions.

The 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months allowed to restore an inoperable accumulator to OPERABLE status is justified in WCAP-1 5049-A, Rev. 1 (Ref. 3).C.1 and C.2 If the accumulator cannot be returned 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 MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and RCS pressure reduced to< 1000 psig within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . 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 more than one accumulator is inoperable, the plant is in a condition outside the accident analyses; therefore, LCO 3.0.3 must be entered immediately.

SURVEILLANCE SR 3.5.1.1 REQUIREMENTS Each accumulator valve should be verified to be fully open This verification ensures that the accumulators are available for injection and ensures timely discovery if a valve should be less than fully open. If an isolation valve is not fully open, the rate of injection to the RCS would be reduced. Although a motor operated valve position Insert 2 should not change with power removed, a closed valve could result in not meeting accident analyses assti,,.concidored reaonRablo in view Of othnr administrativo conFols that onsuro a m~iGpocitionod isolation valve is unli~kely-.(continued)

Farley Units 1 and 2 B 3.5.1-6 Revision P Accumulators B 3.5.1 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.1.4 The bor concentration should be verified to be within required limits for each ccumulator leve -y since the static design of the ac mulators limits the ways in which the concentration can be changed.ha'tsm " u~ a " SatfatOOFI-Ga( .bamplning the S Insert 2 affected accumulator within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a 12% level, indicated, inl has caused a reduction in boron concentration to below the re( ,r limit. It is not necessary to verify boron concentration if the added w re inventory is from the refueling water storage tank (RWST), when the wa contained in the RWST is within the accumulator boron concentration re irements.

This is consistent with the recommendation of NUREG-1366

(.4).SR 3.5.1.5 Verification that p er is removed from each accumulator isolation valve operator when the pr urizer pressure is >_ 2000 psig ensures that an active failure could not ult in the undetected closure of an accumulator motor operated isolation lve. If this were to occur, only one accumulator would be available for in ction given a single failure coincident with a LOCA. Therefore, each i ation valve operator S Hiscxanel by a !onkerd onen feAif.i remoede und-eir aldM. .. ,istbrafth.;

c-etrO91, the 3! a , 4.e,= ....... .... ..This SR allows power to be supplied to the motor operated isolation valves when RCS pressure is < 2000 psig, thus allowing operational flexibility by avoiding unnecessary delays to manipulate the breakers during plant startups or shutdowns.(continued)

BASES Farley Units 1 and 2 B 3.5.1-7 Revision P ECCS -Operating B 3.5.2 BASES ACTIONS B.1 and B.2 (continued)

If the inoperable trains cannot be returned 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 MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . 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 3.5.2.1 REQUIREMENTS Verification of proper valve position ensures that the flow path from the ECCS pumps to the RCS is maintained.

Misalignment of these valves could render both ECCS trains inoperable.

Securing these valves in position by removal of power by locking open the disconnect device to the valve operators ensures that they cannot change position as a result of an active failure or be inadvertently misaligned.

These valves are of REQUIREMENTS the type, described in Reference 6, that can disable the function of both ECCS trains and invalidate the accident analyses.

SR 3.5.2.1 is modified by a Note that specifies when this SR is applicable to valves 8132 A/B. Valves Ir 2otential to disable both ECCS trains when centrifugal charging pump "A" is inoperab e). A 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Froquoncy

.I considered roasonable in viowy of other administrative controls; that will I ensure a mispositoneld valve Uis ikely, I SR 3.5.2.2 Verifying the correct alignment for manual, power operated, and automatic valves in the ECCS flow paths provides assurance that the proper flow paths will exist for ECCS operation.

This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these 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 will automatically reposition 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 (continued)

Farley Units 1 and 2 B 3.5.2-8 Revision 12 ECCS -Operating B 3.5.2 BASES SURVEILLANCE SR 3.5.2.2 (continued)

REQUIREMENTS mispositioned are in the correct position .T.h. 3 day. ,Frq ....is control, and an imprper valve old Only affect a sing train Thi~ Wrte 1a30. h-g pnair.~ nNAGnnnanale thi:G eug operatingoprino SR 3.5.2.3 Periodic surveilla e testing of ECCS pumps to detect gross degradation c ed by impeller structural damage or other hydraulic component oblems is required by Section XI of the ASME Code.This type f testing may be accomplished by measuring the pump devel ed head at only one point of the pump characteristic curve.S Insert 2 I Fm-r-xample, if measured on recirculation flow, the centrifugal char ig pumps should develop a differential pressure of > 2323 psid and the sidual heat removal pumps should develop a differential pressure o > 145 psid. This verifies both that the measured performance i within an acceptable tolerance of the original pump baseline perfor nce and that the performance at the test flow is greater than or eq I to the performance assumed in the plant safety analysis.

Testing is rformed in accordance with the Inservice Testing Program, which ncompasses Section XI of the ASME Code.Section XI of the ASME Ce provides the activities and Frequencies necessary to satisfy the requ' ments.SR 3.5.2.4 and SR 3.5.2.5 These Surveillances demonstrate that ch automatic ECCS valve actuates to the required position on an ac al or simulated SI signal and that each ECCS pump (centrifugal char g and RHR) starts on receipt of an actual or simulated SI signal. ThiSurveillance is not required for valves that are locked, sealed, or oth ise secured in the required position under administrative controls.FrFequency is based OR the need to performn those Sur.'illances under the- conditions, that apply during a plant outage and the potential for unlplanned plant transientS if tho Surveillancer, wore perfoFrmed with the reactor at powor. The 18 monGth FrFequlency is also acceptal based Gonosideration Of the- desi-;gn reliability (and confirmingR operating experience) of the equipment.

The actuation logic is tested as part of ESP Actuation System testing, and equipment perfoFrmance is monitored as, part o~f the Inservico Tes6ting Programn.(continued)

Farley Units 1 and 2 B 3.5.2-9 Revision 9 ECCS -Operating B 3.5.2 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.2.6 Realignment of valves in the flow path on an SI signal is necessary for proper ECCS performance.

These valves have stops (RHR valves) or locking devices (other ECCS valves) to allow proper positioning for limiting total pump flow and/or restrict flow to a ruptured cold leg, ensuring that the other cold legs receive at least the required minimum flow. The required verification for the RHR valves, 603 A/B, assures that the associated pump will not be run out. For other ECCS Periodic inspectnis of the containment sump suction inlet ensure that it is unrestricted an ays in proper operating condition.

The inlet screens consist of perfo d plates arranged such that their outer edges form a trash rack to re ce clogging of the screen surface by large debris. Each plate is cover by wire mesh to further protect against clogging by smaller debris. aration between plates is maintained by spacers and each plate is i ed to a central perforated cylinder, or inner cage, which collects the flo rough each plate.Inspection of the screen plate structure, wire mes creen, perforated plates and inner cage for evidence of structural distre or abnormal corrosion ensures that the inlet trash racks, screens and 'iher cages are properly installed and will perform their intended function.

The 18 month FrFequencY is based on the Reed to perform this SUrfeillanco undor the conditions that apply during a plant outage, and the need to have acce~s to the location.

This Frequency-1has been founRd to be SUffGiciot to detect abnremal degradation and is GGoAFirmd by operating exp.ine REFERENCES

1. 10 CFR 50, Appendix A, GDC 35.2. 10 CFR 50.46.3. FSAR, Section 6, "Engineered Safety Features." 4. FSAR, Chapter 15, "Accident Analysis." (continued)

Farley Units 1 and 2 B 3.5.2-10 Revision P ECCS -Shutdown B 3.5.3 BASES SURVEILLANCE REQUIREMENTS SR 3.5.3.2 (continued)

Verification of proper valve alignment ensures that the flow path from the ECCS pumps to the RCS is maintained.

Misalignment of these valves could render the required ECCS trains inoperable.

Securing these valves in position by removal of power by locking open the breaker or disconnect device for the valve operator ensures that they Insert 2 caMeosit ion as a result of an active failure or be inadvertantl.

misalig n .ay "q" G ..

reaSonable in VieWN of other adminisitrative conRtrols that 41ll enSUre a mnispositioned valve is unlikely and this frequency has becn shown to be acceptable by operating experience.

REFERENCES The applicable references from Bases 3.5.2 apply.Farley Units 1 and 2 B 3.5.3-5 Revision P RWST B 3.5.4 BASES ACTIONS A.1 (continued)

System can perform its design function.

Therefore, prompt action must be taken to restore the tank to OPERABLE condition.

The 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months limit to restore the RWST temperature or boron concentration to within limits was developed considering the time required to change either the boron concentration or temperature and the fact that the contents of the tank are still available for injection.

B.1 With the RWST inoperable for reasons other than Condition A (e.g., water volume), it must be restored to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .In this Condition, neither the ECCS nor the Containment Spray System can perform its design function.

Therefore, prompt action must be taken to restore the tank to OPERABLE status or to place the plant in a MODE in which the RWST is not required.

The short time limit of 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to restore the RWST to OPERABLE status is based on this condition simultaneously affecting redundant trains.C.1 and C.2 If the RWST cannot be returned 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . 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 3.5.4.1 REQUIREMENTS The RWST borated water temperature should be verified to be above the minimum limit assumed in the accident (continued)

Farley Units 1 and 2 B 3.5.4-5 Revision 9 RWST B 3.5.4 BASES SURVEILLANCE REQUIREMENTS SR 3.5.4.1 (continued)

The SR is modified by a Note that eliminates the requirement to perform this Surveillance when ambient air temperature is within the operating limit of the RWST. With ambient air temperature within the limit, the RWST temperature should not exceed the limit.SR 3.5.4.2 The RWST water volume should be verified e to be above the required minimum level in order to ensure that a sufficient initial supply is available for injection and to support continued ECCS and The boron con ntration of the RWST should be verified to be wih the required limits. This SR ensures that the reactor will remain s critical following a LOCA. Further, it assures that the resulting sump will be maintained in an acceptable range so that boron precipitation' ithe core will not occur and the effect of chloride and caustic stress co osion on mechanical systems and com onents will be minimized.....................................

stable, a 7 day samplin Froquencýy to vorif,' boronR concentration is appropria te and has boon Shown to be acceptable through operating expe~eR~e.

I REFERENCES

1. FSAR, Chapter 6 and Chapter 15.Farley Units 1 and 2 B 3.5.4-6 Revision 9 Seal Injection Flow B 3.5.5 BASES ACTIONS A.1 With the seal injection flow exceeding its limit, the amount of charging flow available to the RCS may be reduced. Under this Condition, action must be taken to restore the flow to below its limit. The operator has 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from the time the flow is known to be above the limit to perform SR 3.5.5.1 and correctly position the manual valves and thus be in compliance with the accident analysis.

The Completion Time minimizes the potential exposure of the plant to a LOCA with insufficient injection flow and provides a reasonable time to restore seal injection flow within limits. This time is conservative with respect to the Completion Times of other ECCS LCOs; it is based on operating experience and is sufficient for taking corrective actions by operations personnel.

B.1 and B.2 When the Required Actions cannot be completed within the required Completion Time, a controlled shutdown must be initiated.

The Completion Time of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for reaching MODE 3 from MODE 1 is a reasonable time for a controlled shutdown, based on operating experience and normal cooldown rates, and does not challenge plant safety systems or operators.

Continuing the plant shutdown begun in Required Action B.1, an additional 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is a reasonable time, based on operating experience and normal cooldown rates, to reach MODE 4, where this LCO is no longer applicable.

SURVEILLANCE REQUIREMENTS I Insert 2 SR 3.5.5.1 Verification e that the manual seal injection throttle.valves are adjusted to give a flow within the limits (operation in the acceptable region of Figure 3.5.5-1) ensures that proper manual seal injection throttle valve position, and hence, proper seal injection flow, is maintained.

A differential pressure that is above the reference minimum value is established between the charging header (PT-121, charging header pressure) and the pressurizer, and the total seal injection flow is verified to be within the limits determined in accordance with the __( safety anaiy-i- ihe Pe%,IeAGv..

.I -31 days i6 ba6od On judgMent and..it onsisterntith other EGCS valve Sur~eillaRco Fre~quencies.

The FrFequency has provon to be acceptable through ePerating8X xeiencI (continued)

Farley Units 1 and 2 B 3.5.5-3 Revision 19 ECCS Recirculation Fluid pH Control System B 3.5.6 BASES SURVEILLANCE REQUIREMENTS SR 3.5.6.1 (continued) three TSP storage baskets. The baskets are marked with a minimum and maximum fill level that corresponds to a total TSP volume of between 185 ft 3 and 215 ft 3.The verification that the storage baskets contain the required amount of trisodium phosphate is accomplished by verifying that the TSP level is between the indicated fill marks on the baskets. The intent of the surveillance requirement is to verify containment of the TSP by visual inspection.

Therefore, broken, Insert 2 crimped, or oxidized screen mesh is acceptable as long as the contents are contained.

Also, lumps/caking is an analyzed condition.

T ,he 1!- menth freq'--'Rny is bared eR the passive natue Of the system and the low probability of an undetected change in the T-SP volume.occurrig duriFg the interval.REFERENCES

1. FSAR, Section 6.2.2. FSAR, Section 15.Farley Units 1 and 2 B 3.5.6-5 Revision 12 Containment Air Locks B 3.6.2 BASES SURVEILLANCE SR 3.6.2.1 (continued)

REQUIREMENTS Rate Testing Program. This SR reflects the leakage rate testing requirements with regard to air lock leakage (Type B leakage tests).The acceptance criteria were established during initial air lock and containment OPERABILITY testing. The periodic testing requirements verify that the air lock leakage does not exceed the allowed fraction of the overall containment leakage rate. The Frequency is required by the Containment Leakage Rate Testing Program.The SR has been modified by two Notes. Note 1 states that an inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test. This is considered reasonable since either air lock door is capable of providing a fission product barrier in the event of a DBA. Note 2 has been added to this SR requiring the results to be evaluated against the acceptance criteria which is applicable to SR 3.6.1.1. This ensures that air lock leakage is properly accounted for in determining the combined Type B and 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 in and out of the containment.

Periodic testing of this interlock demonstrates that the interlock will function as designed and Is i that simultaneous opening of the inner and outer doors will not Ins rt2 I inad ve , , h. .. ...tr ainterlock, and given that the interlock mnechanism is ot nremally challenged when the con-tainmen-t air lock de:oorgi used for entr,' and exit (procedures requnire strict adherence t o sigle door opening), this test i only requir~ed to be perfoFrmed every 21 mon~thS. The 24 monGth FFrequency is based On the need to. perform this Surpeillane un~der the conRditions that apply during a plant outage, and the potential for loss of containm~ent OPE=RABILITY:

if the suriweillance Were performed with the reactorF at power. T-he- 214 month FrFequJency for the interlock is justified based on geei opeating oxperienco.

The FrFequ:ency is based on engneeingjudgment and is considered adequate given that h interloc-k is, not challengaed during the use of the airloc-rk.

Farley Units 1 and 2 B 3.6.2-7 Revision 9 Containment Isolation Valves B 3.6.3 BASES ACTIONS D.1, D.2, and D.3 (continued)

In the event one or more penetration flow paths containing containment purge valves, have penetration leakage such that the sum of the leakage for all Type B and C tests is not within limits, purge valve penetration leakage must be restored such that the overall Type B and C testing limit is not exceeded, or the affected penetration flow path must be isolated.

The method of isolation must be by the use of at least one isolation barrier that cannot be adversely affected by a single active failure. Isolation barriers that meet this criterion are a closed and de-activated automatic valve, closed manual valve, or blind flange. A purge valve with resilient seals utilized to satisfy Required Action D.1 must have been demonstrated to support the penetration meeting the leakage requirements of SR 3.6.3.5. The specified Completion Time is reasonable, considering that one containment purge valve remains closed so that a gross breach of containment does not exist.In accordance with Required Action D.2, this penetration flow path must be verified to be isolated on a periodic basis. The periodic verification is necessary to ensure that containment penetrations required to be isolated following an accident, which are no longer capable of being automatically isolated, will be in the isolation position should an event occur. This Required Action does not require any testing or valve manipulation.

Rather, it involves verification, through a system walkdown, that those isolation devices outside containment capable of being mispositioned are in the correct position.

For the isolation devices inside containment, the time period specified as "prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days" is based on engineering judgment and is considered reasonable in view of the inaccessibility of the isolation devices and other administrative controls that will ensure that isolation device misalignment is an unlikely possibility.

For the containment penetration containing a containment purge valve with resilient seal that is isolated in accordance with Required Action D.1, SR 3.6.3.5 must be performed at least once every 92 days.This assures that degradation of the resilient seal is detected and confirms that the leakage rate of the containment purge valve penetration does not increase during the time the penetration is isolated.

The normal forSR 3.6.3.5, 184 days, ,.ecstablished as part of the generic resolution by the NRC staff-of Gonoric Issue B 20 (Ref. 3). Since more reliance is placed on (continued)

Farley Units 1 and 2 B 3.6.3-9 Revision 9 Containment Isolation Valves B 3.6.3 BASES ACTIONS D.1, D .2, and D.3 (continued) a single valve while in this Condition, it is prudent to perform the SR more often. Therefore, a Frequency of once per 92 days was chosen and has been shown to be acceptable based on operating experience.

E.1 and E.2 If the Required Actions and associated Completion Times of Condition A, B, C, or D 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.F.1 In the event one or more penetration flow paths containing containment purge valves have penetration leakage which exceeds the individual purge valve penetration leakage limit, purge valve penetration leakage must be reduced to within the limit prior to the next time that the unit transitions from MODE 5 to MODE 4. Provided that the penetration flow path leakage does not cause the total leakage from all Type B and C tests to exceed the limits, no additional action is required (i.e., isolation or unit shutdown).

If the leakage is sufficient to cause the total leakage from all Type B and C tests to exceed the limits, Condition D also applies.SURVEILLANCE REQUIREMENTS SR 3.6.3.1 Each 48-inch containment purge valve (C -HV-3198A, 3198D, 3196, 3197) is required to be verified sealed close P .....y m! .This Surveillance is designed to ensure that a gross breach of containment is not caused by an inadvertent or spurious opening of a containment purge valve. Detailed analysis of the 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 containment purge valve that is sealed closed must have motive power to the valve operator removed. This can be accomplished by de-energizing the (continued)

Farley Units 1 and 2 B 3.6.3-10 Revision 12 Containment Isolation Valves B 3.6.3 BASES SURVEILLANCE SR 3.6.3.1 (continued)

REQUIREMENTS source of electric power or by removing the air supply to the valve operator.

In this application, the term "sealed" has no connotation of la~k tightness jP -4h Fqe RG isllt ln'l *ra o11 Fe ul ÷hf rth nrr a*Llirn tht; NIRIC" Ge I fan r~r,, -Ao R (Ref.4),t Feae GO SR 3.6.3.This SR r quires verification that each containment isolation manual valve an blind flange located outside containment and not locked, sealed, r otherwise secured and required to be closed during accident conditi ns is closed. The SR helps to ensure that post accident leakaq6 of radioactive fluids or gases outside of the containment Inr2haundary is within design limits. This SR does not require any testing C1 or valv,_e:ý

~ lton. IRather, it involves verification, throug teým walkdown, that those containment isolation valves outside contamt and capable of being mispositioned are in the correct positio t. Since vorifiicatio of valVe position for containmon~t isolation valves, ou1tido contalnmont-is relatively easy, the 31 day FrequoncGy is based OR cnginoorineg judgment and was choson to provide added assuranceB of the cerroct Pitiei

The SR specifies that containment isolation valves that are open under administrative controls are not required to meet the SR during the time the valves are open. This includes RHR-MOV-8701A and RHR-MOV-8702A which may be opened and power removed under administrative controls when the plant is in MODE 4 (for ensuring over-pressure protection system operability).

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 and 4 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.(continued)

Farley Units 1 and 2 B 3.6.3-11 Revision KA Containment Isolation Valves B 3.6.3 SURVEILLANCE SR 3.6.3.5 (continued)

REQUIREMENTS purge and exhaust penetration leakage limit is based on not exceeding the total combined leakage rate limit for all Type B and C testing specified in 5.5.17, Containment Leakage Rate Testing Program.Operating experience has demonstrated that this type of seal has the potential to degrade in a shorter time period than do other seal types.on this observation and the importance of maintaining this ,penetration leak tight (duo to the direct path botween containment and the Rnvaient.)

day Frequency of 14 days was establizhed as part ol t he goenoeric r.esolu- -i-tion by the NRC staff of GonReic Issue B-20,T 1.Containment Le-akage Due to Seal DeteriorFatfion" (Re.3)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 I e interval (from 184 days) is a prudent measure after a valve has been opened.f-;-L SR 3.: Auto tic conta t isolation valves close on a containment isolation nal to preve akage of radioactive material from containmen ollowing a DBA. s SR ensures that each automatic containment isolation valve will actu to its isolation position on a containment isolation signal (Phase A or e B). This surveillance is not required for valves that are locked, seale , otherwise secured in the required position under administrative controls.FrFequency is based an the need to performA this Surveifllance un~der the conitinsthat apply during a plant outage, durin~g the COLD SHU-T-DOWN or REFUELING MODE=S or defuoeled, and the potential for an unplanned transient if the Surveillance wore perfoFrmed with the reacetor at power. Operating experience has shoWn that th componen2ts usually pace this Suvillance-AR6 w.Ahen perfoFrmed at the 18month FrFequency.

Threoete FrFequency was concluded to be acceptable fromR a reliWability standIpoint.

Farley Units 1 and 2 B 3.6.3-13 Revision 9 Containment Isolation Valves B 3.6.3 BASES REFERENCES

1. FSAR, Section 15.2. FSAR, Section 6.2.5. Standard Review Plan 6.2.4.Farley Units 1 and 2 B 3.6.3-14 Revision [N ACTIONS Containment Pressure B 3.6.4 A.1 When containment pressure is not within the limits of the LCO, it must be restored to within these limits within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . The Required Action is necessary to return operation to within the bounds of the containment analysis.

The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 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 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . 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 I Insert 2 SR 3.6.4.1 Verifying that containment pressure is within limits ensures that unit operation remains within the limits assumed in the containment atnýLThe 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frop-uencyGl4o sh SR was developod bared On-- I # I~portingexpriono rlated to #eRodhig Of containment pre6Suro..riation ,,duing the applicable MODES. Furthormore, the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Froouoncvm isll conidre adnaoi iwo to niaionsV 41A14ilab iR theGGctrol room, including alarms, to ale-r the operator to an abnormnal containmon~t pressure condition.

REFERENCES

1. FSAR, Section 6.2.2. 10 CFR 50, Appendix K.Farley Units 1 and 2 B 3.6.4-3 Revision 12 Containment Air Temperature B 3.6.5 BASES 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 four of the following sensor locations with at least two being containment air cooler intake sensors: Instrument Number TE3187 E, F, G, & H TE3188 H & I TE3188 J Sensor Location Containment Air Cooler Intake Lower Compartment Reactor (lower)ZI Inset obsorvod slow rato. s of temperature increase within a" a resul;--t of onviFronmontal heat Fsourcoes (due to tho large volume ot cn,,tain,,,nt).

Futhermoroe, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequec is considr adequate i.i.ootrincaonr aibleine contrl romn including alaFrms, to alert the oper-;Ator Wo Ran Aabnoral contRaiment temperature conRditionR.

REFERENCES

1. FSAR, Section 6.2.2. 10 CFR 50.49.Farley Units 1 and 2 B 3.6.5-4 Revision 9 Containment Spray and Cooling Systems B 3.6.6 BASES ACTIONS (continued)

E.1 and E.2 If the Required Action and associated Completion Time of Condition C or D of this LCO 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.F.1 With two containment spray trains or any combination of three or more containment spray and cooling trains inoperable, the unit is in a condition outside the accident analysis.

Therefore, LCO 3.0.3 must be entered immediately.

SURVEILLANCE REQUIREMENTS SR 3.6.6.1 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.

This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these were verified to be in the correct position prior to locking, sealing, or securing.

This SR does not require any testing or valve manipulation.

Rather, it involves verification, through a system walkdown, that those valves outside containment (only check valves are inside containment) and capable of potentially being mispositioned are in the correct position.S Insert 2 3.6.6.2 Operatin each required containment cooling train fan unit for_>15 minute nsures that all trains are OPERABLE and that all associated cont s are functioning properly.

It also ensures that blockage, fan or mo failure, or excessive vibration can be detected for corrective action. T ans are started from the control room (unless already operatinq).

The 31 day Frqu-RnY war, developed c...id tho knoWn ..liability of the fan units and c.ntro., , the to train redundancy available, and the low probability Of Significn (continued)

Farley Units 1 and 2 B 3.6.6-8 Revision Pq I Containment Spray and Cooling Systems B 3.6.6 BASES SURVEILLANCE REQUIREMENTS SR 3.6.6.2 (continued) degradation of the containmont cooling train occurring botwee SuRvo3.6 It h.a alro boon Ahown to be acceptable tFhroug operating experience.-

S R 3.6.6.3 Verifying that the SW flow rate to each containment cooling train is I-Insert 2 I 6rovides assurance that the design flow rate will be achieved (Ref. 37. safety analyses show that, under post-accident conditions, a flow rate o one fan unit is sufficient to meet the post-accident heat removal requirement

.-The F-qG-GY was developed consider*ig the kRnow reliability of the Cooling Water System, the- Wo9 train* redundancy available, and the low probability Gt a sign ificant degradation Of flow occurrin~g between survillances.

S R 3.6.6.4 Verifying 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. On recirculation flow each pump develops a discharge pressure of > 210 psig. On full flow testing, each pump is run and the flow directed through the containment spray system test line into the refueling canal. The flow is throttled across the pump curve via the regulating globe valve in the test line. Flow and differential pressure are normal tests of centrifugal pump performance required by the ASME Code for Operation and Maintenance of Nuclear Power Plants (Ref. 6). Since the containment spray pumps cannot be tested with flow through the spray headers, they are tested on recirculation flow and full flow to the refueling canal. Taken together, these tests confirm the pump design curve and are indicative of overall performance.

Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by abnormal performance.

The Frequency of the SR is in accordance with the Inservice Testing Program.SR 3.6.6.5 and SR 3.6.6.6 These SRs require verification 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 actuation of a containment High-3 pressure signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the (continued)

Farley Units 1 and 2 B 3.6.6-9 Revision Pq Containment Spray and Cooling Systems B 3.6.6 BASES SURVEILLANCE REQUIREMENTS SR 3.6.6.5 and SR 3.6.6.6 (continued) r e q u ir e d p o s it io n u n d e r a d m in is t r a t iv e c o n t r o l s .,, T -h e.8 Fe a t h t h e t hve l a tc a p p l c o n t in m e as u p sl a t io v a l e s is a ls r e q u ir e by S~ R t u.. ..As ually ps s th ane Sup. be use t s atif b th e TheisSeuiresveilacoficto htec containmesupioaont coolvsing aloreqire by S R 3. 5.2.5 .Ad s in l 3. u. v Hance- may be- used tosat isfy" bof thc b !i Ins rt ns Ti s SR rqi res th era i n leht ea che clo ntdain denthe oingpra inea e drained~ baays lton ' v.~ s red 9iR or sm ke ca e alo n d through ~~~ h~ g te tc nn c i n .h su es tat in eacxpe ray .Soze e u n o str c te .n p ro v i es a s s u ra n cte i d o~~a c 6 3ov ra g o f th e conhhthenmentaduing spay ainlent vavs lose the spayheader l 6c -cc 8~rcto .f .,h .o--a]REFERENCES

1. 10 CFR 50, AppendixA, GDC 38, GDC 39, GDC 40, GDC 41, GDC 42, and GDC 43.2. 10 CFR 50, Appendix K.3. FSAR, Section 6.2.4. FSAR, Section 7.3.(continued)

Farley Units 1 and 2 B 3.6.6-10 Revision P I HMS B 3.6.8 BASES SURVEILLANCE REQUIREMENTS SR 3.6.8.1 Operating each HMS train for > 15 minutes ensures that each train is OPERABLE and that all associated controls (including starting from the control room) are functioning properly.

It also ensures that blockage, fan and/or motor failure, or excessive vibration can be detected for corrective actioq,ýWhile this systerm is not inclu-de-d in the GG*Me 0 n~~~-e16ýg(S-FC FqeG W I -^ ^r2+/-nfe 1; rAAR--- -ý -:!%I ifarnm~ +1 rmfA n l,1 1 n*, -n r ~ ~ c ~mlrrnrrl..,r W rl I -y. -1i -1 1 -1. 1 1 11.. 1 -. _9 r o a 'v.the tw-lirdndancy available-.

I-'a , cFr Insert 2 3.6.8.2 r ifying each HMS fan speed is -1320 rpm ensures that each tral is capable aintaining localized hydrogen concentrations below the fl mability limit. I he I8 month FrFq'dE1 c'i us based OR the Reed te umd-e.r the Genditions that apply dWing a plaRt Gutage --+-Rtial f4aF aR uRplanned tFaR6*eRt if the SuP411aRGe WArA the FeaGtGF at peweF. OpeFatiRg 8XP9Fi9AG8 has.-POReRts usually pass the Sup,41WRGe wh PeFfer.m.ed at the 2 MGRth F=FeqUeRGY.

TheFefeFe, the F-FeqWeRGY was r-RIORWI*ty MaRdpeipt-.

SR 3.6.8.3 This SR ensures that each S train responds properly to a Safety Injection actuation signal. The urveillance verifies that each fan starts from the nonoperating conditionn.th I' ,8RG, ;6 bed oR the need to pormr#OF this undr the cnrditi;ns that apply during a plant outage and the potential for an unplanned transient if the Survellanc-were perFormed with the reactor at power. Operating exeine has shown there components usually pass the Surveillance whn eformed at the 18 monOth rFrequency.

Therfore, the FrFequency was, concluded to be8 acceptable from a relia"biliy' standpoint-.

REFERENCES

1. Deleted 2. Deleted 3. Regulatory Guide 1.7, Revision 1.4. WCAP 7901, Revision 1.Farley Units 1 and 2 B 3.6.8-5 Revision P Reactor Cavity Hydrogen Dilution System B 3.6.9 BASES ACTIONS B.1 (continued)

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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . The allowed Completion Time of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.6.9.1 REQUIREMENTS Operating each RCHDS train for ?_ 15 minutes ensures that each train is OPERABLE and that all associated controls are functioning properly and that each fan may be started by operator action from the control room. It also ensures that blockage, fan and/or motor failure, or excessive vibration can be detected for corrective action While This Stech RCHDS train responds properly to a Safety Injection signal.

verifies that each fan starts from the n cnditior.'The 18 month Feuen-c, is based on the noed t WpRfomtisG Suremilclnc

_eo the pmonditionsthaty appl durin fa plante oug a nd thepoenia foranunplanne SftraInjientifn theal Surveillance veepeermfedsit thet reacto fatnpoterts from, the non-operating,,.-

c ,.n ,..t ..The 49 ...e.... , ,eq.l RG.. 6r, based Operatin expeienc has GhoWn these components usually pass the Surveillance when performed at the 18 month FrFequ1ency.

Therefore, the FrFequencY was concluded to be acceptable fro~m a reliability REFERENCES

1. Deleted 2. Deleted 3. Regulatory Guide 1.7, Revision 0.Farley Units 1 and 2 B 3.6.9-4 Revision R ARVs B 3.7.4 BASES ACTIONS B.1 (continued) be possible with the unit at power. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time is reasonable to repair inoperable ARV lines, based on the availability of the Steam Dump System and MSSVs, and the low probability of an event occurring during this period that would require the ARV lines.C.1 and C.2 If the ARV 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in MODE 4 within 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months . 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 3.7.4.1 To perform a controlled cooldown of the RCS, the ARVs must be able to be opened either remotely or locally and throttled through their full range. This SR ensures that the ARVs are tested through a full control cycle at least once per fuel cycle. Performance of inservice testing or use of an ARV durinq a unit cooldown may satisfy this requirement.

the SurveilAnceP-when oformed at the 18 mon~th FrFequency.

The Frequency s aGcceptable from a reliability standpoint.

S nsert 2 R .7.4.2 The function o manual isolation valve is to isolate a failed open ARV. Cycling the m isolation valve both closed and open demonstrates its capability erform this function.

Performance of inservice testing or use of the ma I isolation valve during unit cooldown may satisfy this requirement.

Gperat* ar4hs shown that thes copOneRSt wsually pass, the Sur4eill-nce when performed at the 18 month Frequency.

The FrequencY is acceptable fromF a reliabiity standpin.Farley Units 1 and 2 B 3.7.4-4 Revision 12 AFW System B 3.7.5 BASES SURVEILLANCE SR 3.7.5.1 (continued)

REQUIREMENTS This surveillance is modified by a Note that provides an exception for the AFW flow control valves. The verification of the AFW flow control valves in the full open position is not required during low power operation

(< 10% RTP) or when the AFW system is not in automatic control. The system is considered in automatic control when it is in standby for AFW automatic initiation and not being operated manually.

The provisions of this note allow operation such as a normal unit startup or shutdown and required AFW pump testing at power to be performed without violating the requirements of this SR.In addition, this surveillance includes verification that the stop check valves 3350A, 3350B, and 3350C are in the open position with the I In_._rt 9 .kbreaker to the valve operators locked open.1 ~I\'Yhe 31 day Freq'JeRcy 06 based With th-o procedural onsur~ec -orrecGt ValveA poSitions ORn engineering judgmeRnt, i~OtR#9l governing valve operation, and SR 3.7.5.2 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 normal tests of centrigufal pump performance required by Section XI of the ASME Code (Ref 2).Because it is undesirable to introduce cold AFW into the steam generators while they are operating, this testing is performed on recirculation flow. This test confirms one point on the pump design curve and is 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 Code, Section XI (Ref. 2)(only required 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.

This deferral is required because there is insufficient steam pressure to perform the test.(continued)

Farley Units 1 and 2 B 3.7.5-8 Revision 9 AFW System B 3.7.5 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.7.5.3 This SR verifies that AFW can be delivered to the steam generators in the event of any accident or transient that generates an ESFAS, by demonstrating that each automatic valve in the flow path actuates to its correct position on an actual or simulated actuation (automatic pump start) signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls#-Thoe 18 month Froqu'oncy iS barod on the need to -H ndeF the GGR&EGRG that ap*EI61FiRg a aRd the peteRtial fGF an WRplaRRed tFaRsieRt if the 96iweella-e pe-fe-.FFReEl with the FeaGtGF at peweF. The 19 rRepth F=FequeR-,, __Ge. on epeFatiRg ind the d66igR F ._Wnt'ý Of t equipment.

-7 .7 SR.R.5.4 his SR verifies that the AFW pumps will start in the event of any... ..accident or transient that generates an ESFAS by demonstrating that Insteach AFW pump starts automatically on an actual or simulated a ation signal in MODES 1, 2, and 3. The motor-driven pumps must bS rified to start on SI, SG water level low-low in any SG, and loss of offsite et. The turbine-driven pump must be verified to start on under-volta n tw~o out of three RCP buses and SG water le v e l lo w -lo w in tw o S Gsa c h e u m u lnao r t h F rfic e '-nt is b a s od Ot t he Reed)N1toOA -A an Q1(2)N12VOO1B-B 6d E acthe GG os team admsso d , r; n ,a~ u ,÷,ag a the pe t ;,tia f oe a -n , ,nrl-ared tfar s-ie t " ;f th8 This SR is modified by a Note that indicates the SR may be deferred until suitable test conditions are established.

This deferral is required because there is insufficient steam pressure to perform the test.S R 3 .fi7.5.5 This SR verifies that the air stored in turbine-driven AFW pump steam admission valve air accumulators is sufficient to open valves Q1(2)N12V001A-A and Q1(2)N12V001B-B.

Each steam admission valve has an air accumulator associated with it. The air accumulators provide sufficient air to ensure the operation of the steam admission valves for turbine-driven AFW pump during a loss of power or other (continued)

Farley Units 1 and 2 B 3.7.5-9 Revision 9 AFW System B 3.7.5 BASES SURVEILLANCE SR 3.7.5.5 (continued)

REQUIREMENTS failure of the normal air suppp4.y-The 1 R;,),,,,;

f ..ba,,4 ,n the-,a ReedL to e .... ... I ilfla e un de the,4"n ,

thnat appl b1 Surveillanco9 Woro perform~ed with the roactor at power. The 18 month frequencY or, acceptable based OR operating experience and the paGEiVo nature of the afir accumu~lator operation4.

REFERENCES

1. FSAR, Section 6.5.2. ASME, Boiler and Pressure Vessel Code, Section XI.Farley Units 1 and 2 B 3.7.5-10 Revision 12 CST B 3.7.6 BASES SURVEILLANCE REQUIREMENTS SR 3.7.6.1 This SR verifies that the CST contains the required volume of cooling tho need for operator awareness Of unit evolutionsG that may affect the CST- ieo bhecks. Also, tho 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is nidered adequate in view of other indicatios i om, inc~luding alarms, to alert the operator to abnormnal deviations in the CST level.REFERENCES

1. FSAR, Section 9.2.6.2. FSAR, Chapter 6.3. FSAR, Chapter 15.4. AFW-FSDA-181010.

5. CALC. BM 95-0961-001, Rev. 1, Verification of CST Sizing Basis.Farley Units 1 and 2 B 3.7.6-4 Revision 12 CCW System B 3.7.7 BASES SURVEILLANCE SR 3.7.7.1 REQUIREMENTS This SR is modified by a Note indicating that the isolation of the CCW flow to individual components may render those components inoperable but does not affect the OPERABILITY of the CCW System.The Note is applicable to CCW loads and does not include components required for CCW OPERABILITY.

Verifying the correct alignment for accessible manual, power operated, and automatic valves in the CCW flow path provides assurance that the proper flow paths exist for CCW operation.

The accessibility of the CCW valves is evaluated on a case by case basis considering such things as ALARA concerns and personnel safety as well as valve enclosures or barricades blocking access to the valves.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 S Insert 2 being mispositioned are in the correct position.SR 3.7.7.2 This SR verifies proper automal operation of the CCW valves on an actual or simulated Safety Injection uation signal. The CCW System is a normally operating system t cannot be fully actuated as part of routine testing during normal operati. This Surveillance is not required for valves that are locked, sealed, or erwise secured in the required position under administrative controls.FrFequency is based On the Rced to pe~ferm this Su~velllaRco udo the conditions that apply during a unit outage and the potential for an unplaRnod transient if the u~ilne were pAe4rMMAd-wi.fth theat power. Operating experience has shown that those comnponentS usually pass the SurveillaRco when p8eFRmed at the 18 month FrFequ1ency.

Therefore, the FrFequency is acceptable from a reliability standpoint.(continued)

Farley Units 1 and 2 B 3.7.7-4 Revision 9 CCW System B 3.7.7 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.7.7.3 This SR verifies proper automatic operation of the CCW pumps on an actual or simulated actuation signal. The CCW System is a normally operating system that cannot be fully actuated as part of routine testing during normal 19 month Frouonc;Y is basod An thp n@PL4 --eileffn thiG SurveillaRGe URdeF the GGRditiGRG that I nsert 2 -n-g a WRit outage aRd the peteRtial feF an URpWRRed tr-ansient of the R-w-P.ge-illaRGe weFe peFfepmed with the F9aGtqF at peweF.OpWati -.a has ShOWR that theSe GGFRPGRents usually pass the Sw ,ý-"PIRAP WhPR peFfEwpAed at the 19 FAGRth FFeqUeRGýL:

ThwefeFe, the FFequ Ptable from a Feliability standpOiRt.

REFERENCES

1. FSAR, Section 9.2.2.Farley Units 1 and 2 B 3.7.7-5 Revision 19 SWS B 3.7.8 BASES ACTIONS C.1 and C.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 3.7.8.1 REQUIREMENTS This SR is modified by a Note indicating that the isolation of the SWS components or systems may render those components inoperable, but does not affect the OPERABILITY of the SWS. The Note is applicable to SWS loads and does not include components required for SWS OPERABILITY.

Verifying the correct alignment for accessible manual, power operated, and automatic valves in the SWS flow path provides assurance that the proper flow paths exist for SWS operation.

The accessibility of the SWS valves is evaluated on a case by case basis considering such things as ALARA concerns and personnel safety as well as valve enclosures or barricades blocking access to the valves.This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since they are verified to be in the correct position prior to being locked, sealed, or secured. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being mispositioned are in the correct position.

This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves.Insert 2 ueRsU corr~ect 'av-p!' e sWtGcn .S7-=S3.7.8.2 This S erifies proper automatic operation of the SWS valves on an actual or si ulated Safety Injection actuation signal. The SWS is a normally oper ng system that cannot be fully actuated as part of normal testing. s Surveillance is not required for valves that are locked, sealed, or ot rwise secured in the required position under administrative controls.Thc 18 month Fr'-y 0s based on thc Reed to perform thiS Surveillance undor the conditions that apply (continued)

Farley Units 1 and 2 B 3.7.8-4 Revision 19 SwS B 3.7.8 BASES SURVEILLANCE REQUIREMENTS SR. 3.7.8.2 (continued) during a unit outage and the potential for an unplanned transient if the Surveillance wore performned with the reactorF at power. Operating...peri.en has sho..W that theSe cnomponents usually pass the SRwhe performed at the 18 month F7equency.

Therefore, the FrFequiency is acceptable from a reliability standpoint.

S R 3.7.8.3 This SR verifies proper automatic operation of the SWS pumps on an actual or simulated actuation signal. The SWS is a normally operating system that cannot be fully actuated as part of normal testing during normal operationnP-The 18 Fr-euencY

,; based on the need to Insert 2 performn thin r'il;c unRd-er the conditions that apply during a uni~t shown thttee comFponents usually pass the Surveillance when SR 3.7.8.44 This SR requires isual inspection be made of the ground area immediately surroun the SWS buried piping. The performance of a visual inspection of the ound provides an indication of SWS piping integrity (leak tightness) by nitoring the surrounding ground for excessive moisture or erosion."'

h e8 MOnth Fee a s acceptable based On operating experience and the passive nature oef REFERENCES

1. FSAR, Section 9.2.1.2. FSAR, Section 6.2.3. FSAR, Section 5.1.Farley Units 1 and 2 B 3.7.8-5 Revision 9 UHS B 3.7.9 BASES LCO The UHS is required to be OPERABLE and is considered OPERABLE if it contains a sufficient volume of water at or below the maximum temperature that would allow the SWS to operate for at least 30 days following the design basis LOCA without the loss of net positive suction head (NPSH), and without exceeding the maximum design temperature of the equipment served by the SWS. To meet this condition, the UHS temperature should not exceed 95°F and the level should not fall below 184 ft mean sea level during normal unit operation.

APPLICABILITY In MODES 1, 2, 3, and 4, the UHS is required to support the OPERABILITY of the equipment serviced by the UHS and required to be OPERABLE in these MODES.In MODE 5 or 6, the OPERABILITY requirements of the UHS are determined by the systems it supports.ACTIONS A.1 and A.2 If the UHS water level or temperature are not within the required limits, 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 4 within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months and in MODE 5 within 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months .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 3.7.9.1 This SR verifies that adequate long term (30 day) cooling can be maintained.

The specified level also ensures that sufficient NPSH is available to operate the SWS The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Freguenc,'is Insert 2 .....variatn, duing tho applica9b, MODES. This SR verifies that the UHS water level is _ 184 ft mean sea level.(continued)

Farley Units 1 and 2 B 3.7.9-2 Revision 19 UHS B 3.7.9 BASES SURVEILLANCE REQUIREMENTS SR 3.7.9.2 (continued)

This SR verifies that the SWS is available to cool the CCW System to at least its maximum design temperature with the maximum accident or normal design heat loads for 30 days following a Design Basis Insert2 21 h F.. unc ...'od-on operatingoxporionco I FeateGd tO 48RC.nIOR9r of #I.,,- n'rnrnptpr vnria~tiRSn EIUFR trn he. nnnpin.akl I MODES. This SR verifies that the water temperature at the discharge of the Service Water Pumps is _< 950F.REFERENCES

1. FSAR, Section 9.2.5.2. Regulatory Guide 1.27.Farley Units 1 and 2 B 3.7.9-3 Revision 19 Control Room B 3.7.10 BASES SURVEILLANCE SR 3.7.10.1 REQUIREMENTS Standby systems should be checked periodically to ensure that they function properly.

As the environment and normal operating conditions on this system are not severe, testing each train (CREFS and Pressurization) once every month provides an adequate check of this system. The CREFS trains are initiated from the control room with flow through the HEPA and charcoal filters. Systems must be operated for >_ 15 minutes to demonstrate the function of the system (Ref. 3). Systems with heaters must be operated with the heters-ener aized ..Th e 21 d ~av Fr eeer.visp n b~aqpd An th e! b!t S R 3.7.10.22 ThisSRveiies

/ hat the required CREFS testing is performed in accordance wit the Ventilation Filter Testing Program (VFTP). The CREFS filter t sts are in accordance with ASME N510-1989 (Ref. 4).The VFTP inc udes testing the performance of the HEPA filter, charcoal ads rber efficiency, flow rate, and the physical properties of the activate charcoal.

Specific test Frequencies and additional information re discussed in detail in the VFTP.S R 3.7.1 .3 v Insert 2 This SR verifies tha ea tarts and operates on an actual or simulated Safety Injection (SI) actuation si The co -it8ot With the typical idustry refue!ing cycle. This SR is modified by a note which provides an exception to the requirement to meet this SR in MODES 5 and 6. This is acceptable since the automatic Sl actuation function is not required in these MODES.SR 3.7.10.4 This SR verifies that the CRE Ap can be maintained within limits defined in the Control Room Integrity Program (CRIP) with one CREFS train in operation.

If the requirements of this SR cannot be met, a determination must be made as to the cause of the failure.Once identified, the appropriate Condition (for either the CREFS or the CRE) must be entered. For example, if the failure is due to a breach in the integrity of the CRE, the Condition for an inoperable (continued)

Farley Units 1 and 2 B 3.7.10-7 Revision R CRACS B 3.7.11 BASES SURVEILLANCE REQUIREMENTS Insert 2 SR 3.7.11.1 This SR verifies that the heat removal capability of the system is sufficient to remove the heat load assumed in the safety analyses in the control room. This SR of §e t-. The 189 mnith Frequency is .ppropriate Since significant dogradation of tho CRAGS i s slow and is not expected over this time period REFERENCES

1. FSAR, Section 6.4.Farley Units 1 and 2 B 3.7.11-4 Revision 9 PRF B 3.7.12 BASES ACTIONS E.1 (continued)

When two trains of the PRF System are inoperable during movement of irradiated fuel assemblies in the spent fuel pool room, action must be taken to place the unit in a condition in which the LCO does not apply. Action must be taken immediately to suspend movement of irradiated fuel assemblies in the spent fuel pool room. This does not preclude the movement of fuel to a safe position.SURVEILLANCE SR 3.7.12.1 REQUIREMENTS During movement of irradiated fuel in the spent fuel pool room, the two PRF trains are required to be aligned to the spent fuel pool room.When moving irradiated fuel, periodic verification of the PRF system alignment is required.

During movement of irradiated fuel the potential exists for a fuel handling accident.

Verification of the PRF train alignment when moving irradiated fuel provides assurance the Insert 2 rect system alignment is maintained to support the assumptions of the fu ndling accident analysis regarding the OPERABILITY of the PRF System",I The 24 h -r FrAnuJn,-

pecified f4r thcs v,-nfiertann

c adequate to confirm the PRF System alignment and has been shown to- bhe acc...ptable by operating eXpe.Rince.

This surveillance is modified by a note which clarifies that the surveillance need only be performed during the movement of irradiated fuel in the spent fuel pool room.SR 3.7.12.2 Standby systems should be checked periodically to ensure that they function properly.

As the environmental and normal operating conditions on this system are not severe, testing each train once every month provides an adequate check on this system. This Surveillance requires that the operation of the PRF System be verified in the applicable alignment (post LOCA and/or refueling accident).

The surveillance is applied separately to each operating mode of the PRF System as required by plant conditions.

In MODE 1-4, operational testing in the post LOCA alignment is required to verify the capability of the system to perform in this capacity.

Operational testing of the PRF System in the refueling accident alignment is only required to be performed to support the movement of irradiated fuel in the spent fuel pool storage room (when the potential exists for a fuel handling accident).(continued)

Farley Units 1 and 2 B 3.7.12-5 Revision P PRF B 3.7.12 BASES SURVEILLANCE SR 3.7.12.2 (continued)

REQUIREMENTS Systems that do not credit the operation of heaters need only be operated for _> 15 minutes to demonstrate the function of the system.The system is initiated from the control room with flow through the HEPA and charcoal filters.SR 3.7.12.3/This SR verifies at the required PRF System testing is performed in accordance w the Ventilation Filter Testing Program (VFTP). The PRF Syste ilter tests are in accordance with ASME N510-1989 (Ref. 6). T e VFTP includes testing HEPA filter performance, charcoal dsorber efficiency, system flow rate, and the physical prope es of the activated charcoal (general use and following spec /ic operations).

Specific test frequencies and additional inf mation are discussed in detail in the VFTP.R3.7.12.4 This SR verifies that each PRF train starts and operates on an actual or simulated Phase B actuation signal. In addition, the normal spent S Insert 2 fuel pool ventilation system must be verified to isolate on an actual or simulated spent fuel pool ventilation low differential pressure signal nd on an actual or simulated spent fuel pool high radiation signal.SR 3.7.12.5 This SR verifies the integrity of the ECCS pump rooms and penetration area boundary.

The ability of the boundary to maintain negative pressure with respect to potentially uncontaminated adjacent areas is periodically tested to verify proper function of the PRF System. During the post-LOCA mode of operation, the PRF System is designed to maintain a slight negative pressure in the ECCS pump rooms and penetration area boundary, to prevent unfiltered LEAKAGE. The PRF System is designed to maintain _ -0.125 inches water gauge with respect to adjacent area pressure (as measured by the AP between the PRF mechanical equipment room and the RHR Heat Exchanger Room) at a flow rate of < 5,500 cfm.Gcncctont i';Wth Roforonoe 7.(continued)

Farley Units 1 and 2 B 3.7.12-6 Revision P PRF B 3.7.12 BASES SURVEILLANCE SR 3.7.12.6 REQUIREMENTS (continued)

During the fuel handling mode of operation, the PRF is designed to maintain a slightly negative pressure in the spent fuel pool room with respect to atmospheric pressure and surrounding areas at a flow rate of <5 5,500 cfm, to prevent unfiltered leakage. The slightly negative is verified by using a non-rigorous method that yields some obse identification of the slightly negative pressure.

Examples of non-rigorou pthods are smoke sticks, hand held differential pressure indicators, o er measurement devices that do not provide for an absolute measurement",-t REFERENCES

1. FSAR, Section 6.2.3.2. FSAR, Section 9.4.2.3. FSAR, Sections 15.4.1 and 15.4.5.4. Regulatory Guide 1.25.5. 10CFR100.6. ASME N510-1989.

1= _-7 ewI at9F-Y-, ,I, unde !r. 13 , 2 Farley Units 1 and 2 B 3.7.12-7 Revision P I Fuel Storage Pool Water Level B 3.7.13 BASES LCO The fuel storage pool water level is required to be > 23 ft over the top of irradiated fuel assemblies seated in the storage racks. The specified water level preserves the assumptions of the fuel handling accident analysis (Ref. 3). As such, it is the minimum required for fuel storage and movement within the fuel storage pool.APPLICABILITY This LCO applies during movement of irradiated fuel assemblies in the fuel storage pool, since the potential for a release of fission products exists.ACTIONS A.1 Required Action A.1 is modified by a Note indicating that LCO 3.0.3 does not apply.When the initial conditions for prevention of an accident cannot be met, steps should be taken to preclude the accident from occurring.

When the fuel storage pool water level is lower than the required level, the movement of irradiated fuel assemblies in the fuel storage pool is immediately suspended to a safe position.

This action effectively precludes the occurrence of a fuel handling accident.

This does not preclude movement of a fuel assembly to a safe position.If moving irradiated fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not specify any action. If moving irradiated fuel assemblies while in MODES 1, 2, 3, and 4, the fuel movement is independent of reactor operations.

Therefore, inability to suspend movement of irradiated fuel assemblies is not sufficient reason to require a reactor shutdown.SURVEILLANCE REQUIREMENTS SR 3.7.13.1 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 period1ia4Tho 7 day- Freuoncy is Farley Units 1 and 2 B 3.7.13-2 Revision 12 Fuel Storage Pool Water Level B 3.7.13 BASES SURVEILLANCE SR 3.7.13.1 (continued)

REQUIREMENTS During refueling operations, the level in the fuel storage pool is in equilibrium with the refueling canal, and the level in the refueling canal is checked P in accordance with SR 3.9.6.1 (refueling cavity water level verification).

REFERENCES

1. FSAR, Section 9.1.2.2. FSAR, Section 9.1.3.3. FSAR, Section 15.4.5.4. Regulatory Guide 1.25, Rev. 0.5. 10 CFR 100.11.Farley Units 1 and 2 B 3.7.13-3 Revision 9 Fuel Storage Pool Boron Concentration B 3.7.14 BASES ACTIONS A.1 and A.2 (continued)

If the LCO is not met while moving irradiated fuel assemblies in MODE 5 or 6, LCO 3.0.3 would not be applicable.

If moving irradiated 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 3.7.14.1 This SR verifies that the concentration of boron in the fuel storage pool is within the required limit. As long as this SR is met, the analyzed accidents are fully ahe- 7 day FrFequeRGy -s Insert 2 , xpo.... to. take plco o.er 6uch a chort poriod of tim.'I REFERENCES

1. USNRC Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants, LWR Edition, NUREG-0800, June, 1987.2. USNRC Spent Fuel Storage Facility Design Bases (for Comment)Proposed Revision 2, 1981.3. ANS, "Design Requirements for Light Water Reactor Spent Fuel Storage Facilities at Nuclear Power Stations," ANSI/ANS-57.2-1983.4. WCAP-14416-NP-A, Rev. 1, "Westinghouse Spent Fuel Rack Criticality Analysis Methodology," November, 1996.5. FSAR, Section 4.3.2.7.2.

6. NRC, Letter to all Power Reactor Licensees from B.K. Grimes,"OT Position for Review and Acceptance of Spent Fuel Storage and Handling Applications," April 14, 1978.7. "Farley Units 1 and 2 Spent Fuel Rack Criticality Analysis Using Soluble Boron Credit," CAA-97-138, Rev. 1.Farley Units 1 and 2 B 3.7.14-4 Revision H Secondary Specific Activity 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 the secondary specific activity cannot be restored to within limits 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . 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 verifies that the secondary specific activity in the steam generators is within the limits of the accident analysis.

A gamma isotopic analysis of the secondary coolant, which determines DOSE S Insert 2 r E'UiVA-LrE1nFI c~frms the validity of the safety analysis assumptions as to the sou in post accident releases.

It also serves to identify and trend any unusual is etrtions that might indicate changes in reactor coolant activity or LEA 31 day FroequencGy is bared on the dotoction o~f inro~asing trendS of the level of DOSE EQUIVALENT 1 131, and allows fr -apprpriFate action to be taken to maintain levels below the LCO limit.REFERENCES

1. 10CFR100.11.

2. FSAR, Chapter 15.Farley Units 1 and 2 B 3.7.16-3 Revision 12 Cask Storage Area Boron Concentration Cask Loading Operations B 3.7.17 BASES APPLICABILITY This LCO applies whenever any fuel assembly .is stored in the cask storage area of the spent fuel pool.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 fuel storage pool (including the transfer canal and cask storage area) is less than required, immediate action must be taken to preclude the occurrence of an accident or to mitigate the consequences of an accident in progress.This is most efficiently achieved by immediately suspending the movement of fuel assemblies.

Action is also initiated to restore the concentration of boron simultaneously with suspending movement of fuel assemblies.

If the LCO is not met while moving irradiated fuel assemblies in MODE 5 or 6, LCO 3.0.3 would not be applicable.

If moving irradiated 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 I Insert 2 SR 3.7.17.1 The boron concentration in the spent fuel cask storage area water must be verified to be within limit within four hours prior to entering the Applicability of the LCO. For loading operations, this means within four hours of loading the first fuel assembly into the cask.For unloading operations, this means verifying the concentration of the borated water source to be used to re-flood the spent fuel cask within four hours of commencing re-flooding operations.

This ensures that when the LCO is applicable (upon introducing water into the spent fuel cask), the LCO will be met.Is--k- f-epeFat fW91 Ga ions contin'ue for 418 hours0.00484 days 0.116 hours 6.911376e-4 weeks 1.59049e-4 months or moro and coRt-n'.'o until the spent sk is removed from the cask storago area.When both the transfer canal gate and the cask storage area gate are open, the boron concentration measurement may be performed by sampling in accordance with SR 3.7.14.1.

When at least one gate is closed, the sample is to be taken in the cask storage area.Farley Units 1 and 2 B 3.7.17-4 Revision 14 ESF Room Coolers B 3.7.19 BASES ACTIONS (continued)

A.1 If one train of a required ESF Room Cooler subsystem is inoperable, action must be taken to restore the subsystem train to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . In this Condition, the remaining OPERABLE ESF Room Cooler subsystem train is adequate to perform the heat removal function for its associated ESF equipment.

B.1 and B.2 If the ESF Room Cooler subsystem train cannot be restored to OPERABLE status within the associated Completion Time or two trains of the same ESF Room Cooler subsystem are inoperable, 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . 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 3.7.19.1 REQUIREMENTS Verifying the correct alignment for manual valves servicing safety-related equipment provides assurance that the proper flow paths exist for ESF Room Cooler operation.

This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since they are verified to be in the correct position prior to being locked, sealed, or secured. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being mispositioned are in the correct position.

This SR does not apply to valves that cannot be inadvertently misaligned, Insert 2 such as check valves.co.nciront With the procedural corolo goVerning valpo operation, and- oncuroFS correct valvo positione.(continued)

Farley Units 1 and 2 B 3.7.19-5 Revision Pq ESF Room Coolers B 3.7.19 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.7.19.2 This SR verifies proper operation of the ESF Room Cooler fans on an actual or simulated actuation signal. Depending on the room cooler, this may be manual, high room temperature, an equipment running Each Room Cooler Fan can be placed in Run mode locally. With the Room Cooler in the Run mode, all automatic functions are being met and the Room Cooler is considered OPERABLE.REFERENCES

1. FSAR, Section 9.4.Farley Units 1 and 2 B 3.7.19-6 Revision P AC Sources--

Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.1 (continued)

REQUIREMENTS appropriate independence of offsite circuits is maintain[ Insert 2 ! v ... ...SR 3.8.1.2 and SR 3.8.1.6 These SRs help to ensure the availability of the standby electrical power supply to mitigate DBAs and transients and to maintain the unit in a safe shutdown condition.

To minimize the wear on moving parts that do not get lubricated when the engine is not running, these SRs are modified by a Note (Note 2 for SR 3.8.1.2) to indicate that all DG starts for these Surveillances may be preceded by an engine prelube period and followed by a warmup period prior to loading.For the purposes of SR 3.8.1.2 and SR 3.8.1.6 testing, the DGs are started from standby conditions.

Standby conditions for a DG mean that the diesel engine coolant and oil are being continuously circulated and temperature is being maintained consistent with manufacturer recommendations.

In order to reduce stress and wear on diesel engines, some manufacturers recommend a modified start in which the starting speed of DGs is limited, warmup is limited to this lower speed, and the DGs are gradually accelerated to synchronous speed prior to loading.These start procedures are the intent of Note 3, which is only applicable when such modified start procedures are recommended by the manufacturer.

During a modified start, a DG will not respond to a ESF or LOSP signal automatically.

Therefore, the DG is considered inoperable with respect to response to ESF or LOSP signals during the brief duration of modified starts. If necessary, Operator action is required to place the speed control in automatic and reset the excitation system. This will immediately allow the DG to achieve normal voltage and frequency.

The DG shall be verified to accelerate to at least a synchronous speed of 900 rpm for the 2850 kW generator and 514 rpm for the 4075 kW generators.(continued)

Farley Units 1 and 2 B 3.8.1-17 Revision 12 AC Sources-Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.2 and SR 3.8.1.6 (continued)

REQUIREMENTS SR 3.8.1.6 requires thad, 51 9 1 E the DG starts from standby conditions and achieves required voltage and frequency within 12 seconds. The permissive for closing the generator output breaker requires frequency to be greater than 57 Hz and voltage greater than 3952 V. The 12 second start requirement supports the assumptions of the design basis LOCA analysis in the FSAR, Chapter 15 (Ref. 5).The 12 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, the 12 second start requirement of SR 3.8.1.6 applies.Since SR 3.8.1.6 requires a 12 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 S Insert 2 intent of Note 1 of SR 3.8.1.2.The norm-al 31 day FrFequency for SR 3.8.1.2 iG consistent with RegulatoI' Guide 1.108 (Ref. 9). The 184' day Frequerny for SR 3.8.1.6 i s a reduction in cold testing consistent with Generic Letter 84 15 (Ref. 7). These FrFequece poide adequate assurance o G OPERABILITY, while- miiizn d adation resultfing fromte#in%

SR 3.8.1.3 This Surveillance verifies that the DGs are capable of synchronizing with the offsite electrical system and accepting loads in a range comparable to the maximum expected accident loads. A minimum run time of 60 minutes is required to stabilize engine temperatures, while minimizing the time that the DG is connected to the offsite source.Although no power factor requirements are established by this SR, the DG is normally operated at a power factor between 0.8 lagging and 1.0. The 0.8 value is the design rating of the machine, while the 1.0 is an operational limitation to ensure circulating currents are minimized.

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.(continued)

Farley Units 1 and 2 B 3.8.1-18 Revision 9 AC Sources--

Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.3 (continued)

REQUIREMENTS his 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 per unit at a time in order to avoid common cause failures that might result from offsite circuit or grid perturbations.

Note 3 is intended to be applied on a per unit basis and is not intended to preclude testing DGs on different units at the same time. Note 4 stipulates a prerequisite requirement for performance of this SR. A successful DG start must precede this test to credit satisfactory performance.

SR 3.8.1.4 This SR provides verification that the level of fuel oil in the day tank is at or above a level which ensures sufficient time for manual transfer of fuel oil from the DG storage tank if the automatic transfer fails. The level is expressed as an equivalent volume in gallons, and ensures adequate fuel oil for a minimum of 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months of DG operation at the S Insert 2 continuous rating.of fuel oil is available, Since low level alarm. are provided and faciti operators would be aware of anY large uses of fuel oil duringthis SR 3.8.1.5 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 fuel transfer systems are OPERABLE.(continued)

Farley Units 1 and 2 B 3.8.1-19 Revision 12 AC Sources--

Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.5 (continued)

REQUIREMENTS The design of fuel transfer systems is such that pumps operate automatically or must be started manually in order to maintain an adequate volume of fuel oil in the day tanks during or following DG testing. h g --se, a 31 day Fr .... -.. ..:e SR .8.1.6 eSR 3.8.1.2.Insert 2 SR 3.8.1.7 Transfer of the unit power supply from the normal offsite circuit to the alternate offsite circuit demonstrates the OPERABILITY of the Pitp.rontp.

nit.jit di.-trhihfloin nptwork to pnwpr th. s,butdinwn The 18 mon ifthFequy of NoteThe Of reanf e is thebased on egnring udgmert, taking into e rtosideration the urit conditiohs Required to pertfrm the Surveillare, and ist inteded to be consistent Withl expected fuel cycle iengths. Operating experience has shown that these Gomproents usually pans the SR wher peeriomed at the 18 month Frequeney.

ThReefre, the FraequenY waS concluded to be acceptable from a reliability standpoint.

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.SR 3.8.1.Each DG is provided with an engine overspeed trip to prevent damage to the engine. Recovery from the transient caused by the loss of a large load could cause diesel engine overspeed, which, if excessive, might result in a trip of the engine. This Surveillance demonstrates the DG load response characteristics and capability to reject the largest single load without exceeding predetermined voltage and while maintaining a specified margin to the overspeed trip. The single load for each DG is approximately 1000 kW. This Surveillance may be accomplished by: (continued)

Farley Units 1 and 2 B 3.8.1-20 Revision 12 AC Sources--

Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.8 (continued)

REQUIREMENTS

a. Tripping the DG output breaker with the DG carrying greater than or equal to its associated single largest post-accident load while paralleled to offsite power, or while solely supplying the bus; or b. Tripping its associated single largest post-accident load with the DG solely supplying the bus.As required by Regulatory Guide 1.9 (Ref. 3), the load rejection test is acceptable if the increase in diesel speed does not exceed 75% of the difference between synchronous speed and the overspeed trip setpoint.The voltage tolerance specified in this SR is derived from Regulatory Guide 1.9 (Ref. 3) recommendations for response during load sequence interval.

The voltage specified is consistent with the design range of the equipment powered by the DG. SR 3.8.1.8.b is the Iner vle'to whyichte smte'u~str state voltage vsstem recoverfollowing"load rejec-iO.

I ,h ossetwt h'SR 3.8.1.9 As required by Regulatory Guide 1.108 (Ref. 9), paragraph 2.a.(1), this Surveillance demonstrates the as designed operation of the standby power sources during loss of the offsite source. This test verifies all actions encountered from the loss of offsite power, including shedding of the 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 autostart time of 12 seconds is derived from requirements of the accident analysis to respond to a design basis large break LOCA.The Surveillance should be continued for a minimum of 5 minutes in order to demonstrate that all starting transients have decayed and stability is achieved.The requirement to verify the connection and power supply of permanent and autoconnected loads is intended to satisfactorily show the relationship of these loads to the DG loading logic. In certain circumstances, many of these loads cannot actually be connected or loaded without undue hardship or potential for undesired operation.(continued)

Farley Units 1 and 2 B 3.8.1-21 Revision 9 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.9 (continued)

REQUIREMENTS For instance, Emergency Core Cooling Systems (ECCS) injection valves are not desired to be stroked open, or high pressure injection systems are not capable of being operated at full flow, or residual heat removal (RHR) systems performing a decay heat removal function are not desired to be realigned to the ECCS mode of operation.

In lieu of actual demonstration of connection and loading of loads, testing that adequately shows the capability of the DG systems to perform these functions is acceptable.

This testing may include any series of sequential, overlapping, or total steps so that the S Insert 2 entire connection and loading sequence is verified.l e ,,Rgulte,, Guide 1,108m, 9) ,, 2.a.1), ta ,,ke ,s into This SR is modified by two Notes. The reason for Note 1 is to minimize wear and tear on the DGs during testing. For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine coolant and oil continuously circulated and temperature maintained consistent with manufacturer recommendations.

The reason for Note 2 is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems.SR 3.8.1.10 This Surveillance demonstrates that the DG automatically starts and achieves the required voltage and frequency within the specified time (12 seconds) from the design basis actuation signal (LOCA signal)and operates for > 5 minutes. The 5 minute period provides sufficient time to demonstrate stability.

SR 3.8.1.10.d and SR 3.8.1.10.e ensure that permanently connected loads and emergency loads are energized from the offsite electrical power system on an ESF signal without loss of offsite power. Emergency loads are started simultaneously by logic in the load sequencers sensing the availability of offsite power.(continued)

Farley Units 1 and 2 B 3.8.1-22 Revision 12 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.10 (continued)

REQUIREMENTS The requirement to verify the connection of permanent and autoconnected loads is intended to satisfactorily show the relationship of these loads to the DG loading logic. In certain circumstances, many of these loads cannot actually be connected or loaded without undue hardship or potential for undesired operation.

For instance, ECCS injection valves are not desired to be stroked open, or high pressure injection systems are not capable of being operated at full flow, or RHR systems performing a decay heat removal function are not desired to be realigned to the ECCS mode of operation.

In lieu of actual demonstration of 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 I Insert 2 and loading sequence is verified....... '.-FeqWRy Of 1 S nenths takes i,-tG GGensderatien

'-,",t GOnditions FeWithd the GFF exe ted fuel 1WG cycl legt s Oprating experience hase shown that these components usually pass the SR when performed at the 18 mon~th FrFequencGy.

T-herefore, the FrFequency war, concluded to be acceptable fromn a reliability standpoint.

This SR is modified by two Notes. The reason for the first Note 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.

The reason for the second Note (which only applies to SR 3.8.1.10.d and e) is that during operation with the reactor critical, performance of SR 3.8.1.10.d and e could cause perturbations to the electrical distribution systems that could challenge continued steady state operation and, as a result, unit safety systems.SR 3.8.1.11 This Surveillance demonstrates that DG noncritical protective functions (e.g., high jacket water temperature) are bypassed on a loss of voltage signal and/or an ESF actuation test signal, i.e., are bypassed during accident conditions.(continued)

Farley Units 1 and 2 B 3.8.1-23 Revision P AC Sources--

Operating B 3.8.1 BASES SURVEILLLANCE REQUIREMENTS SR 3.8.1.11 (continued)

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.performed at the 18 moenth FrFequency.

Therefore, the FrFequency was concluded to be acceptable from a reliability sta-ndrpint SR 3.8.1.12 I Insert 2=This surveillance requires demonstration once per 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 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , >_ 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of which is at a load equivalent to the 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months load rating and the remainder of the time at a load equivalent to the continuous duty rating of the DG. The DG starts for this Surveillance can be performed either from standby or hot conditions.

The provisions for 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.The steady-state generator voltage and frequency shall be maintained between 4160 t 420 volts and 60 +/- 1.2 Hz during this test..--1--.,-,,---.-.

with...............,-'.-s-.A)Feglaor, Guide 1. 108 (Ref. 9), paragraph 2.a.(3), takes into consi6deration unit conditions required to perform the Survýeillance, and is intended to be consistent with expected fuel cycle lengths.This Surveillance is modified by a Note. The Note states that momentary transients due to changing bus loads do not invalidate this test.(continued)

Farley Units 1 and 2 B 3.8.1-24 Revision PA AC Sources -Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1.13 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 12 seconds. The 12 second time is derived from the requirements of the accident analysis to respond to a design basis large break LOCA..m4 th Irpnu.eRGS

.wh

the FeGOF.,mnRdatpe.

tvf his SR is modified by two Notes. Note 1 ensures that the test is erformed with the diesel sufficiently hot. The requirement that the diesel has operated for at least 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months at full load conditions prior to performance of this Surveillance is consistent with the manufacturer recommendations for achieving hot conditions.

Momentary transients due to changing bus loads do not invalidate this test. Note 2 allows all DG starts to be preceded by an engine prelube period to minimize wear and tear on the diesel during testing.SR 3.8.1.14 As required by Regulatory Guide 1.108 (Ref. 9), paragraph 2.a.(6), this Surveillance ensures that the manual synchronization and automatic load transfer from the DG to the offsite source can be made and the DG can be returned to ready to load status when offsite power is restored.

It also ensures that the autostart logic is reset to allow the DG to reload if a subsequent loss of offsite power occurs.The DG is considered to be in ready to load status when the DG is at rated speed and voltage, the output breaker is open and can receive an autoclose signal on bus undervoltage, and the load sequence Insr timers are reset.Insert2mntr 6 OGstn it h FGMe~ain 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.(continued)

Farley Units 1 and 2 B 3.8.1-25 Revision 9 AC Sources-Operating B 3.8.1 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1.15 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 is received during operation in the test mode. Ready to load operation is defined as the DG running at rated speed and voltage with the DG output breaker open.This testing may include any series of sequential, overlapping, or total steps so that the entire connection and loading sequence is verified.R 3.8.1.16 Under accident 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 10%(or 0.5 seconds, whichever is greater) load sequence time interval 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.

Reference 2 provides a summary of the automatic loading of Insert 2 ESF buses.* "o e~e .'.,. be. GOsst. ... o.+With expected fue l ... ,.,.gnths.

SR 3.8.1.17 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 3.8.1.9, 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 (continued)

Farley Units 1 and 2 B 3.8.1-26 Revision 19 AC Sources--

Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.17 (continued)

REQUIREMENTS 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 Insert 2 and loading sequence is verified.The Of 18 months takes into consideration unt conditins requirod to perfoFrm the gurvoillanco and iS intended to be consistent with an expected fuel cycle length Of 18 monthS-.This SR is modified by two Notes. The reason for Note 1 is to minimize wear and tear on the DGs during testing. For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine coolant and oil continuously circulated and temperature maintained consistent with manufacturer recommendations for DGs. The reason for Note 2 is that the performance of the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems.SR 3.8.1.18 This Surveillance demonstrates the DG capability to reject a load of 1200-2400 kW without overspeed tripping or exceeding the predetermined voltage limits. The DG load rejection may occur because of a system fault or inadvertent breaker tripping.

This Surveillance ensures proper engine generator load response under the simulated test conditions.

This test simulates the loss of the total connected load that the DG experiences following a 1200-2400 kW load rejection and verifies that the DG does not trip upon loss of the load. These acceptance criteria provide for DG damage protection.

While the DG is not expected to experience this transient during an event and continues to be available, this response ensures that the DG is not degraded for future application, including reconnection to the bus if the trip initiator can be corrected or isolated.

The DG output breaker(s) must remain closed such that the DG is connected to at least one ESF bus. All fuses and breakers on the energized ESF bus(es) must be verified not to trip.This surveillance is modified by a note which states that testing of the shared Emergency Diesel Generator (EDG) set (EDG 1-2A or EDG 1C) on either unit may be used to satisfy this surveillance requirement (continued)

Farley Units 1 and 2 B 3.8.1-27 Revision 12 AC Sources -Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.18 (continued)

REQUIREMENTS for these EDGs for both units. The surveillance requirement consists of sufficient testing to demonstrate that each DG, the DG output breaker, and bus fuses and breakers can successfully withstand a 1200-2400 kW load rejection on each unit. This does not require, however, that each shared DG be aligned to each unit and a load rejection be performed in a redundant fashion. This surveillance is intended to assure the correct performance of the DG voltage regulators and governors.

accoptablo by oporating oxporience.

Insert 2 SR 3.8.1.19 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 he DGs are started simultaneously.

The !0 Y ear FrFeq'6'eR Gc 06 consiste 1R~t_ w. 1t-hi thc r ec m e dtrs o Regulatory Guide 1.108 (Ref. 9). This surveillance would also be applicable after any modifications which could affect DG interdependence.

This SR is modified by a Note. The reason for the Note is to minimize wear on the DG during testing. For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine coolant and oil continuously circulated and temperature maintained consistent with manufacturer recommendations.

REFERENCES

1. 10 CFR 50, AppendixA, GDC 17.2. FSAR, Chapter 8.3. Regulatory Guide 1.9, Rev. 1, 1971.4. FSAR, Chapter 6.5. FSAR, Chapter 15.(continued)

Farley Units 1 and 2 B 3.8.1-28 Revision 12 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES ACTIONS E.1 (continued) receiver pressure is restored to the required limit. A period of 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months is considered sufficient to complete restoration to the required pressure prior to declaring the DG inoperable.

This period is acceptable based on the remaining air start capacity, the fact that most DG starts are accomplished on the first attempt, and the low probability of an event during this brief period.F. 1 With a Required Action and associated Completion Time not met, or one or more DG's fuel oil, lube oil, or starting air subsystem not within limits for reasons other than addressed by Conditions A through D, the associated DG may be incapable of performing its intended function and must be immediately declared inoperable.

SURVEILLANCE SR 3.8.3.1 REQUIREMENTS This SR provides verification that there is an adequate inventory of useable fuel oil in the shared storage tanks (25,000 gallons each) to support the operation of the required DG(s) for 7 days at full load. The 7 day period is sufficient time to place the unit in a safe shutdown Insert 2 .condition and to bring in replenishment fuel from an offsite location.The 31 day Frequency i6 adequate to that a su-fficient supply of fuel oil is available, Sio low level alar uided aRd unit woeuld- be- areof any largo 6soe offuel Ailduin thiG period-.SR 3.8.3.2 This Surveillance ensures that sufficient lube oil inventory is available to support at least 7 days of full load operation for each DG. The inventory may consist of a combination of lube oil in storage and the useable sump volume above the manufacturer recommended minimum sump level or a total volume of lube oil in storage that is in addition to the lube oil normally maintained in each DG sump. The 238 gal requirement for the 4075 kW DGs and the 167 gal requirement for DG 1C are based on the DG manufacturer consumption values for 7 days of operation at full rated load. Implicit in this SR is the requirement to verify the capability (continued)

Farley Units 1 and 2 B 3.8.3-6 Revision rp Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE SR 3.8.3.2 (continued)

REQUIREMENTS to transfer the lube oil from its storage location to the DG, when the DG lube oil sump does not hold adequate inventory for 7 days of full load operation without the level reaching the manufacturer recommended Insert 2 minimum level.A 31 day F .equency is adequate to e..... that a .ufficient lube o, i supply is oncite, 6inco DG stars and runR timne ar closely monitored by the unit; taff SR 3.8.3.3 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 new fuel oil in accordance with ASTM D4057-06 (Ref. 2)b. Verify in accordance with the tests specified in ASTM D975-07 (Ref.3) 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 when tested in accordance with ASTM D1298-99 (Ref. 6), a kinematic viscosity at 40 0 C of > 1.9 centistokes and < 4.1 centistokes, and a flash point of > 125°F; and c. Verify that the new fuel oil has a clear and bright appearance with proper color when tested in accordance with ASTM D4176-04 (Ref.7) or a water and sediment content within limits when tested in accordance with ASTM D2709-96 (Ref. 8)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)

Farley Units 1 and 2 B 3.8.3-7 Revision P Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE SR 3.8.3.4 (continue REQUIREMENTS redundncy, id divei available in the contro Insert 2 below norm.al air .tart ,.takes into account the capacity, capability, sity of the AC GsourceS and other indications oom, including alarms, to alert the oprator to ro m,8G.....

... ..REFERENCES

1. FSAR, Section 8.3.1.1.7.

2. ASTM-D4057-06.

3. ASTM-D975-07.

4. FSAR, Chapter 6.5. FSAR, Chapter 15.6. ASTM D1298-99.7. ASTM D4176-04.8. ASTM D2709-96.9. ASTM D1552-07.10. ASTM D2622-07.11. ASTM D4294-03.12. ASTM D5452-06.Farley Units 1 and 2 B 3.8.3-9 Revision P DC Sources-Operating B 3.8.4 BASES (continued)

SURVEILLANCE REQUIREMENTS SR 3.8.4.1 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 applying a voltage to the battery to maintain it in a fully charged condition during normal operation.

The float voltage of 2.2 V per cell or 132 V overall is higher than the nominal design voltage of 125 V and is consistent with the manufacturer's recommendations for maintaining a full charge.Verifying that terminal voltage is > 127.8 V provides assurance that average of all cell voltages is maintained greater than 2.13 V.Maintain voltage at the higher value of 2.2 V per cell prolongs ce ifeexpectancy.-h7da FeuRYwG9SsntwH SR 3.8.4.2 Visual inspection to detect excessive corrosion on the battery terminals or connectors, or measurement of the post to post resistance of these items provides an indication of the need for leaning and/or retorqueing.

~1 The Sur,,Poillanco FrFequencY for these inSPections, which can detec-t t.h.÷ ...... ttcan cus powo .losse' "u9 to re.istarnc hoatin, is 92 days. This FrFequec iscnidered acceptable based on operating exeinerelaýted to detecting corrosiontrnd.

SR 3.8.4.3 Visual inspection of the battery cells, cell plates, and battery racks provides an indication of physical damage or abnormal deterioration that could potentially degrade battery performance.

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).

deterioration and has been Shown to be adequate by operating I .69-.(continued)

Farley Units 1 and 2 B 3.8.4-7 Revision P i DC Sources--

Operating B 3.8.4 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.4.4 and SR 3.8.4.5 Visual inspection and post to post resistance measurements of battery terminals or connectors provide an indication of the need for cleaning and/or retorqueing.

The anticorrosion material is used to help ensure good electrical connections and to reduce terminal deterioration.

The visual inspection for corrosion is not intended to require removal of and inspection under each terminal connection.

The removal of visible corrosion is a preventive maintenance SR.The presence of visible corrosion does not necessarily represent a failure of this SR provided visible corrosion is removed during performance of SR 3.8.4.4.The 18 month frg .u.G.Y fOr this SR is +ufficient to dct..t abnormal detorioration and has boon shown to be adequate by opor,,atn This SR requires that each required battery charger be capable of supplying 536 amps (Auxiliary Building chargers) and 3 amps (SWIS chargers) at 125 V for >_ 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . 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.

Thc Survoillanco Frouoc is accctable.

given the unit conditions reuI4UIIU LU eUIII test LL,,LuII OtU e ULFIUFtiv GUIIIUfUW UIRTF91 oxisting to _onsuiro aacdquaic cnargcr porROrmanco aIuFRng tncSc" 'a met inevl n1.,effn ,-.+,ýr

+h=. r'..e a~r ic. insrMr 4~r +^~ hjQ tf %I I I IVI ILl I II ILVI .t.r-.*r~rJ 4.. I ,. ,n I,. Inn n~kc.tMirlo 0 Uri Tr &*out? W, tic ty'VV W orl'a 0.This surveillance is modified by a Note which clarifies that it may be performed in any mode of operation provided certain conditions are met. The design is such that any battery charger may be tested while a spare or redundant battery and/or charger is in service in its place.The spare or redundant battery and/or charger must be within the 18 month surveillance frequency to maintain the DC subsystem(s) to which they are aligned OPERABLE.

This operational flexibility maintains TS OPERABILITY of the applicable battery and DC train while testing the normally aligned charger.(continued)

Farley Units 1 and 2 B 3.8.4-8 Revision ý0 I DC Sources--

Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.7 REQUIREMENTS (continued)

A battery service test is a special test of battery capability, as found, to satisfy the design requirements (design load profile) of the DC electrical power system. The discharge rate and test length should correspond to the design load profile requirements as specified in Insert 2 Reference 4.The Su-r've0llance Frequency of 18 months is consistent with the recomm~endations of Regulatory Guide 1.32 (Ref. 10), which states that the battery so rice test should be perfo)rmod during refuelin operations or at some othor outage, (applicable to Auxiliary Building battorios only) with intervals between tests, not to exceed 18 moenths.This SR is modified by three Notes. Note 1 allows the performance of a performance discharge test in lieu of a service test once per 60 months. Note 2 allows the performance of a modified performance discharge test in lieu of a service test at any time.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, followed by the test rate employed for the performance test, both of which envelop 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. The battery terminal voltage for the modified performance discharge test should remain above the minimum battery terminal voltage specified in the battery service test for the duration of time equal to that of the service 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.The reason for Note 3 is that performing the Surveillance for the Auxiliary Building batteries would perturb the electrical distribution system and challenge safety systems.(continued)

Farley Units 1 and 2 B 3.8.4-9 Revision P I DC Sources--

Operating B 3.8.4 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.4.8 A battery performance discharge test is a test of constant current capacity of a battery, 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.A battery modified performance discharge test is described in the Bases for SR 3.8.4.7. Either the battery performance discharge test or the modified performance discharge test is acceptable for satisfying SR 3.8.4.8. The modified performance discharge test may be used to satisfy SR 3.8.4.8 while simultaneously satisfying the requirements of SR 3.8.4.7 at any time. The performance discharge test may be used to satisfy 3.8.4.8 while simultaneously satisfying the requirements of SR 3.8.4.7 once per 60 months.The acceptance criteria for this Surveillance are consistent with IEEE-450 (Ref. 9). This reference recommends that the battery be replaced if its capacity is below 80% of the manufacturer's rating. A capacity of 80% shows that the battery rate of deterioration is increasing, even if there is ample capacity to meet the load requirements.

I Insert 2 mp~~agII.,mna L ag GFt a tIhic tast ,c Remarn yI. 60~f nAGRth.tI 11 f the battery shows degradation, or if the battery has reached 85% of its expected life or 17 years, whichever comes first, the Surveillance Frequency is reduced to 18 months. Degradation is indicated, according to IEEE-450 (Ref. 9), when the battery capacity drops by more than 10% relative to its capacity on the previous performance test or when it is > 10% below the manufacturer's rating. These I a6afcn+ Wit t thha ra1 ommrnerdatan.s_

.i EEZE ..A.(Ref. 9).This SR is modified by a Note. The reason for the Note is that performing the Surveillance for the Auxiliary Building batteries would perturb the electrical distribution system and challenge safety systems.(continued)

Farley Units 1 and 2 B 3.8.4-10 Revision P I 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 required batteries with one or more battery cell parameters outside the Category C limit for any connected cell, sufficient capacity to supply the maximum expected load requirement is not assured and the corresponding DC electrical power subsystem must be declared inoperable.

Additionally, other potentially extreme conditions, such as not completing the Required Actions of Condition A within the required Completion Time or average electrolyte temperature of representative cells falling below the minimum temperature limit,,or the average cell float voltage < 2.13 volts, which is equivalent to overall battery terminal voltage _< 127.8 volts, 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 the values specified in Table 3.8.6-1. IEEE-450 (Ref. 3) recommends regular battery inspections t leae-sýR including voltage, specific gravity, and electrolyte temperature i ilot sc, SIR The P nsp-tion of specific gravity and voltage is consistent with IEEE-450 (Ref. 3 .In addition, within 7 days of a battery discharge

< 110 V or a battery 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)

Farley Units 1 and 2 B 3.8.6-3 Revision EA Battery Cell Parameters B 3.8.6 BASES SURVEILLANCE SR 3.8.6.2 (continued)

REQUIREMENTS voltage to drop to < 110 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.

Insert 2 S SR 3.8.6.3 This Surv nce verification that the average temperature of 10 connected resentative cells is >_ 60'F for the Auxiliary Building batteries and > 3 for the SWIS batteries, is consistent with a recommendation of 1 -450 (Ref. 3), that states that the.erature of electrol tes representative cells should be 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 design considerations.

Table 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 with the lowest specific gravity and voltage from the previous quarterly surveillance.

The Category A limits specified for electrolyte level are based on manufacturer recommendations and are consistent with the guidance in IEEE-450 (Ref. 3), with the extra 1/4 inch allowance above the high water level indication for operating margin to account for temperatures and charge effects. In addition to this allowance, footnote a to Table 3.8.6-1 permits the electrolyte level to be above the specified maximum level during equalizing charge, provided it is (continued)

Farley Units 1 and 2 B 3.8.6-4 Revision q Battery Cell Parameters B 3.8.6 BASES SURVEILLANCE Table 3.8.6-1 (continued)

REQUIREMENTS The Category B limits specified for electrolyte level and float voltage are the same as those specified for Category A and have been discussed above. The Category B limit specified for specific gravity for each connected cell is _> 1.190 with the average for all connected cells > 1.195. The manufacturers recommended fully charged specific gravity is 1.215 for the Auxiliary Building and 1.210 for the SWIS batteries.

The value of 0.020 below the manufacturers recommended fully charged value for SWIS batteries has been adopted as the Category B minimum for each connected cell for both the Auxiliary Building and SWIS batteries.

The minimum specific gravity value required for each cell ensures that the effects of a highly charged or newly installed cell will not mask overall degradation of the battery.Category C defines the limits for each connected cell. These values, although reduced, provide assurance that sufficient capacity exists to perform the intended function and maintain a margin of safety. When any battery parameter is outside the Category C limits, the assurance of sufficient capacity described above no longer exists, and the battery must be declared inoperable.

The Category C limits specified for electrolyte level (above the top of the plates and not overflowing) ensure that the plates suffer no physical damage and maintain adequate electron transfer capability.

The Category C limits for float voltage are based on operating experience, which has shown that a cell voltage of 2.02 V or below, under float conditions and not caused by elevated temperature of the cell, indicates internal cell problems and may require cell replacement.

The Category C limit of average specific gravity >_ 1.190 is based on operating experience.

In addition to that limit, if a cell is < 1.190, then it shall not have decreased more than 0.080 from the previous test.The footnotes to Table 3.8.6-1 are applicable to Category A, B, and C specific gravity. Footnote (b) to Table 3.8.6-1 requires the above mentioned correction for electrolyte level and temperature, with the exception that level correction is not required when battery charging current is < 2 amps on float charge. This current provides, in general, an indication of overall battery condition.(continued)

Farley Units 1 and 2 B 3.8.6-6 Revision 19 Inverters

-Operating B 3.8.7 BASES ACTIONS A.1 (continued) is powered from its constant voltage source, it is relying upon interruptible AC electrical power sources (offsite and onsite). The uninterruptible inverter source to the AC vital buses is the preferred source for powering instrumentation trip setpoint devices.B.1 and B.2 If the inoperable devices or components cannot be restored to OPERABLE status within the required Completion Time, the unit must be brought to a MODE in which the LCO does not apply. To achieve this status, the unit must be brought to at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . 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 plant systems.SURVEILLANCE SR 3.8.7.1 REQUIREMENTS This Surveillance verifies that the inverters are functioning properly with all required circuit breakers closed and AC vital buses energized from the inverter.

The verification of proper voltage and frequency L-_ output ensures that the required power is readily available for the Insert 2 rmentation of the RPS and ESFAS connected to the AC vital buses. ýTho 7.day Frequoncy takes into account the redundant capability of the invertors and other indications available in the control room that alert the operator to inverter malfunctions.

REFERENCES

1. FSAR, Chapter 8.2. FSAR, Chapter 6.3. FSAR, Chapter 15.Farley Units 1 and 2 B 3.8.7-4 Revision 12 Inverters

-Shutdown B 3.8.8 BASES SURVEILLANCE SR 3.8.8.1 (continued)

REQUIREMENTS output ensures that the required power is readily available for the instrumentation connected to the AC vital bse4;--7-day II eqie G ta e Ga... ..,,., i, ....* pability "f the, i .... teFG Insert 2 Eprno 6A Weot OR m3f therPRF('MG s.RA~ h REFERENCES

1. FSAR, Chapter 6.2. FSAR, Chapter 15.Farley Units 1 and 2 B 3.8.8-4 Revision 19 Distribution Systems--

Operating B 3.8.9 BASES ACTIONS F.1 (continued)

With two trains with inoperable distribution subsystems that result in a loss of safety function, adequate core cooling, containment OPERABILITY and other vital functions for DBA mitigation would be compromised, and immediate plant shutdown in accordance with LCO 3.0.3 is required.SURVEILLANCE REQUIREMENTS SR 3.8.9.1 This Surveillance verifies that the required AC, DC, and AC vital bus electrical power distribution systems are functioning properly, with the correct circuit breaker alignment.

The correct breaker alignment ensures the appropriate separation and independence of the electrical divisions is maintained, and the appropriate voltage is available to each required bus. The verification of proper voltage availability on the I buses ensures that the required voltage is readily available for motive S Insert 2 a wels l as control functions for critical system loads connected to these buses. ,dH~dat capability of the AC, DG, and AC vital bus electrical powor diStribution subsystems, and other indications av-ilable in the control roeo that alert the operator to 6ubsystem malfunctiens.

REFERENCES

1. FSAR, Chapter 6.2. FSAR, Chapter 15.3. Regulatory Guide 1.93, December 1974.Farley Units 1 and 2 B 3.8.9-9 Revision R Distribution Systems- Shutdown B 3.8.10 BASES ACTIONS A.1, A.2.1, A.2.2, A.2.3, A.2.4, and A.2.5 (continued) heat removal. Pursuant to LCO 3.0.6, the RHR ACTIONS would not be entered. Therefore, Required Action A.2.5 is provided to direct declaring RHR inoperable, which results in taking the appropriate RHR 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 REQUIREMENTS SR 3.8.10.1 This Surveillance verifies that the AC, DC, and AC vital bus electrical power distribution subsystems are functioning properly, with all the buses energized.

The verification of proper voltage availability on the buses ensures that the required power is readily available for motive I Insert 2 1'1ascontrol functions for critical system loads connected to these buses. The 7 day Frequency takes into acccunt the capabity Of the electrfical power distributio subsystems, and other indiatin available in the conrol1 room that ale~t the operator to subsystem; REFERENCES

1. FSAR, Chapter 6.2. FSAR, Chapter 15.Farley Units 1 and 2 B 3.8.10-5 Revision 12 Boron Concentration B 3.9.1 BASES SURVEILLANCE REQUIREMENTS SR 3.9.1.1 This SR ensures that the coolant boron concentration in the filled portions of the RCS, the refueling canal, and the refueling cavity that have direct access to the core is within the COLR limits. The boron concentration of the coolant in each volume that has direct access to the core is determined periodically by chemical analysis.I In~rt2 I I I kA m.in;iM Frnogunc..y Of once ever,' 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months is a a;mount of timo to vorify tho boron concentration of samples. The FroquencY is based On opcratine ha .sh 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to be adequate-.

Feasee~a FepreseRtatve-pee e~Whieh REFERENCES

1. 10 CFR 50, Appendix A, GDC 26.2. FSAR, Chapter 15.2.4.Farley Units 1 and 2 B 3.9.1-4 Revision R Nuclear Instrumentation B 3.9.2 BASES SURVEILLANCE REQUIREMENTS SR 3.9.2.1 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.

SR 3.9.2.2 i the performance of a CHANNEL CALIBRATION every 18 months. ThV SR is modified by a Note stating that neutron detectors are excl.ded from the CHANNEL CALIBRATION.

The CHANNEL CALIBRTION for the source range neutron flux monitors consists of obtaining t detector plateau or preamp discriminator curves and evaluating th se curves. The CHANNEL CALIBRATION for the Westinghouse moni rs also includes verification of the audible count rate function.

e !8 month Frcq'enc' is based OR the need to performA thiG Survefillance under the conditions that apply drln Rg a plant outage. Operating ha6 choWn the copn"Gent.

usually pass the Su.veillance when performed at the 18 mon0th-FroguoncY-.

REFERENCES

1. 10 CFR 50, AppendixA, GDC 13, GDC 26, GDC 28, and GDC 29.2. FSAR, Section 15.2.4.2.2.

Farley Units 1 and 2 B 3.9.2-5 Revision IN I Containment Penetrations B 3.9.3 BASES ACTIONS A.1 and A.2 If the containment equipment hatch, air locks, or any containment penetration that provides direct access from the containment atmosphere to the outside atmosphere is not in the required status, including the Containment Purge and Exhaust Isolation System not capable of automatic actuation when the purge and exhaust valves are open, the unit must be placed in a condition where 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 SR 3.9.3.1 REQUIREMENTS 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 that each valve is capable of being closed by an OPERABLE S Insert 2 automatic containment purge and exhaust isolation signal.,r-z ;o pe-F~rned 7 days. du-I, GO~R E r ALTEPTIO.NS or m- ement of irradiated ffuel assemblies Mithin ccO'ztaiRmA-At.

T-hA S'J-Lj!ve3noRG

!.'zt8F-aI

- sooted to 198 commoncurate with the duration of time to complete fuo handling 9oerations.

A suRveillance before the sta of refueling, operatioRn will pFrvide UAo or three roio. !-ahn+o verific;atio-nr duFRig the applicable period for thi, such, this Surveillance ensues that a postulated fuel handling accident that releases fission prouc r-ad-ioac-tivity within the- con-tainmen-t Will not resul1t in radiological doses in excesoo of those recommenended by RG 1. 195 (Refernce

.SR 3.9.3.2 This Surveillance demonstrates that each containment purge and exhaust valve actuates to its isolation position on manual initiation or n an actual or simulated high radiation signal from each of the ontainment purge radiation monitoring instrumentation channels.0 w Ht! I e F51UHM F=FWQW- .Y with cte(on tinued (continued)

Farley Units 1 and 2 B 3.9.3-5 Revision P Containment Penetrations B 3.9.3 BASES SURVEILLANCE REQUIREMENTS SR 3.9.3.2 (continued)

ESFAS instrumentation and Val-e testing requi--'romAnts.

Rn LCO 3.3.6, the Containment Purge and Eixhaust Isolation intuetto equires a CHANNEL CHECK evor-' 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and a GOT ove,,' 92 days to enSUre the channol QPEERABILIT during refulin*g operations.

Ever, 18 mon'nths a t' CALIBRATION i6 peiformed.

The syste, m actuatio-n opne .time i demonRstrated.

ever; 18 monthsl, duhrinOR a STAGGERED TEST BASIS. SR 3.6.3.4 demonstrates that the isolation time of each valve is in accordance with the Inservice Testing Program requirements.

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 The equipment hatch is provided with a set of hardware, tools, and equipment for moving the hatch from its storage location and installing it in the opening. The required set of hardware, tools, and equipment shall be inspected to ensure that they can perform the required Insert 2 functions.

I 7 dy frequency is adequate ccnsidedn~g that the hardware, tools, Iand equ-ipment are dedicated to the equipment hatch and not uswed for any ether func~tions.

The SR is modified by a Note which only requires that the surveillance be met for an open equipment hatch. If the equipment hatch is installed in its opening, the availability of the means to install the hatch is not required.REFERENCES

1. GPU Nuclear Safety Evaluation SE-0002000-001, Rev. 0, May 20, 1988.2. FSAR, Section 15.4.5.3. NUREG-0800, Section 15.7.4, Rev. 1, July 1981.4. Regulatory Guide 1.195, "Methods and Assumptions for Evaluating Radiological Consequences of Design Basis Accidents at Light-Water Nuclear Power Reactors," May 2003.Farley Units 1 and 2 B 3.9.3-6 Revision PR RHR and Coolant Circulation

-High Water Level B 3.9.4 BASES ACTIONS A.4, A.5, A.6.1, and A.6.2 (continued)

With RHR loop requirements not met, the potential exists for the coolant to boil and release radioactive gas to the containment atmosphere.

Performing the actions described above ensures that all containment penetrations are either closed or can be closed so that the dose limits are not exceeded.The Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months allows fixing of most RHR problems and is reasonable, based on the low probability of the coolant boiling in that time.SURVEILLANCE SR 3.9.4.1 REQUIREMENTS This Surveillance demonstrates that the RHR loop is in operation and circulating reactor coolant. The flow rate is determined by the flow Insert 2 i H sufficient decay heat removal capability and to prevent thermal and boron stratifica ion in oif 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . ,- ;.fficient, considering the flow, temperatWre, pump control, ard alarm iRdicatins available to the oprato'r in room for monitoring the RHR System.REFERENCES

1. FSAR, Section 5.5.7.Farley Units 1 and 2 B 3.9.4-4 Revision 9 RHR and Coolant Circulation--

Low Water Level B 3.9.5 BASES ACTIONS B.2 (continued)

If no RHR loop is in operation, actions shall be initiated immediately, and continued, to restore one RHR loop to operation.

Since the unit is in Conditions A and B concurrently, the restoration of two OPERABLE RHR loops and one operating RHR loop should be accomplished expeditiously.

B.3, B.4. B.5.1, and B.5.2 If no RHR is in operation, the following actions must be taken: a) the equipment hatch must be closed and secured with four bolts;b) one door in each air lock must be closed; and c) each penetration providing direct access from the containment atmosphere to the outside atmosphere must be either closed by a manual or automatic isolation valve, blind flange, or equivalent, or verified to be capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System.With RHR loop requirements not met, the potential exists for the coolant to boil and release radioactive gas to the containment atmosphere.

Performing the actions described above ensures that all containment penetrations are either closed or can be closed so that the dose limits are not exceeded.The Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months allows fixing of most RHR problems and 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 RHR loop is in operation and circulating reactor coolant. 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, during operation of the RHR loop with the water level in the vicinity of Insert 2 reactor vessel nozzles, the RHR pump suction requirements must (continued)

Farley Units 1 and 2 B 3.9.5-3 Revision [N RHR and Coolant Circulation-Low Water Level B 3.9.5 BASES SURVEILLANCE REQUIREMENTS SR 3.9.5.2 (continued)

Verification that the required pump is OPERABLE ensures that an additional RCS or RHR pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation.

I Insert 2 YV-e~i~ifýjfformed by verifying proper breaker alignment and power available to the requirea r ...available and has boon shown to be acc.ptable by operating expe~eR~e REFERENCES

1. FSAR, Section 5.5.7.Farley Units 1 and 2 B 3.9.5-4 Revision 12 Reactor Cavity Water Level B 3.9.6 BASES SURVEILLANCE REQUIREMENTS SR 3.9.6.1 (continued) considere 2deuat in iew of the largc volume of water and the Insert 2 no lp edual controls of valve ...hich m-ake udnoanned level chanrlq -,nAlkely.

REFERENCES

1. Regulatory Guide 1.25, March 23, 1972.2. FSAR, Section 15.4.5.3. NUREG-0800, Section 15.7.4.4. 10 CFR 100.10.5. Malinowski, D. D., Bell, M. J., Duhn, E., and Locante, J., WCAP-828, Radiological Consequences of a Fuel Handling Accident, December 1971.6. NUREG/CR 5009.Farley Units 1 and 2 B 3.9.6-3 Revision 9 Joseph M. Farley Nuclear Plant License Amendment Request for Adoption of TSTF-425-A, Revision 3, Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program Using the Consolidated Line Item Improvement Process Enclosure 6 Technical Specification Cross Reference for FNP and TSTF 425 Mark ups Enclosure 6 Technical Specification Cross Reference for FNP Units 1 and 2 and TSTF 425 Mark ups Technical Specification Section Title/Surveillance TSTF-425 FNP Units 1 Description*

and 2 Shutdown Margin (SDM) 3.1.1 3.1.1 Verify SDM to be within the limits specified in the COLR 3.1.1.1 3.1.1.1 Core Reactivity 3.1.2 3.1.2 Verify measured core reactivity is within +/- 1% L1 klk of 3.1.2.1 3.1.2.1 predicted values.Rod Group Alignment Limits 3.1.4 3.1.4 Verify individual rod positions within alignment limit. 3.1.4.1 3.1.4.1 Verify rod freedom of movement (trippability) by moving each 3.1.4.2 3.1.4.2 rod not fully inserted in the core 2 10 steps in either direction.

Shutdown Bank Insertion Limits 3.1.5 3.1.5 Verify each shutdown bank is within the insertion limits 3.1.5.1 3.1.5.1 specified in the COLR.Control Bank Insertion Limits 3.1.6 3.1.6 Verify each control bank insertion is within the insertion limits 3.1.6.2 3.1.6.2 specified in the COLR.Verify sequence and overlap limits specified in the COLR are 3.1.6.3 3.1.6.3 met for control banks not fully withdrawn from the core.Physics Tests Exceptions

-MODE 2 3.1.8 3.1.8 Verify the RCS lowest loop average temperature is > [531]oF 3.1.8.2 3.1.8.2 Verify THERMAL POWER is < 5% RTP. 3.1.8.3 3.1.8.3 Verify SDM is within the limits specified in the COLR. 3.1.8.4 3.1.8.4 FQ(Z) 3.2.1 3.2.1 Verify FQ(Z) is within steady state limit. 3.2.1.1 3.2.1.1 Verify FQ(Z) is within the transient limit. 3.2.1.2 3.2.1.2 FNAH 3.2.2 3.2.2 Verify FNAH is within limits specified in the COLR. 3.2.2.1 3.2.2.1 AFD 3.2.3 3.2.3 Verify AFD within limits for each OPERABLE excore channel 3.2.3.1 3.2.3.1 QPTR 3.2.4 3.2.4 Verify QPTR is within limit by calculation 3.2.4.1 3.2.4.1 Verify QPTR is within limit using the movable incore 3.2.4.2 detectors.

Confirm that the normalized symmetric power distribution is --------------

3.2.4.2 consistent with QPTR.RTS Instrumentation 3.3.1 3.3.1 Perform CHANNEL CHECK. 3.3.1.1 3.3.1.1 Compare results of calorimetric heat balance calculation to 3.3.1.2 3.3.1.2 power range channel output.Compare results of the incore detector measurements to 3.3.1.3 3.3.1.3 Nuclear Instrumentation System (NIS) AFD.Perform TADOT 3.3.1.4 3.3.1.4 Perform ACTUATION LOGIC TEST 3.3.1.5 3.3.1.5 Perform TADOT 3.3.1.6 Calibrate excore channels to agree with incore detector 3.3.1.6 3.3.1.9 measurements.

Perform COT 3.3.1.7 3.3.1.7 Perform COT 3.3.1.8 3.3.1.8 E6-1 Enclosure 6 Technical Specification Cross Reference for FNP Units 1 and 2 and TSTF 425 Mark ups Technical Specification Section Title/Surveillance TSTF-425 FNP Units 1 Description*

and 2 Perform TADOT 3.3.1.9 Perform CHANNEL CALIBRATION.

3.3.1.10 3.3.1.10 Perform CHANNEL CALIBRATION.

3.3.1.11 Perform CHANNEL CALIBRATION 3.3.1.12 Perform COT 3.3.1.13 3.3.1.11 Perform TADOT 3.3.1.14 3.3.1.12 Perform TADOT 3.3.1.15 3.3.1.12 Verify RTS RESPONSE TIME is within limits 3.3.1.16 3.3.1.14 ESFAS Instrumentation 3.3.2 3.3.2 Perform CHANNEL CHECK 3.3.2.1 3.3.2.1 Perform ACTUATION LOGIC TEST 3.3.2.2 3.3.2.2 Perform ACTUATION LOGIC TEST 3.3.2.3 Perform MASTER RELAY TEST 3.3.2.4 3.3.2.3 Perform COT 3.3.2.5 3.3.2.4 Perform SLAVE RELAY TEST 3.3.2.6 3.3.2.8 Perform TADOT 3.3.2.7 3.3.2.5 Perform TADOT 3.3.2.8 3.3.2.6 Perform CHANNEL CALIBRATION.

3.3.2.9 3.3.2.7 Verify ESFAS RESPONSE TIMES are within limit. 3.3.2.10 3.3.2.9 Perform TADOT 3.3.2.11 3.3.2.10 PAM Instrumentation 3.3.3 3.3.3 Perform CHANNEL CHECK for each required instrumentation 3.3.3.1 3.3.3.1 channel that is normally energized.

Perform CHANNEL CALIBRATION 3.3.3.2 3.3.3.2 Remote Shutdown System 3.3.4 3.3.4 Perform CHANNEL CHECK 3.3.4.1 3.3.4.1 Verify each required control circuit and transfer switch is 3.3.4.2 3.3.4.2 capable of performing the intended function Perform CHANNEL CALIBRATION for each required 3.3.4.3 3.3.4.3 instrumentation channel.Perform TADOT of the reactor trip breaker open/closed 3.3.4.4 indication.

LOP DG Start Instrumentation 3.3.5 3.3.5 Perform CHANNEL CHECK 3.3.5.1 Perform TADOT 3.3.5.2 3.3.5.1 Perform CHANNEL CALIBRATION 3.3.5.3 3.3.5.2 Verify ESF RESPONSE TIME within limit. 3.3.5.3 Containment Purge and Exhaust Isolation Instrumentation 3.3.6 3.3.6 Perform CHANNEL CHECK 3.3.6.1 3.3.6.1 Perform ACTUATION LOGIC TEST 3.3.6.2 3.3.6.2 Perform MASTER RELAY TEST 3.3.6.3 3.3.6.3 Perform ACTUATION LOGIC TEST 3.3.6.4 Perform MASTER RELAY TEST 3.3.6.5 Perform COT 3.3.6.6 3.3.6.4 Perform SLAVE RELAY TEST 3.3.6.7 3.3.6.5 Perform TADOT 3.3.6.8 3.3.6.6 E6-2 Enclosure 6 Technical Specification Cross Reference for FNP Units I and 2 and TSTF 425 Mark ups Technical Specification Section Title/Surveillance TSTF-425 FNP Units 1 Description*

and 2 Perform CHANNEL CALIBRATION 3.3.6.9 3.3.6.7 Verify ESF RESPONSE TIME within limit. 3.3.6.8 CREFS Actuation Instrumentation 3.3.7 3.3.7 Perform CHANNEL CHECK 3.3.7.1 3.3.7.1 Perform COT 3.3.7.2 3.3.7.2 Perform ACTUATION LOGIC TEST 3.3.7.3 3.3.7.3 Perform MASTER RELAY TEST 3.3.7.4 3.3.7.4 Perform ACTUATION LOGIC TEST 3.3.7.5 Perform MASTER RELAY TEST 3.3.7.6 Perform SLAVE RELAY TEST 3.3.7.7 3.3.7.5 Perform TADOT 3.3.7.8 3.3.7.6 Perform CHANNEL CALIBRATION 3.3.7.9 3.3.7.7 PRF Actuation Instrumentation

3.3.8 Perform

CHANNEL CHECK 3.3.8.1 Perform COT 3.3.8.2 Perform ACTUATION LOGIC TEST 3.3.8.3 Perform MASTER RELAY TEST 3.3.8.4 Perform SLAVE RELAY TEST 3.3.8.5 Perform TADOT 3.3.8.6 Perform CHANNEL CALIBRATION 3.3.8.7 FBACS Actuation Instrumentation

3.3.8 Perform

CHANNEL CHECK 3.3.8.1 Perform COT 3.3.8.2 Perform ACTUATION LOGIC TEST 3.3.8.3 Perform TADOT 3.3.8.4 Perform CHANNEL CALIBRATION 3.3.8.5 BDPS 3.3.9 Perform CHANNEL CHECK 3.3.9.1 Perform COT 3.3.9.2 Perform CHANNEL CALIBRATION 3.3.9.3 RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 3.4.1 Verify pressurizer pressure is greater than or equal to the limit 3.4.1.1 3.4.1.1 specified in the COLR.Verify RCS average temperature is less than or equal to the 3.4.1.2 3.4.1.2 limit specified in the COLR.Verify RCS total flow rate is r [284,000]

gpm and greater than 3.4.1.3 3.4.1.3 or equal to the limit specified in the COLR.Verify by measurement that RCS total flow rate is within the --------------

3.4.1.3 limits.Verify by precision heat balance that RCS total flow rate is > 3.4.1.4[284,000]

gpm and greater than or equal to the limit specified in the COLR.Reactor Coolant System (RCS) 3.4.2 3.4.2 Verify RCS Tavn in each loop > [541]oF. 3.4.2.1 3.4.2.1 RCS P/T Limits 3.4.3 3.4.3 Verify RCS pressure, RCS temperature, and RCS heatup and 3.4.3.1 3.4.3.1 cooldown rates are within the limits specified in the PTLR.E6-3 Enclosure 6 Technical Specification Cross Reference for FNP Units I and 2 and TSTF 425 Mark ups Technical Specification Section Title/Surveillance TSTF-425 FNP Units 1 Description*

and 2 RCS Loops MODES 1 and 2 3.4.4 3.4.4 Verify each RCS loop is in operation.

3.4.4.1 3.4.4.1 RCS Loops MODES 3 3.4.5 3.4.5 Verify required RCS loops are in operation.

3.4.5.1 3.4.5.1 Verify steam generator secondary side water levels are 2_ 3.4.5.2 3.4.5.2[171% for required RCS loops.Verify correct breaker alignment and indicated power are 3.4.5.3 3.4.5.3 available to each required pump.RCS Loops MODES 4 3.4.6 3.4.6 Verify required RHR or RCS loop is in operation.

3.4.6.1 3.4.6.1 Verify SG secondary side water levels are > [171% for 3.4.6.2 3.4.6.2 required RCS loops.Verify correct breaker alignment and indicated power are 3.4.6.3 3.4.6.3 available to each required pump.RCS Loops -MODE 5, Loops Filled 3.4.7 3.4.7 Verify required RHR loop is in operation.

3.4.7.1 3.4.7.1 Verify SG secondary side water level is 2 [17]% in required 3.4.7.2 3.4.7.2 SGs.Verify correct breaker alignment and indicated power are 3.4.7.3 3.4.7.3 available to each required RHR pump.RCS Loops -MODE 5, Loops Not Filled 3.4.8 3.4.8 Verify required RHR loop is in operation.

3.4.8.1 3.4.8.1 Verify correct breaker alignment and indicated power are 3.4.8.2 3.4.8.2 available to each required RHR pump.Pressurizer 3.4.9 3.4.9 Verify pressurizer water level is < [92]%. 3.4.9.1 3.4.9.1 Verify capacity of each required group of pressurizer heaters 3.4.9.2 3.4.9.2 is a [125] kW.Verify required pressurizer heaters are capable of being 3.4.9.3 3.4.9.3 powered from an emergency power supply.Pressurizer PORVs 3.4.11 3.4.11 Perform a complete cycle of each block valve. 3.4.11.1 3.4.11.1 Perform a complete cycle of each PORV. 3.4.11.2 3.4.11.2 Perform a complete cycle of each PORV using the backup 3.4.11.3 PORV control system.Perform a complete cycle of each solenoid air control valve 3.4.11.3 and check valve on the air accumulators in PORV control systems.Verify PORVs and block valves are capable of being powered 3.4.11.4 from emergency power sources.Check power available to the Unit Two PORV block valve 3.4.11.4 LTOP System 3.4.12 3.4.12 Verify a maximum of [one] [HPI] pump is capable of injecting 3.4.12.1 into the RCS.Verify a maximum of one charging pump is capable of 3.4.12.2.

3.4.12.1 injecting into the RCS.Verify each accumulator is isolated.

3.4.12.3 3.4.12.2 E6-4 Enclosure 6 Technical Specification Cross Reference for FNP Units 1 and 2 and TSTF 425 Mark ups Technical Specification Section Title/Surveillance TSTF-425 FNP Units 1 Description*

and 2 Verify RHR suction valve is open for each required RHR 3.4.12.4 3.4.12.3 suction relief valve Verify required RCS vent > [2.07] square inches open. 3.4.12.5 3.4.12.4 Verify each required RHR suction relief valve setpoint.

3.4.12.5 Verify PORV block valve is open for each required PORV. 3.4.12.6 Verify associated RHR suction isolation valve is locked open 3.4.12.7 with operator power removed for each required RHR suction relief valve.Perform a COT on each required PORV, excluding actuation.

3.4.12.8 Perform CHANNEL CALIBRATION for each required PORV 3.4.12.9 actuation channel.RCS Operational LEAKAGE 3.4.13 3.4.13 Verify RCS operational LEAKAGE is within limits by 3.4.13.1 3.4.13.1 performance of RCS water inventory balance.Verify primary to secondary LEAKAGE is < 150 gallons per 3.4.13.2 3.4.13.2 day through any one SG.RCS PIV Leakage 3.4.14 3.4.14 Verify leakage from each RCS PIV is equivalent to < 0.5 gpm 3.4.14.1 3.4.14.1 per nominal inch of valve size up to a maximum of 5 gpm at an RCS pressure 2 [2215] psig and _5 [2255] psig.Verify RHR System autoclosure interlock prevents the valves 3.4.14.2 3.4.14.2 from being opened with a simulated or actual RCS pressure signal ? [425] psig.Verify RHR System autoclosure interlock causes the valves to 3.4.12.3 3.4.14.3 close automatically with a simulated or actual RCS pressure signal _ [600] psig.RCS Leakage Detection Instrumentation 3.4.15 3.4.15 Perform CHANNEL CHECK of the required containment 3.4.15.1 3.4.15.1 atmosphere radioactivity monitor.Perform COT of the required containment atmosphere 3.4.15.2 3.4.15.2 radioactivity monitor.Perform CHANNEL CALIBRATION of the required 3.4.15.3 containment sump monitor.Perform CHANNEL CALIBRATION of the required 3.4.15.4 3.4.15.3 containment atmosphere radioactivity monitor.Perform CHANNEL CALIBRATION of the required 3.4.15.5 3.4.15.4 containment air cooler condensate flow rate monitor.RCS Specific Activity 3.4.16 3.4.16 Verify reactor coolant gross specific activity _ 100/E pCi/gm. 3.4.16.1 3.4.16.1 Verify reactor coolant DOSE EQUIVALENT 1-131 specific 3.4.16.2 3.4.16.2 activity 5 1 pCi/gm.Determine E from a sample taken in MODE 1 after a 3.4.16.3 3.4.16.3 minimum of 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 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .RCS Loop Isolation Valves 3.4.17 E6-5 Enclosure 6 Technical Specification Cross Reference for FNP Units 1 and 2 and TSTF 425 Mark ups Technical Specification Section Title/Surveillance TSTF-425 FNP Units 1 Description*

and 2 Verify each RCS loop isolation valve is open and power is 3.4.17.1 removed from each loop isolation valve operator RCS Loops -Test Exceptions 3.4.19 Verify THERMAL POWER is < P-7. 3.4.19.1 Accumulators 3.5.1 3.5.1 Verify each accumulator isolation valve is fully open 3.5.1.1 3.5.1.1 Verify borated water volume in each accumulator is > [7853 3.5.1.2 3.5.1.2 gallons 0% and 8171 gallons 0%]Verify nitrogen cover pressure in each accumulator is >[385] 3.5.1.3 3.5.1.3 psig and <[481] psig Verify boron concentration in each accumulator is > [1900] 3.5.1.4 3.5.1.4 ppm and < [2100] ppm.Verify power is removed from each accumulator isolation 3.5.1.5 3.5.1.5 valve operator when RCS pressure is > [2000] psig ECCS -Operating 3.5.2 3.5.2 Verify the following valves are in the listed position with power 3.5.2.1 3.5.2.1 to the valve operator removed.Verify each ECCS manual, power operated, and automatic 3.5.2.2 3.5.2.2 valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.Verify ECCS piping is full of water. 3.5.2.3 Verify each ECCS automatic valve in the flow path that is not 3.5.2.5 3.5.2.4 locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.Verify each ECCS pump starts automatically on an actual or 3.5.2.6 3.5.2.5 simulated actuation signal.Verify, for each ECCS throttle valve listed below each position 3.5.2.7 3.5.2.6 stop is in the correct position.Verify, by visual inspection, each ECCS train containment sump 3.5.2.8 3.5.2.7 suction inlet is not restricted by debris and the suction inlet trash racks and screens show no evidence of structural distress or abnormal corrosion.

RWST 3.5.4 3.5.4 Verify RWST borated water temperature 3.5.4.1 3.5.4.1 Verify RWST borated water volume 3.5.4.2 3.5.4.2 Verify RWST boron concentration 3.5.4.3 3.5.4.3 Seal Injection Flow 3.5.5 3.5.5 Verify manual seal injection throttle valves are adjusted 3.5.5.1 3.5.5.1 Eccs Recirculation Fluid pH Control System 3.5.6 Perform a visual inspection of the ECCS Recirculation Fluid --------------

3.5.6.1 pH Control System and verify BIT 3.5.6 Verify BIT borated water temperature is a [145]°F. 3.5.6.1 Verify BIT borated water volume is a [1100] gallons. 3.5.6.2 Verify BIT boron concentration is 2 [20,000] ppm and _5 3.5.6.3[22,500] ppm.Containment Air Locks (Atmospheric, Subatmospheric, Ice 3.6.2 3.6.2 E6-6 Enclosure 6 Technical Specification Cross Reference for FNP Units 1 and 2 and TSTF 425 Mark ups Technical Specification Section Title/Surveillance TSTF-425 FNP Units 1 Description*

and 2 Condenser, and Dual)Perform required air lock leakage rate testing in accordance 3.6.2.1 3.6.2.1 with the Containment Leakage Rate Testing Program.Verify only one door in the air lock can be opened at a time. 3.6.2.2 3.6.2.2 Containment Isolation Valves (Atmospheric, 3.6.3 3.6.3 Subatmospheric, Ice Condenser, and Dual)Verify each [42] inch purge valve is sealed closed, except for 3.6.3.1 3.6.3.1 one purge valve in a penetration flow path while in Condition E of this LCO.Verify each [8] inch purge valve is closed, except when the [8] 3.6.3.2--------

inch containment 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. ______Verify each containment isolation manual valve and blind 3.6.3.3 3.6.3.2 flange that is located outside 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.Cycle each weight or spring loaded check valve testable 3.6.3.6--------

during operation through one complete cycle of full travel, and verify each check valve remains closed when the differential pressure in the direction of flow is 5 [1 .2] psid and opens when the differential pressure in the direction of flow is ! [1 .2] psid and< [5.0] psid.__ _____Perform leakage rate testing for containment purge valves 3.6.3.7 3.6.3.5 with resilient seals.Verify each automatic containment isolation valve that is not 3.6.3.8 3.6.3.6 locked, sealed or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal. _______Cycle each weight or spring loaded check valve not testable 3.6.3.9--------

during operation through one complete cycle of full travel, and verify each check valve remains closed when the differential pressure in the direction of flow Verify each [ ] inch containment purge valve is blocked to 3.6.3.10--------

restrict the valve from opening ______________

Verify the combined leakage rate for all shield building bypass 3.6.3.11--------

leakage paths _______Containment Pressure 3.6.4 3.6.4 Verify containment pressure is within limits. 3.6.4.1 3.6.4.1 Containment Air Temperature 3.6.5 3.6.5 Verify containment average air temperature is within limits 3.6.5.1 3.6.5.1 Containment Spray and Cooling Systems -------- 3.6.6 Verify each containment spray manual, power operated, and --------------

3.6.6.1 automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.Operate each required containment cooling train fan unit -------- 3.6.6.2 Verify each containment cooling train cooling water flow rate --------------

13.6.6.3 E6-7 Enclosure 6 Technical Specification Cross Reference for FNP Units 1 and 2 and TSTF 425 Mark ups Technical Specification Section Title/SurveilIlance TSTF-425 FNP Units 1 Description*

and 2 Verify each automatic containment spray valve in the flow -------- 3.6.6.5 path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.Verify each containment spray pump starts automatically on --------------

3.6.6.6 an actual or simulated actuation signal.Verify each containment cooling train starts automatically on --------------

3.6.6.7 an actual or simulated actuation signal.Verify each spray nozzle is unobstructed.

3.6.6.8 Spray Additive System (Atmospheric, Subatmospheric, Ice 3.6.7--------

Condenser, and Dual)Verify each spray additive manual, power operated, and 3.6.7.1--------

automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.Verify spray additive tank solution volume 3.6.7.2--------

Verify spray additive tank [NaOH] solution 3.6.7.3--------

Verify each spray additive automatic valve in the flow path 3.6.7.4--------

that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.Verify spray additive flow [rate] from each solution's flow path. 3.6.7.5--------

Shield Building (Dual and Ice Condenser) 3.6.8--------

Verify annulus negative pressure is > [5] inches water gauge. 3.6.8.1--------

Verify shield building structural integrity by performing a visual 3.6.8.2---------

inspection of the exposed interior and exterior surfaces of the shield building.Verify the shield building can be maintained at a pressure 3.6.8.3--------

equal to or more negative than [-0.5] inch water gauge in the annulus by one Shield Building Air Cleanup System train with f inal f low :5 []I cfmr within [22] seconds after a start signal. _______HMS (Atmospheric, Ice Condenser, and Dual) 3.6.9 3.6.8 Operate each HMS train for 2:15 minutes. 3.6.9.1 3.6.8.1 Verify each HMS train flow rate on slow speed is 2:[4000] cfm 3.6.9.2 3.6.8.2 Verify each HMS train starts on an actual or simulated 3.6.9.3 3.6.8.3 actuation signal.HIS (Ice Condenser) 3.6.10--------

Energize each HIS train power supply breaker and verify 3.6.10.1--------

[32] ignitors are energized in each train Verify at least one hydrogen ignitor is OPERABLE in each 3.6.10.2--------

containment region.Energize each hydrogen ignitor and verify temperature is 3.6.10.3--------

[1 700]'F.Reactor Cavity Hydrogen Dilution System -------- 3.6.9 Operate each Reactor Cavity Hydrogen Dilution train -------- 3.6.9.1 Verify each Reactor Cavity Hydrogen Dilution train -------- 3.6.9.2 ICS (Atmospheric and Subatmoapheric) 3.6.11--------

Operate each ICS train for ý10 continuous hours with heaters ,3.6.11.1--------

E6-8 Enclosure 6 Technical Specification Cross Reference for FNP Units 1 and 2 and TSTF 425 Mark ups Technical Specification Section Title/Surveillance TSTF-425 FNP Units 1 Description*

and 2 operating or (for systems without heaters) a 15 minutes].Verify each ICS train actuates on an actual or simulated 3.6.11.3 actuation signal.Verify each ICS filter bypass damper can be opened 3.6.11.4 SBACE (Dual and Ice Condenser) 3.6.13 Operate each SBACS train for [> 10 continuous hours with 3.6.13.1 heaters operating or (for systems without heaters) > 15 minutes]Verify each SBAC train actuates on an actual or simulated 3.6.13.3 actuation signal Verify each SBACS filter bypass damper can be opened. 3.6.13.4 Verify each SBACS train flow rate is > [ cfm. 3.6.13.5 ARS (Ice Condenser) 3.6.14 Verify each ARS fan starts on an actual or simulated 3.6.14.1 actuation signal Verify, with the ARS fan dampers closed, each ARS fan 3.6.14.2 motor Verify, with the ARS fan not operating, 3.6.14.3 Verify each motor operated valve in the hydrogen collection 3.6.14.4 header that is not locked, sealed, or otherwise secured in position, opens ...Ice Bed (Ice Condenser) 3.6.15 Verify maximum ice bed temperature is < [27]°F. 3.6.15.1 Verify total mass of stored ice ... 3.6.15.2 Verify that the ice mass of each basket sampled 3.6.15.3 Verify, by visual inspection, accumulation of ice on structural 3.6.15.4 members Verify, by chemical analysis of the stored ice in at least one 3.6.15.5 randomly selected ice basket from each ice condenser bay, that ice bed: Visually inspect, for detrimental structural wear, cracks, 3.6.15.6 corrosion, or other damage, two ice baskets from each group of bays Verify, by chemical analysis, that ice added to the ice 3.6.15.7 condenser meets the boron concentration and pH requirements of SR 3.6.15.5.Ice Condenser Doors (Ice Condenser) 3.6.16 Verify all inlet doors indicate closed by the Inlet Door Position 3.6.16.1 Monitoring System.Verify, by visual inspection, each intermediate deck door is 3.6.16.2 closed and not impaired by ice, frost, or debris.Verify, by visual inspection, each inlet door is not impaired by 3.6.16.3 ice, frost, or debris.Verify torque 3.6.16.4 Perform a torque test 3.6.16.5 Verify for each intermediate deck door 3.6.16.6 Verify, by visual inspection, each top deck [door] 3.6.16.7 Divider Barrier Integrity (Ice Condenser) 3.6.17 E6-9 Enclosure 6 Technical Specification Cross Reference for FNP Units I and 2 and TSTF 425 Mark ups Technical Specification Section Title/Surveillance TSTF-425 FNP Units 1 Description*

and 2 Verify, by visual inspection, that the seals and sealing 3.6.17.2 surfaces of each personnel access door and equipment hatch Remove two divider barrier seal test coupons and verify 3.6.17.4 Visually inspect 3.6.17.5 Containment Recirculation Drains (Ice Condenser) 3.6.18 Verify, by visual inspection 3.6.18.1 Verify for each ice condenser floor drain 3.6.18.2 MSIVs 3.7.2 3.7.2 Verify each MSIV actuates 3.7.2.2 3.7 MFIVs and MFRVs and [Associated Bypass Valves] 3.7.3 3.7.3 Verify each MFIV, MFRV 3.7.3.2 ARVs 3.7.4 Verify one complete cycle of each ARV. 3.7.4.1 Verify one complete cycle of at least one manual isolation valve ------------

3.7.4.2 in each ARV Line.ADVs 3.7.4 Verify one complete cycle of each ADV. 3.7.4.1 Verify one complete cycle of each ADV block valve. 3.7.4.2 AFW System 3.7.5 3.7.5 Verify each AFW manual, power operated, and automatic 3.7.5.1 3.7.5.1 valve in each water flow path, Verify each AFW automatic valve that is not locked 3.7.5.3 3.7.5.3 Verify each AFW pump starts automatically 3.7.5.4 3.7.5.4 Verify the turbine driven AFW pump steam admission valves -------------

3.7.5.5 open when air is supplied from their respective air accumulators.

CST 3.7.6 3.7.6 Verify the CST level 3.7.6.1 3.7.6.1 CCW System 3.7.7 3.7.7 Verify each CCW manual, power operated,'and automatic 3.7.7.1 3.7.7.1 valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.Verify each CCW automatic valve in the flow path that is not 3.7.7.2 3.7.7.2 locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.Verify each CCW pump starts automatically on an actual or 3.7.7.3 3.7.7.3 simulated actuation signal.SWS 3.7.8 3.7.8 Verify each SWS manual, power operated, and automatic 3.7.8.1 3.7.8.1 valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.Verify each SWS automatic valve in the flow path that is not 3.7.8.2 3.7.8.2 locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.Verify each SWS pump starts automatically on an actual or 3.7.8.3 3.7.8.3 simulated actuation signal.E6-10 Enclosure 6 Technical Specification Cross Reference for FNP Units 1 and 2 and TSTF 425 Mark ups Technical Specification Section Title/Surveillance TSTF-425 FNP Units 1 Description*

and 2 Verify the integrity of the SWS buried piping by visual 3.7.8.4 inspection of the ground area.UHS 3.7.9 3.7.9 Verify water level of UHS 3.7.9.1 3.7.9.1 Verify average water temperature of UHS 3.7.9.2 3.7.9.2 Operate each cooling tower fan 3.7.9.3 Verify each cooling tower fan starts automatically on an actual 3.7.9.4 or simulated actuation signal.Control Room --------------

3.7.10 Operate each CREFS Pressurization train --------------

3.7.10.1 Verify each CREFS train actuates ---------------

3.7.10.3 Verify CRE Ap within limits in the Control Room ---------------

3.7.10.4 IntegrityProgram (CRIP).CREFS 3.7.10 Operate each CREFS train 3.7.10.1 Verify each CREFS train actuates 3.7.10.3 Verify one CREFS train can maintain positive pressure 3.7.10.4 CRACS 3.7.11 Verify each CRAGS train ---------------

3.7.11.1 CREATCS 3.7.11 Verify each CREATCS train 3.7.11.1 PRF 3.7.12 Verify two PRF trains aligned to the SFPR. -------------

3.7.12.1 Operate each PRF train ---------------

3.7.12.2 Verify each PRF train actuates --------------

3.7.12.4 Verify one PRF train can maintain a pressure ---------------

3.7.12.5 Verify one PRF train can maintain a slightly negative pressure -------------

3.7.12.6 ECCS PREACS 3.7.12 Operate each ECCS PREACS train 3.7.12.1 Verify each ECCS PREACS train actuates 3.7.12.3 Verify one ECCS PREACS train can maintain a pressure 3.7.12.4 Verify each ECCS PREACS filter bypass damper can be 3.7.12.5 closed FBACS 3.7.13 Operate each FBACS train 3.7.13.1 Verify each FBACS train actuates 3.7.13.3 Verify one FBACS train can maintain a pressure 3.7.13.4 Verify each FBACS filter bypass damper can be closed 3.7.13.5 -PREACS 3.7.14 Operate each PREACS train 3.7.14.1 Verify each PREACS train actuates 3.7.14.3 Verify one PREACS train can maintain a pressure 3.7.14.4 Verify each PREACS filter bypass damper can be closed 3.7.14.5 Fuel Storage Pool Water Level 3.7.15 3.7.13 Verify the fuel storage pool water level 3.7.15.1 3.7.13.1 Fuel Storage Pool Boron Concentration 3.7.16 3.7.14 Verify the fuel storage pool boron concentration is within limit. 3.7.16.1 3.7.14.1 E6-11 Enclosure 6 Technical Specification Cross Reference for FNP Units 1 and 2 and TSTF 425 Mark ups Technical Specification Section Title/Surveillance TSTF-425 FNP Units 1 Description*

and 2 Secondary Specific Activity 3.7.18 3.7.16 Verify the specific activity 3.7.18.1 3.7.16.1 ESF Room Coolers 3.7.19 Verify each ESF Room Cooler system manual valve servicing

3.7.19.1 safety-related equipment that is not locked, sealed, or otherwise secured in position, is in the correct position.Verify each ESF Room Cooler fan starts automatically on an -------------

3.7.19.2 actual or simulated actuation signal.AC Sources -Operating 3.8.1 3.8.1 Verify correct breaker alignment and indicated power 3.8.1.1 3.8.1.1 availability for each [required]

offsite circuit.Verify each DG starts from standby conditions 3.8.1.2 3.8.1.2 Verify each DG is synchronized and loaded and operates 3.8.1.3 3.8.1.3 Verify each day tank 3.8.1.4 3.8.1.4 Check for and remove accumulated water from each day tank 3.8.1.5 Verify the fuel oil transfer system operates 3.8.1.6 3.8.1.5 Verify each DG starts from standby 3.8.1.7 3.8.1.6 Verify [automatic

[and] manual] transfer of AC power sources 3.8.1.8 3.8.1.7 from the normal offsite circuit to each alternate

[required]

off site circuit.Verify each DG rejects a load greater than or equal to its 3.8.1.9 3.8.1.8 associated single largest post-accident load Verify each DG does not trip and voltage is maintained 3.8.1.10 Verify on an actual or simulated loss of offsite power signal 3.8.1.11 3.8.1.9 Verify on an actual or simulated Engineered Safety Feature 3.8.1.12 3.8.1.10 (ESF) actuation signal each DG auto-starts from standby condition Verify each DG's noncritical automatic trips are bypassed on 3.8.1.13[actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ESF actuation signal]Verify each DG's automatic trips are bypassed 3.8.1.11 Verify each DG operates 3.8.1.14 3.8.1.12 Verify each DG starts and achieves...

3.8.1.15 3.8.1.13 Verify each DG 3.8.1.16 3.8.1.14 Verify, with a DG operating in test mode and connected to its 3.8.1.17 3.8.1.15 bus, an actual or simulated ESF actuation signal overrides the E6-12 Enclosure 6 Technical Specification Cross Reference for FNP Units 1 and 2 and TSTF 425 Mark ups Technical Specification Section Title/Surveillance TSTF-425 FNP Units 1 Description*

and 2 test mode Verify interval between each sequenced load block 3.8.1.18 3.8.1.16 Verify on an actual or simulated loss of offsite power signal in 3.8.1.19 3.8.1.17 conjunction with an actual or simulated ESF actuation signal Verify each IDG does not trip and voltage -------- 3.8.1.18 Verify when started simultaneously from standby condition 3.8.1.20 3.8.1.19 Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 3.8.3 Verify each fuel oil storage tank 3.8.3.1 3.8.3.1 Verify lubricating oil inventory 3.8.3.2 3.8.3.2 Verify each IDG air start receiver pressure 3.8.3.4 3.8.3.4 Check for and remove accumulated water from each fuel oil 3.8.3.5--------

storage tank.DC Sources -Operating 3.8.4 3.8.4 Verify battery terminal voltage 3.8.4.1 3.8.4.1 Verify no visible corrosion at battery terminal -------- 3.8.4.2 Verify battery cells, cell plates, and racks show no visual -------- 3.8.4.3 indication of physical damage or abnormal deterioration._______

Remove visible terminal corrosion, verify battery cell- to-cell---------------

3.8.4.4 and terminal connections are coated with anti-corrosion material.Verify post-to-post battery connection resistance

3.8.4.5 Verify each required Auxiliary Building battery -------- 3.8.4.6 Verify battery capacity -------- 3.8.4.7 Verify each battery charge 3.8.4.2--------

Verify battery capacity 3.8.4.3 3.8.4.8 Battery Cell Parameters

3.8.6 Verify battery cell parameters

3.8.6.1 Verify battery cell parameters

3.8.6.2 Verify average electrolyte temperature of representative cells ---------------

3.8.6.3 Battery Parameters 3.8.6--------

Verify each battery float current 3.8.6.1--------

Verify each battery pilot cell voltage 3.8.6.2--------

Verify each battery connected cell electrolyte level 3.8.6.3-------7 Verify each battery pilot cell temperature 3.8.6.4--------

Verify each battery connected cell voltage 3.8.6.5--------

Verify battery capacity 3.8.6.6--------

Inverters

-Operating 3.8.7 3.8.7 Verify correct inverter voltage, [frequency].

And alignment to 3.8.7.1 3.8.7.1 required AC vital buses ______Inverters

-Shutdown 3.8.8 3.8.8 Verify correct inverter voltage, [frequency,]

and alignments to 3.8.8.1 3.8.8.1 required AC vital buses. ______Distribution Systems -Operating 3.8.9 3.8.9 Verify correct breaker alignments and voltage to [required]

13.8.9.1 13.8.9.1 116-13 Enclosure 6 Technical Specification Cross Reference for FNP Units 1 and 2 and TSTF 425 Mark ups Technical Specification Section Title/Surveillance TSTF-425 FNP Units 1 Description*

and 2 AC, DC, and AC vital bus electrical power distribution subsystems.

Distribution Systems -Shutdown 3.8.10 3.8.10 Verify correct breaker alignments and voltage to required AC, 3.8.10.1 3.8.10.1 DC, and AC vital bus electrical power distribution subsystems.

Boron Concentration 3.9.1 3.9.1 Verify boron concentration is within the limit specified in the 3.9.1.1 3.9.1.1 COLR.Unborated Water Source Isolation Water 3.9.2 Verify each valve that isolates unborated water sources is 3.9.2.1 secured in the closed position.Nuclear Instrumentation 3.9.3 3.9.2 Perform CHANNEL CHECK 3.9.3.1 3.9.2.1 Perform CHANNEL CALIBRATION 3.9.3.2 3.9.2.2 Containment Penetrations 3.9.4 3.9.3 Verify each required containment penetration is in the 3.9.4.1 3.9.3.1 required status.Verify each required containment purge and exhaust valve 3.9.4.2 3.9.3.2 actuates to the isolation position on an actual or simulated actuation signal.Verify the capability to install the equipment hatch. -3.9.3.3 RHR and Coolant Circulation

-High Water Level 3.9.5 3.9.4 Verify one RHR loop is in operation and circulating reactor 3.9.5.1 3.9.4.1 coolant at a flow rate RHR and.Coolant Circulation

-Low Water Level 3.9.6 3.9.5 Verify one RHR loop is in operation and circulating reactor 3.9.6.1 3.9.5.1 coolant at-a flow rate Verify correct breaker alignment and indicated power 3.9.6.2 3.9.5.2 available to the required RHR pump that is not in operation.

Refueling Cavity Water Level 3.9.7 3.9.6 Verify refueling cavity water level 3.9.7.1 3.9.6.1 The Technical Specification (TS) Section Title/Surveillance Description portion of this Enclosure is a summary description of the referenced TSTF 425/ FNP TS Surveillances which is provided for information.

E6-14

v t e Letter Sequence Request
TAC:ME5055, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B (Approved, Closed)
Initiation Request Acceptance... Supplement Administration Questions Answers Results Approval Other:
MONTHYEAR2011-02-21 [Table View]

ML103140605

Text

Enclosures:

2.0 Assessment

2.1 Applicability

2.2 Optional

3.0 Regulatory

4.0 Environmental

2.0 Assessment

2.1 Applicability

4.0 Environmental

2.0 Technical

2.2.3 Resolutions

3.0 External

4.0 General

5.0 References

2.2.1 Previous

3.1.2 SURVEILLANCE

3.3.1 SURVEILLANCE

3.3.1 SURVEILLANCE

3.3.1 SURVEILLANCE

3.3.1 SURVEILLANCE

3.3.1 SURVEILLANCE

3.3.2 SURVEILLANCE

3.3.3 ACTIONS

3.3.5 ACTIONS

3.3.5 SURVEILLANCE

3.3.6 SURVEILLANCE

3.3.7 ACTIONS

3.3.7 SURVEILLANCE

3.3.8 SURVEILLANCE

3.4.9 SURVEILLANCE

3.5.1 SURVEILLANCE

3.8.1 SURVEILLANCE

3.8.1 SURVEILLANCE

3.8.1 SURVEILLANCE

3.8.4 SURVEILLANCE

3.8.6 ACTIONS

3.8.6 SURVEILLANCE

3.8.7 ACTIONS

3.9.1 Boron

3.9.2 Farley

3.9.3 Farley

3.9.6 Refueling

3.1.2 SURVEILLANCE

3.3.1 SURVEILLANCE

3.3.1 SURVEILLANCE

3.3.1 SURVEILLANCE

3.3.1 SURVEILLANCE

3.3.1 SURVEILLANCE

3.3.2 ACTIONS

3.3.2 SURVEILLANCE

3.3.2 SURVEILLANCE

3.3.2 Table

3.3.2 Table

3.3.2 Table

3.3.2 Table

3.3.3 ACTIONS

3.3.5 ACTIONS

3.3.5 SURVEILLANCE

3.3.6 SURVEILLANCE

3.3.6 SURVEILLANCE

3.3.6 Table

3.3.7 ACTIONS

3.3.7 SURVEILLANCE

3.3.8 SURVEILLANCE

3.3.8 SURVEILLANCE

3.3.8 Table

3.4.9 SURVEILLANCE

3.5.1 SURVEILLANCE

3.8.6 ACTIONS

3.8.6 SURVEILLANCE

3.9.1 Boron

3.9.2 SURVEILLANCE

3.9.3 SURVEILLANCE

3.9.6 Refueling

3.3.8 Perform

3.3.8 Perform

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